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Home My WebLink About199-094CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:CD1-06 ,11,13,16 and 20 non-witnessed MITIA"s 06-21-25 Date:Sunday, June 22, 2025 10:24:04 AM Attachments:image001.png MIT CRU CD1-6,11,13,16 and 20 SI TESTS 06-21-25.xlsx Good Morning, Please see the attached 10-426 form from the non witnessed shut in MITIA’s on CD1-06 ,11,13,16 and 20 that were conducted on 6-21-25. If you have any questions please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000830 Type Inj N Tubing 5 10 10 10 Type Test P Packer TVD 6622 BBL Pump 1.9 IA 430 2000 1965 1960 Interval 4 Test psi 1656 BBL Return 1.9 OA 460 465 470 470 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2041800 Type Inj N Tubing 715 890 930 930 Type Test P Packer TVD 6748 BBL Pump 1.6 IA 470 2000 1960 1960 Interval 4 Test psi 1687 BBL Return 1.6 OA 710 715 715 715 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990520 Type Inj N Tubing 1080 1750 1290 1295 Type Test P Packer TVD 6783 BBL Pump 1.0 IA 500 2040 1990 1985 Interval 4 Test psi 1696 BBL Return 1.0 OA 150 155 155 155 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990940 Type Inj N Tubing 510 685 705 710 Type Test P Packer TVD 6733 BBL Pump 1.2 IA 470 2010 1960 1955 Interval 4 Test psi 1683 BBL Return 1.2 OA 635 640 640 640 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042400 Type Inj N Tubing 985 1165 1205 1205 Type Test P Packer TVD 6843 BBL Pump 1.4 IA 440 2000 1950 1950 Interval 4 Test psi 1711 BBL Return 1.4 OA 600 610 610 610 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 Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD1 PAD Van Camp / Burton 06/21/25 Notes: Notes: Notes: Notes: CD1-06 CD1-11 CD1-16 CD1-20 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: CD1-13 Notes: CD1-20 Notes: Form 10-426 (Revised 01/2017)2025-0621_MIT_CRU_CD1-16 9 9 9 9 999 999¾ 99 9 9 -5HJJ CD1-16 MEMORANDUM TO: Jim Regg P.I. Supervisor Rey t FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CDI-16 COLVILLE RIV UNIT CDI-16 Src: Inspector Reviewed By: P.I. Supry S Comm Well Name COLVILLE RIV UNIT CDI-16 API Well Number 50-103-20306-00-00 Inspector Name: Lou Laubenstein Permit Number: 199-094-0 Inspection Date: 6/12/2021 Insp Num: mitLOL210612164841 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-16 type jnj W TVD 6733 - Tubing 2525 2525 _ 2525 _ 2525 - PTD 1990940 Type Test, SPT Test psi 1683 IA 545 1900 1870 1870 - - BBL Pumped: 1.2 ---- BBL Returned: 1 1.2 - OA 780 780 - 780 780 Interval avRTST p/F Notes: Thursday, June 17, 2021 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg P.I.Supervisor Teri f(2-1)7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-16 FROM: Bob Noble COLVILLE RIV UNIT CD1-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-16 API Well Number 50-103-20306-00-00 Inspector Name: Bob Noble Permit Number: 199-094-0 Inspection Date: 6/10/2017 Insp Num: mitRCNI70612081905 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-16 Type Inj W' TVD 6733 ' Tubing 2400 - 2400 2400 ' 2400 PTD 1990940 - Type Test SPT Test psi 1683 IA I 540 1900 1870 - 1870 BBL Pumped: 1.1 BBL Returned: 1.1 - OA 840 840 840 840 ' Interval 4vRTST P/F P f Notes: SCANNED AUG 2'2 2017, Monday,June 19,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission r7 DATE: Tuesday,June 18,2013 TO: Jim Regg hee l (v vl 13 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-16 FROM: Jeff Turkington COLVILLE RIV UNIT CDI-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,.Y- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-16 API Well Number 50-103-20306-00-00 Inspector Name: Jeff Turkington Permit Number: 199-094-0 Inspection Date: 6/12/2013 Insp Num: mitJAT130614192425 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-16 T yp e W TVD 6733 In' � IA 350 2030 • 1975 1975 • J I � PTD 1990940 • Type Test SPT Test psi 1683 OA 840 840 840 840 Interval 4YRTST P/F P Tubing 2525 2525 2525 2525 Notes: 1.3 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of 1 u MEMORANDUM To: Jim Re ~j~ / P.I. Supgrvisor ' l~~ ~l Z~'~~ ~ FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-16 COLVILLE RIV UNIT CD1-16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I.Suprv ~~Sl~- Comm Well Name: COLVILLE RIV iJNIT CD1-16 Insp Num: mitRCN090617212459 Rel Insp Num: API Well Number: 50-103-20306-00-00 Permit Number: 199-094-0 / Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ CDI-16 Type Inj. W 7'~ 6732 / IA 50 2480 2430 2430 P.T.D 1990940 TypeTest SPT Test psi 2480 - QA 770 780 780 780 Interval 4YRTST P~ P ;j Tubing 1894 1894 1894 1894 Notes: ~ ~ ..~,~,.1~ ~~~~U» I 6~~~s`i . ~a=~!~~ . ~i~,:~ =i ~, ws~.~ ~ ~ :.~...~ '-=, i_I i ; ~ Ut r:i Monday, June 22, 2009 Page 1 of 1 r: ~'C?iANICAL INTEGRITY R :PORT - t~~, -~~~ 1~1~ - ~~ oPER ~ F~FLn L~~L C.~~.:~.~\~ ~..~t~ _._C t .i.. :, _. r_.. .., - _~~'~ T-/~,~ KILL Nln"f$ER 1,.~~ _ \ Y~ ~n~ LL DATA T~3 .~~.?~}.. TVD ; . BTD . ~ ?~ T'VD ~~ .- - Lc,SII:~ : ~ SIZOt? : `"~Lj' ~~ ~} TVD ; LV : ?"~ •'T"L1`7 ~_ae_ . ~~+ Shoe . ~ ?'`JT ; ~'Cr . ?•~ '~J =uoi='~ ~l~ ~. P2CiCer ~t5 ?~ TV~D; SeL nt `t~~ ole S_~e ~~ and t erfs ~3pte. v\ to ~;\,k ~ ~ ~ "~' ~3t~~CJ C'r'...PN;~"~~ itTTEGR~"TY - ~a,Rfif~:~~~~v ~.~ Z~Q7 rn::u~.us ?ress Test: lP ?5 ain ~4 min Corments : __~~~c ss~~-~, M.~~~ ~'i`:~._~ 1 ~r` r'1°_~l5' r ~*'CH.~NIC~, ~., Ii4TEGRI'?'~ -PAR?' # 2 ~ ~-~~`'~~ Cement Volumes :-- x~snt_ Liner Csg ~~L S~ ; DV ti~ cwt Jol to cover aer~s C. ~~~~~ ~'~ r~ ~~~`> ~~c~~~~; ~,~~ _..eoretical T_OC _ ~ ~j~~e `~~ ~~(~, ~~ ~ ~ ~U~v .~ Cement Bond Log (Yes or No) \~_; In AOGCC File - L CBL Evaluation, cone shove perfs 'x~~~\~`'c'~c~ ~~,~ ,~_~ \ Production Log: Type_ _ P.valcati on coN~LJS ~ oi3s ?art i 1 ?ar~ 12: • Alpine Field CD1-161njection Well Completion 16" Conductor to 114' 4-112" Cameo "A-1" SSSY (2.125" ID) DB-6 Lock (3.812" ID) @ 1,757` MD/1,678'SS 9-5l8" 36 ppf J-55 8TC Surface Casing 2628' MD/ 2354' SS cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. #ubing (Jet Lube Run'n'Seal) AP150-103-20306-00 Packer Fluid mix: 9.6 ppg KCI Brine with EC-1124A and 2150' ! 2010' SS diesel cap Plug S#atus SSSV -out XN -all plugs puffed Wellbore open 1213/99 TOC +/- 8600' 1 -Baker S-3 Packer (3.875" lD) @ 8898' MDl6688'SS 2 - 4-1/2" joints (2) blank tubing 3 - HES "XN" (3.725" ID) LN @ 8974' MDl6730' SS 4 - 4-1/2" joint tubing 5 - 4-1/2" WLEG EOT @ 9008'MD/6746'SS ~N 6-1/8" Openhole to TD @ 12,600' MD / 6903' SS 7" 26 ppf L-80 BTC Mod Production Casing @ 9,595' MD16998` SS wi#h Best-o-Life thread compound l)ndated 11/23/99 . . ConocðPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 99501 r '1· {} 1.007 SCí~NSJ Þ,? 1[\ . a 4- \ qqAh Dear Mr. Maunder: -, -~Ìi Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fomi 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs . ConocoPhillips Well Irttegrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 ) ) MEMORANDUM State of Alaska TO: Jim Regg P.I. Supervisor ~q '11,~c< Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-16 COLVILLE RlV UNIT CDl-16 (}c....o C{tt \ "\ ~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv SbL- Comm Well Name: COLVILLE RIV UNIT CD1~16 Insp Num: mitCSOS0906181011 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-103-20306-00-00 Permit Number: 199-094-0 Inspector Name: Chuck Scheve Inspection Date: 9/4/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~r::~~~i~f:~~~f~¡-:-~:-~~ --' J._ ._....L_ ]-------J.-:---j------I--------+-------.--------~------d--r. --.------ Interval 4YRTST PIF P Tubing I 3388 ; 3388 1 3388 [ 3388; ] ________.________.___._______._____._ __________._______.__._______~_.__.__L____.__ _._ . _______L_._.___ Notes Pretest pressures were observed for 30+ minutes and found stable. SÇ/\NNE~} SEP ? 1 20fJ:'¡ Wednesday, September 07,2005 Page 1 of 1 ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 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 by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement -- CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI 8.5 CD1--~ 7.33' 1 -'P ' 6.0 CD1-5 4' 0.6 MI 3.6 "CD1-6 10.42'-- 1.4 Gl 8.5 CD1-16 14.33' -2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CDi122 1.83' 0.3 P 1.8-- CD1-23 15.42' 2.1 MI 12.7 , CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 · __ CD1-27 18.83' 2.6 P 15.7 CD1-28 ........ -~'¢'5~ .......... 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 .. CD1-38 3.5' 0.5 P 3.0 -C-D-~i~- .......... -~i~-3r ..... 0.8 MI ..... 4.8 C~-~-16 ..... :1";[i~-~; ...... 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 ~ 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 C D2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 Alpine Cement Top Fill Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips CC: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the weft numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks/. > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 ofz '- 4/24/2003 7:55 AM /Alpi~e bement lop Pill Name: AOGCC ALPINE cement top outs 04-16-03.xls j AOGCC ALPINE cement top outs 04-16-03.xls: Type: EXCEL File (application/msexcel) J Encoding' base64 r'-~Cement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 AM PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total.volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular Injection during, the second quarter of 2000: h(1)' h(2)' h0) Totaifor Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~ 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 Z 9 2002 Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired durin$ the fourth quarter 2000: " ;I'otal ' - Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected /:?-//7 Please call me at 263-4603 should yoU have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files 199-094-0 COLVILLE RIV UNIT CDI-16 '50- 103~20306-00 PHILLIPS ALASKA INC Roll Itl: Start: Stop Roll #2: Start Stop MD 12600 TVD 06948 Completion Date: ~f'6/23/99~ompleted Status: WAGIN Current: T Name C 9371~''/' C 9372~'"'" L AND-MD L AND-TVD CDR-MD L CDR-MD L CDR-TVD L CDR-TVD L Cement Bond w/SCMT R SRVY CALC R SRVY CALC R SRVY RPT R SRVY RPT Interval Sent Received T/C/D 4 SCHLUM CDR/ADN 2,3 SCHLUM CDPdADN PB1 ~XL 5069-9312 PBI o,,"F~AL 4100-7000 PB1 ,..~n~AL 2600-12550 t~I;1NAL 2628-9312 PB1 w,'F1NAL 2400-6900 ,..,"F'INAL 2400-7000 PB1 OH OH OH 2/5 OH 2/5 OH 2/5 OH 2/5 OH 2/5 OH 2/5 b-'9~00-9330 Color Print ~" CH t,,,BHI 8348.56-12600 OH /,,'BHI 0-9357. PB1 OH ~CHLUM 115-9357. PB1 OH t,,,/SCHLUM 115-12600. PB1 OH 11/24/99 11/30/99 11/30/99 11/30/99 11/30/99 11/30/99 11/30/99 11/30/99 11/24/99 11/30/99 11/30/99 11/30/99 11/24/99 11/30/99 11/30/99 11/30/99 11/30/00 1/3/01 11/9/99 11/12/99 11/9/99 11/12/99 10/18/99 10/21/99 10/22/99 11/12/99 Tuesday, September 25,2001 Page 1 of 1 MEMORANDUM State of nia~ka Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~{.- \~?' DATE: March 30, 2001 Chairman ~:J~~--~' ~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips P.I. Supervisor CDt AIpine tA, [~-O \ Colville River Unit FROM: Chuck Scheve Alpine Petroleum Inspector NON- .C. PNFI[~. N.TIAL ' . l W~'l Cm~l I" P'T'D'i '199'046 /, N,o,~: J Notes: . P.T.D:I 1~20 i Notes: ,..P:T.9.I Notes: .'W~.q , P.T.D:I 2~2 No~s: P.T.D.I 19~52 No~: . Packer Depth .. ,Pretest i,n,it~,l, , 15 Min. 3,0.Min. ,., , I T~ ~.j:l sW .l T-v.D-_! ~5.1. ?UUng'l 45O I 450 I 4~0 / 4~0 ~lln~erva~l i. I I ,'r¥.m,testl., P !TestpsiI 172!! ca~ing i 350 ! 2ooo. l 2ooo i 2ooo i P/F !. I 'lTym'.'i;l"'s 'l'T.g.b.'! 6824'JTl~bin~'l' 5q J' 50"1' 5~ 'l 50 IType.~..il ' P, JTestpsiJ '~7C~ J'cas'ingl 0 ! qgr'~, i~9~-I lg50i ~;~' '1-P ' 'w'~,,I 'Cra-lA I Tym,nj.l' s '! T-{/-D-'! 6'~§3 ITub, in~]J 450 I 450'_1 450' I ';t50 !,,~,~1 ~' N~s: J wa,I' CD1-19 I Ty~lnj. I ' n' I T.V.D. I ~20'. I ~u~g i' 220d I =~! 22~"1 =~ I'n~l-~' [ P;T.B:I",5~g IT~tJ,P'IT"trail '~,JC~ingl' 0 I ~ I !9~ i.~1 P~ I'E J Noms: Class 2 dispo~l well J "W~IJ CD1-23IT~I~j.'J N'1 ~.V.D. I ST~ ! TuU.g I ' 2~ I 2S0 t'2~ .... J 2~l,~a~t ~ ' ! P.T.D.J"~9~.3~J.Ty~tJ p .JT~tmiJ 1~ JC~ingl o I ~01 ~! ~ I' P~ ! ~ J N°ms: This w~J fail~ a .previous t~t Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER tNJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Terrkoerature ~a~ Survey D= Differentia~ Temperature Test l~tervat i= Initial Test 4= Four Year Cycle v= Required byVariance W= Test dudng Workover o= Other (desc~be ~n notes) Test's Details I traveled to the Phillips Alpine location and witnessed the ~n ~'cctjon wells. All pretest pressures were observed for 1 hour+ while waiting for pumping equipment to arrive and were found to be stable. A standard annulus pressure test was then performed with alt 9 wells demo~~mechanical integrity~.,. M.I.T.'s pertormed: 9 Attachments: Number ot Failures:: 0_ Total Time during tests: 7_. MIT report form 5/12100 L.G. 010330-MIT Alpine-CS 41410t PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. Annular Disposal during the fourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681 7~oo- o55' zoo - 1-5 o 135' Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD 1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files Re: CD1-16 bond log Subject: Re: CDl-16 bond log Date: Fri, 01 Dec 2000 12:50:18 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Michael D Erwin <MERWIN@ppco.com> Mike, Thanks for the log. Yes, I concur that the portion of the well that was logged does show good cement. Pity that the tool couldn't be coaxed to fall a little further since by the depths in the completion log the tool got essentially to the top of the Alpine. No reason to believe that the cement quality is any different in the intervals not imaged. Thanks. Tom Michael D Erwin wrote' Tom, Please find attached below the PDS file for our rr~st recent cement bond log. >From what I see, it's evident the cement bond job is more than adequate for injection isolation on this well. The well logged is CD1-16. It was not logged initially due to conflicts, and then the Pulse Test caught it, and for the past several months the rig has blocked it. We finally caught a time when it was uncovered and the logging crew was available. I also attached a weft schematic. If you would let me know your thoughts on this log I would appreciate it. The dated info may not be correct but the depths and hardware should be. According to my notes, there is only 1 other injection well lacking a log prior to commencing injection. That weft is 1-26 and it needs a WFL log since it's bong log was considered inconclusive. mike (See attached file: CD1-16 Schematic. doc) Fomarded by Michael D Erwin/PPCO on 11/29/2000 03:33 PM Ken Clasper <clasperkl@slb.com> on 11/26/2000 08:53:16 PM To: Michael D Erwin/PPCO@Phillips cc: Michael Kasecky/PPCO@Phillips Subject: CD1-16 bond log Please see the attached PDS file from this weekend's logs. (See attached file: Scmt-fnl. pds) Ken Clasper Senior Field Engineer Resevoir Evaluation - Wireline Prudhoe Bay, Alaska (907) 659-2487 (907) 659-2486 (fax) ~ ,.¢~ 12/1/00 12:52 PM ARCO Alaska, Inc. -~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendv Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: CF!VED Cons. Commission Anch0rag0 ' Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the fourth quarter of 1999. Annular b~jection during the fourth quarter of 1999: h(1) I h(2) h(3) Total for Previous i New Well Name Volume Volume Volume Quarter Total ~ Total CD1-37 15214 100 0 15314 17273 32587 CD1-39 27391 100 0 27491 4017 31508 1D-12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 0 29025 CD1-32 7449 100 0 7549 0 7549 CD1-03 285 100 0 385 0 385 CD1-42 287 100 0 387 0 387 CD1-40 20 0 0 20 32649 32669 CD1-45 274 100 0 374 0 374 CD1-36 293 100 0 393 0 393 CD1-35 217 100 0 317 0 317 CD1-23 20 0 0 20 17085 17105 CDI-13 89 100 0 189 0 . 189 CD1-01 20 0 0 20 5201 I 5221 I Total Volumes into AnnuIi for which b~jection Authorization Expired during the fourth quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus · 2N-315 25326 100 0 25426 Open, Freeze Protected i 2L-329A 33971 100 0 34071 Open, Freeze Protected i 2L-325 20280 100 0 20380 ~ Open, Freeze Protected 2L-313 12433 100 0 12533 ! Open, Freeze Protected , I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 199-94 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20306-00/50-103-20306-70 4. Location of well at surface i !?_i',;.~'.'; I~' !:'~;: i ' .-- 9. Unit or Lease Name 330' FNL, 2468' FWL, Sec. 5, T11N, RSE, UM ! ,,~.~_.~ ~ Colville River Unit At Top Producing Interval 10. Well Number 2130'FNL, 2617'FWL, Soc-4, TllN, RSE, UM i ~__~ ir CDl-le&CDl-lePBl · - '- ;_i 11. Field and Pool 286' FSL, 1109' FEL, Sec. 4, T11 N, R5E, UM Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. Alpine Oil Pool RKB 37' feetI ADL 372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if off'shore 16. No. of Completions October 5, 1999 October 21, 1999 October 23, 1999 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12600' MD/6948' TVD 12600' MD/6948' TVD YES [] No []I N/A feet MD 858' MD 122. Type Electric or Other Logs Run GR/Res/Neut/Dens OR - '""AL SE'I-I-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOq-I-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2629' 12.25" 425 sx AS III LW, 234 sx Class G 7" 26# L-80 Surface 9596' 8.5" 140 sx Class G CD1-16 PB1 cement plug dressed off to 8396' to start CD1-16 sidetrack 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9008' 8898' open hole completion from 9595'-12600' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9357'-8850' Plug #1' 197 sx 15.8 ppg Class G 8850'-8284' Plug #2:227 sx 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Plant Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 124-Hour Rate > , w~ ~'~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ~1~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME CD1-16 PB1 Top Alpine Base Alpine CD1-16 Top Alpine TD GEOLOGIC MARKERS MEAS, DEPTH TRUE VERT. DEPTH 9126' 9217' 9331' 12600' 6910' 6977' 6909' 6948' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Robertson 265-6034 Signed /~,4.,.~..~~/~¢~,4_.¢ ~..~.1. _ ~./'~~ ' Title Alpine Drilling Team Leader Do~o~hester INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 11/03/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CDi-16 WELL_ID: 998B14 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:10/05/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20306-00 10/05/99 (D1) TD/TVD: 1315/0 SUPV:DONALD LUTRICK MW: 8.6 VISC: 200 PV/YP: 8/50 (1315) DRLG APIWL: 20.0 Move rig from CD1-26 to CDi-16. Accept rig ~ 0600 hrs. 10/5/99. Held pre-spud meeting. Function test diverter. Drilling from 114' to 1315' 10/06/99 (D2) MW: 9.7 VISC: 180 PV/YP: 10/51 TD/TVD: 2638/2406 (1323) RU TO RUN CSG SUPV:DONALD LUTRICK APIWL: 8.5 Drilling from 1315' to 1451' CBU. Wiper trip to DC's. No problems. Break circ. Survey. Seat washed out in #2 pump. Replace center seats in #2 pump. Drilling from 1451' to 1842' Change liner and swab in %2 pump. Drilling from 1842' to 2404' Change swab in #1 pump. Drilling from 2404' to 2638'. Circ and condition mud. POH to 1936' Pumped out from 2350' due to swabbing. 10/07/99 (D3) MW: 9.6 VISC: 45 PV/YP: 8/20 APIWL: 8.6 TD/TVD: 2638/2406 ( 0) MU BHA SUPV:DONALD LUTRICK PJSM. RIH w/9-5~8" casing. Pump viscosified water w/med nut plug. Pump cement. ND diverter. Nil BOPE. 10/08/99 (D4) MW: 9.7 VISC: 44 PV/YP: 10/28 APIWL: 6.8 TD/TVD: 3138/2752 ( 500) WIPERTRIP AT 3644' SUPV:DONALD LUTRICK NU BOPE and test to 300/3500 psi. Drill out cement, FE and 20' new formation to 2658' Perform FIT. Drill 30' to 2688'. Perform FIT. Drilling from 2688' to 3138' 10/09/99 (D5) MW: 9.8 VISC: 45 PV/YP: 12/30 TD/TVD: 5168/4143 (2030) DRLG AT 5700 SUPV:DONALD LUTRICK Drilling from 3138' to 5168' APIWL: 5.0 10/10/99 (D6) MW: 9.8 VISC: 45 PV/YP: 11/26 TD/TVD: 7283/5616 (2115) DRLG SUPV:DONALD LUTRICK Drilling from 7187' to 7283' APIWL: 4.5 Date: 11/03/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/11/99 (D7) TD/TVD: 9357/7080 SUPV:DONALD LUTRICK MW: 9.8 VISC: 42 PV/YP: 10/24 2074) POH APIWL: 4.7 Drilling from 7283' to 9355' Circ sweep. Wipertrip to 7072'. Pump out 8420' to 7560'. Tight and swabbing. 10/12/99 (D8) TD/TVD: 9357/7080 SUPV:DONALD LUTRICK MW: 9.9 VISC: 45 PV/YP: 10/24 0) RIH W/ SIDETRACK BHA APIWL: 4.5 Wipertrip to 7072' Pump out 8420' to 7560'. PJSM. Pump cement to balance plug. Circ out cement contaminated mud. Pump cement to balance plug. Circ out cement contaminated mud. 10/13/99 (D9) MW: 9.8 VISC: 45 PV/YP: 12/28 APIWL: 5.1 TD/TVD: 8746/6638 0) DRILLING AHEAD AT 8965' SUPV:MIKE WHITELEY / BRIAN ROBERTS0 Wash and ream from 8015' to 8331' Drill cement from 8331' to 8396' Time drill and kick off cement plug from 8396' to 8436' Drill from 8436' to 8746' 10/14/99 (D10) TD/TVD: 9398/6926 SUPV:MIKE WHITELEY MW: 9.7 VISC: 43 PV/YP: 10/31 652) CIRC FOR SHORT TRIP - TD'D AT 9,605' APIWL: 4.3 Drill from 8746' to 9153'. Kick drill. Circ for wiper trip. Made wiper trip to 7915', tight, pump and back ream out from 8356'-8200'. RIH, no problems. Drill from 9153' to 9398'. No problems. 10/15/99 (Dll) TD/TVD: 9605/6948 SUPV:MIKE WHITELEY MW: 9.7 VISC: 44 PV/YP: 9/27 APIWL: 4.0 207) CIRC AND COND MUD AND HOLE FOR CEMENT JOB Drill from 9398' to 9605' Wiper trip to 7915' PJSM. Run 7" casing. 10/16/99 (D12) TD/TVD: 9605/6948 SUPV:MIKE WHITELEY MW: 9.7 VISC: 41 PV/YP: 9/23 0) DRILL OUT CEMENT / FLOATS APIWL: 10.6 Finish running 7" casing. Circ and condition mud for cement job. PJSM. Pump cement. Test BOP's to 250/3500 psi. No leaks. Ran LOT. 10/17/99 (D13) TD/TVD:10034/6947 SUPV:MIKE WHITELEY MW: 9.2 VISC: 49 PV/YP: 9/30 429) DRILLING AHEAD AT 10,270' APIWL: 4.2 Wash to 9500' Drill out plugs, F.C., cement and shoe at 9595' Drill 20' new hole to 9625' Ran FIT, 12.5 ppg EMW. PJSM, spill drill. Displace hole with 9.2 ppg Flo-Pro mud. Drill from 9625' to 10034' Date: 11/03/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 10/18/99 (D14) MW: 9.2 VISC: 48 PV/YP: 10/28 APIWL: 4.0 TD/TVD:10815/6946 (781) DRILLING AHEAD AT 11,060' SUPV:MIKE WHITELEY Drill from 10034'-10615', hard to slide at 10520' Circ for short trip, pump sweep around. Made wiper trip to 9550', pumped and back reamed out. No problems. Drilled from 10615' to 10815'. 10/19/99 (D15) MW: 9.1 VISC: 49 PV/YP: 12/36 TD/TVD:l1514/6942 ( 699) WIPER TRIP FROM 11,659' TO SHOE SUPV:MIKE WHITELEY APIWL: 4.0 Drill from 10815' to 11142' Circ hole clean and condition mud to lower ECD from 11.2 ppg to 10.9 ppg. Drill from 11142' to 11514' Hard to slide at 11172' to 11184' and 11240'-11265' Pumped med nut plug pill at 11340'.. Good slides at 11340'-11367' and 11510'-11530' after pumping LCM sweep. Spill drill/fire drill. 10/20/99 (D16) MW: 9.2 VISC: 61 PV/YP: 14/43 TD/TVD:12303/6946 (789) DRILLING AHEAD AT 12,525' SUPV:MIKE WHITELEY APIWL: 4.0 Drilling from 11514' to 11659' Finish circ out sweeps. Made wiper trip to 10524' Pump and back ream out, no problems. Drill from 11659'-12027'. Circ hole clean to lower ECD from 11.4 ppg to 11.15 ppg. Drill from 12027' to 12303' Unable to slide at 12080'-86' Drilled to 12130' Pumped LCM sweep around, no problem making slide after pumping LCM sweep. Hole started seeping at 12200', 7 bph mud loss, ECD'S - 11.5 ppg. Pump sweeps around and circ to lower ECD from 11.5 ppg. 10/21/99 (D17) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12600/6948 (297) POOH LAYING DOWN 3.5" DP - LOSS RATE AT 0530 HRS - 16 SUPV:MIKE WHITELEY Drill from 12303'-12600', hole seeping, lost total 75 bbls mud. Pump sweeps around and circ clean for wiper trip. Made wiper trip to 9527', pumped and back reamed out, no problems. Displace well with 9.2 ppg KC1 water, pumped 50 bbls high vis spacer, 600 bbls 9.2 ppg KC1 water. Observe well, loss rate 60+ bbls/hr. POOH. Spot LCM pill. 10/22/99 (D18) TD/TVD:12600/6948 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 26 PV/YP: 0/ 0 0) SET PACKER / TEST TUBING APIWL: 0.0 Finish spotting LCM pill out bit at 9535'. POOH, LD 3.5" drill pipe. PJSM. Run 4.5" tubing. Packer set at 8897'. ND BOP's. Nil tree and test to 250/5000 psi. 10/23/99 (D19) TD/TVD:12600/6948 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 26 PV/YP: 0/ 0 0) RELEASED RIG AT 08:30 HRS 10-23-99. APIWL: 0.0 PJSM. Freeze protect well. Set packer at 8897' Release rig 0830 hrs. 10/23/99. " SURVEY CALCULATION AND FIELD wORKSHEET Job No. 0451-08304 Sidetrack No. Page 1 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/16 PB1/16 Survey Section Name 26 PB1 MWD PHI Rep. MILCHAK/NEWLON ~l"r~i~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[--] SS[~ Target Description Target Coord. E/W Slot Coord. E/W 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft~ 30m~ 10m~] Vert. Sec. Azim. 106.84 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) {DD) (DD) (FT) (FT) (FT) (FT) (Per 100 F-r) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 05-OCT-99 MWD 115.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 9 1/2" MlC 1.4 DEG AKO 05-OCT-99 MWD 201.24 0.78 114.94 86.24 201.24 0.58 -0.25 0.53 0.90 0.90 05-OCT-99 MWD 290.71 1.70 116.32 89.47 290.69 2.49 -1.09 2.27 1.03 1.03 05-OCT-99 MWD 381.71 3.14 116.49 91.00 381.60 6.28 -2.80 5.71 1.58 1.58 05-OCT-99 MWD 470.97 4.31 116.98 89.26 470.67 11.99 -5.42 10.89 1.31 1.31 05-OCT-99 MWD 562.37 5.93 113.24 91.40 561.70 20.07 -8.84 18.29 1.81 1.77 -4.09 05-OCT-99 MWD 652.10 6.32 112.90 89.73 650.92 29.58 -12.59 27.10 0.44 0.43 -0.38 '05-OCT-99 MWD 743.18 7.18 113.66 91.08 741.37 40.22 -16.82 36.93 0.95 0.94 0.83 05-OCT-99 MWD 833.10 8.02 108.74 89.92 830.50 52.07 -21.09 48.02 1.18 0.93 -5.47 05-OCT-99 MWD 922.94 8.55 111.19 89.84 919.40 64.99 -25.52 60.18 0.71 0.59 2.73 05-OCT~99 MWD 1011.73 8.81 111.18 88.79 1007.18 78.35 -30,36 72.68 0.29 0.29 -0.01 i 05-OCT-99 MWD 1106.98 8.79 110.59 95.25 1101.30 92.89 -35.56 86.29 0.10 -0.02 -0.62 i 05-OCT-99 MWD 1202.37 10.81 109.77 95.39 1195.30 109.10 -41.15 101.53 2.12 2.12 -0.86 ~, . 06-OCT-99 MWD 1297.51 13.88 109.54 95.14 1288.23 129.41 -47.98 120.69 3.23 3.23 -0.24 06-OCT-99 MWD 1391.45 14.55 107.66 93.94 1379.29 152.47 -55.33 142.55 0.87 0.71 -2.00 06-OCT-99 MWD 1486.19 16.95 107.04 '94.74 1,470.47 178.18 -62.99 167.10 2.54 2.53 -0.65 i 06-OCT-99 MWD 1581.36 19.41 107.32 95.17 1560.88 207.87 -71.76 195.46 2.59 2.58 0.29 __ -- 06-OCT-99 MWD 1675.52 22.01 106.58 94.16 1648.95 241.17 -81.46 227.31 2.78 2.76 -0.79 06-OCT-99 MWD 1770.80 25.46 106.69 95.28 1736.15 279.51 -92.44 264.05 3.62 3.62 0.12 -- 06-OCT~99 MWD 1866.43 29.14 106.61 95.63 1821.12 323.36 -105.00 306.07 3.85 3.85 -0,08 06-oCT-99 MWD 1961.56 33.15 106.10 95.13 1902.52 372.55 -118.84 353.27 4.22 4.22 -0.54 -- 06-OCT-99 MWD 2056.67 36.70 105.99 95.11 1980 49 426.99 -133.89 405.60 3.73 , 3.73 -0.12 06-OCT-99 MWD 2152.31 39.40 106.21 95.64 2055.80 485.93 -150.24 462.22 2.83 2.82 0.23 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08304 Sidetrack No. Page 2 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co.- #19 Field ALPINE Well Name & No. CD#1/16 PB1 / 16 Survey Section Name 26 PB1 MWD BHI Rep. MILCHAK/NEWLON J~lilr~"~l~ WELL DATA Target TVD (F-D Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SS~ Target Description Target Coord. F_JW Slot Coord. E/VV 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 106.84 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'r) (FT) (F'P/ (F'I~ (Per 100 FT) Drop (-) Left (-) 06-0CT-99 MWD 2247.08 42.39 107.15 94.77 2127.43 547.96 -168.06 521.65 3.22 3.16 0.99 _. -- 06-0CT-99 MWD 2344.17 45.08 107.14 97.09 2197.57 615.07 -187.84 585.78 2.77 2.77 -0.01 -- 06-0CT-99 MWD 2440.32 44.82 107.30 96.15 2265.62 683.00 -207.95 650.66 0.29 -0.27 0.17 06-0CT-99 MWD 2533.78 44.54 107.48 93.46 2332.07 748.71 -227.59 713.37 0.33 -0.30 O. 19 06-0CT-99 MWD 2578.86 44.40 107.81 45.08 2364.24 780.29 -237.16 743.47 0.60 -0.31 0.73 08-0CT-99 MWD 2711.08 45.85 107.77 132.22 2457.53 873.97 -265.79 832.68 1.10 1.10 -0.03 6 3/4" M1XL 1.2 DEG AKO 08-0CT-99 MWD 2805.93 46.31 107.46 94.85 2523.32 942.29 -286.46 897.80 0.54 0.48 -0.33 08-0CT-99 MWD 2901.21 46.07 106.96 95.28 2589.28 1011.04 -306.81 963.48 0.45 -0.25 -0.52 08-0CT-99 MWD 2994.92 46.86 107.73 93.71 2653.83 1078.98 -327.06 1028.32 1.03 0.84 0.82 . 08-0CT-99 MWD 3091.43 46.69 107.19 96.51 2719.93 1149.30 -348.16 1095.41 0.44 -0.18 -0.56 09-0CT-99 MWO 3187.11 46.48 106.79 95.68 2785.68 1218.80 -368.47 1161.87 0.37 -0.22 -0.42 09-0CT-99 MWD 3282.31 46.29 106.11 95.20 2851.36 1287.72 -387.99 1227.98 0.55 -0.20 -0.71 09-0CT-99 MWD 3376.47 46.14 107.16 94.16 2916.51 1355.69 -407.45 1293.11 0.82 -0.16 1.12 09-0(~T-99 MWD 3472.67 46.06 106.55 96.20 2983.22 1425.01 -427.55 1359.45 0.46 -0.08 -0.63 -- 09-0CT-99 MWD 3568.32 45.94 106.81 95.65 3049.66 1493.81 -447.30 1425.35 0.23 -0.13 0.27 09-0CT-99 MWD 3663.58 45.59 106.08 95.26 3116.11 1562.06 -466.62 1490.81 0.66 -0.37 -0.77 09-0CT-99 MWD 3759.62 46.13 106.24 96.04 3183.00 1630.98 -485.80 1557.01 0.57 0.56 0.17 09-0CT-99 MWD 3854.72 46.24 106.36 95.10 3248.84 1699.60 -505.06 1622.88 O. 15 O. 12 0113 -- 09-0CT-99 MWD 3949.97 46.04 105.55 95.25 3314.84 1768.27 -523.94 1688.91 0.65 -0.21 -0.85 09-0CT-99 MWD 4045.23 45.76 105.54 95.26 3381.13 1836.66 -542.27 1754.81 0.29 -0.29 -0.01 _._ 09-0CT,99 MWD 4141.02 47.19 106.97 95.79 3447.10 1906.11 -561.72 1821.48 1.84 1.49 1.49 -- 09-0CT-99 MWD 4235.67 47.15 106.93 94.65 3511.44 1975.52 -581.96 1887.88 0.05 -0.04 -0.04 09-0CT-99 MWD 4330.45 47.34 106.38 94.78 3575.79 2045.11 -601.91 1954.56 0.47 . 0.20 -0.58 09-0CT-99 MWD 4426.61 47.57 106.96 96.16 3640.81 2115.96 -622.23 2022.42 0.50 0.24 0.60 i SURVEY CALCULATION' AND FIELD WORKSHEET Job No. 0451-08304 Sidetrack No. Page 3 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/16 PB1 / 16 Survey Section Name 26 PB1 MWD BHI Rep. MILCHAK/NEWLON ~lr~'~~ WELL DATA Target TVD CT) Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS[-] Target Description Target Coord. E/W Slot Coord. E/W 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (Dp) Buil~Walk\DL per: 10Oft~ 30m~] lOmE~ Vert. Sec. Azim. 106.84 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FO (F'F) (F'I~ (FI') (Per ~00 FO Drop (-) Left (-) 09-OCT-99 MWD 4521.99 47.62 106.70 95.38 3705.13 2186.39 -642.62 2089.84 0.21 0.05 -0.27 ,' 09-OOT-99 MWD 4616.47 47.61 106.33 94.48 3768.82 2256.17 -662.46 2156.74 0.29 -O.01 -0.39 ., 09-OCT-99 MWD 4711.71 47.52 106.62 95.24 3833.08 2326.46 -682.39 2224.15 0.24 -0.09 0.30 09-OOT-99 MWD 4807.00 47.53 107.14 95.29 3897.43 2396.74 -702.80 2291.40 0.40 0.01 0.55 ...... 09-OOT-99 'MWD 4901.76 47.47 106.66 94.76 3961.45 2466.61 -723.11 2358.25 0.38 -0.06 -0.51 0~-OOT-99 MWD 4996.44 47.23 107.04 94.68 4025.59 2536.24 -743.29 2424.90 0.39 -0.25 0.40 09-OOT-99 MWD 5091.85 46.86 106.64 95.41 4090.61 2606.07 -763.52 2491.73 0.49 -0.39 -0.42 10-OCT-99 MWD 5207.18 46.20 107.21 115.33 4169.95 2689.77 -787.89 2571.80 0.68 -0.57 0.49 10-OOT-99 MWD 5302.95 45.69 107.70 95.77 4236.55 2758.59 -808.53 2637.46 0.65 -0.53 0.51 10-OOT-99 MWD 5398.10 45.09 106.10 95.15 4303.37 2826.33 -828.23 2702.27 1.35 -0.63 -1.68 10-OCT-99 MWD 5492.59 47.24 107.43 94.49 4368.81 2894.48 -847.90 2767.52 2.49 2.28 1.41 10-OOT-99 MWD 5588.11 46.80 107.23 95.52 4433.93 2964.36 -868.72 2834.23 0.49 -0.46 -0.21 10-OCT-99 MWD 5683.11 46.56 106.76 95.00 4499.11 3033.47 -888.92 2900.33 0.44 -0.25 -0.49 10-OCq'-99 MWD 5778.14 46.26 106.72 95.03 4564.63 3102.30 -908.74 2966.24 0.32 ,0.32 .0.04 i'. \ 10-OCT-99 MWD 5873.22 46.03 106.21 95.08 4630.51 3170.86 -928.18 3031.99 0.46 -0.24 -0.54 10-OCT-99 MWD 5968.90 45.59 106.16 95.68 4697.20 3239.46 -947.30 3097.87 0.46 -0.46 -0.05 10-OCT-99 MWD 6063.77 45.24 105.24 94.87 4763.79 3307.01 -965.58 3162.92 0.78 -0.37 -0.97 10-oCT-99 MWD 6159.30 44.79 106.13 95.53 4831.33 3374.57 -983.85 3227.97 0.81 -0.47 0.93 10~OOT-99 MWD 6254.92 45.77 108.50 95.62 4898.61 3442.50 -1004.08 3292.82 2.04 1.02 2.48 , , 10-OCT-99 MWD 6349.81 44.87 108.80 94.89 4965.34 3509.93 -1025.65 3356.75 0.97 -0.95 0.32 10-OCT.99 MWD 6445.48 44.33 109.01 95.67 5033.45 3577.06 -1047.42 3420.30 0.59 -0.56 0.22 1 O-OCT-99 MWD 6540.77 46.39 108.63 95.29 5100.41 3644.82 -1069.28 3484.47 2.18 2.16 -0.40 1 O-OCT-99 MWD 6636.48 45.69 107.77 95.71 5166.84 3713.70 -1090.80 3549.92 0.98 .-0.73 -0.90 10-OCT-99 MWD 6731.58 45.12 107.75 95.10 5233.61 3781.41 -1111.46 3614.41 0.60 -0.60 -0.02 SURVEY CALCU LATION AND FIELD WORKSHEET Job No. 0451-O8304 Sidetrack No. Page 4 of 5 '_ [1[~-' I Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/16 PB1 / 16 Survey Section Name 26 PB1 MWD BHI Rep. MILCHAK / NEWLON ~~/~1~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord, N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL~ SS~ Target Description Target Coord, E/W Slot Coord. EJW 2468,00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (oD) Buil~Walk\DL per: 100ft~ 30m0 10m[-] Vert. Sec. Azim. 106.84 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type p-r) (OD) (DD) (FT) (FT) (FT) (F'I') (Per 100 FT) Drop (-) Left (-) 10-OCT-99 MWD 6825.70 46.74 107.78 94.12 5299.07 3849.02 -1132.09 3678.81 1.72 1.72 0.03 , 10-OCT-99 MWD 6920.76 46.27 107.25 95.06 5364.50 3917.97 -1152.85 3744.57 0.64 -0.49 -0.56 1~-OCT-99 MWD 7016.07 45.91 107.34 95.31 5430.60 3986.64 -1173.26 3810.13 0.38 -0.38 0.09 10-OCT-99 MWD 7111.73 46.01 107.59 95.66 5497.10 4055.40 -1193.90 3875.73 0.21 0.10 0.26 10-OCT-99 MWD 7206.72 47.16 107.73 94.99 5562.39 4124.39 -1214.83 3941.47 1.22 1.21 0.15 11--OCT-99 MWD 7300.95 46.88 107.09 94.23 5626.63 4193.32 -1235.46 4007.25 0.58 -0.30 -0.68 11 -OCT-99 MWD 7395.99 46.43 106.95 95.04 5691.86 4262.44 -1255.69 4073.34 0.49 -0.47 -0.15 11-OCT-99 MWD 7491.72. 45.73 106.57 95.73 5758.26 4331.39 -1275.58 4139.37 0.79 -0.73 -0.40 11-OCT-99 MWD 7586.77 44.79 106.25 95.05 5825.17 4398.91 -1294.65 4204.13 1.02 -0.99 -0.34 11 -OCT-99 MWD 7682.20 44.05 105.89 95.43 5893.33 4465.69 -1313.14 4268.31 0.82 -0.78 -0.38 11 -OCT-99 MWD 7777.76 45.85 106.26 95.56 5960.95 4533.19 -1331.84 4333.18 1.90 1.88 0,39 11 -OCT-99 MWD 7873.00 45.48 105.54 95.24 6027.51 4601.31 ;1350.50 4398.69 0.67 -0.39 -0.76 11-OCT-99 MWD 7968.15 46.78 106.29 95.15 6093.45 ' 4669.89 -1369.31 4464.65 1.48 1.37~ 0.79 11 -OCT'-99 MWD 8064.14 46.40 106.26 95.99 6159,42 4739.62 -1388.86 4531.59 0.40 -0.40 -0.03 ~" 11 -OCT-99 MWD 8158.48 46.12 105.64 94.34 6224.65 4807.77 -1407.59 4597.13 ' 0.56 -0.30 -0.66 11 -ocT'99 MWD 8253.53 46.54 106.66 95.05 6290.28 4876.51 -1426.71 4663.16 0.89 0.44 1.07 11-OCT-99 MWD 8348.56 46.54 106.86 95.03 6355.64 4945.49 -1446.60 4729.21 O. 15 0.00 0.21 11-OCT-99 MWD 8444.84 46.24 106.10 96.28 6422.05 5015,20 -1466.38 4796.06 0.65 -0.31 -0.79 11-OCT-99 MWD 8540.08 45.67 106.35 95.24 6488.27 5083.66 -1485.51 4861.79 0.63 -0.60 0.26 11-OCT-99 MWD 8635.80 45;06 105.81 95.72 6555.52 5151.76 -1504.37 4927.24 0.75 -0,64 -0.56 11 -OCT-99 MWD 8730.11 44.46 105.30 94.31 6622.48 5218.15 -1522.18 4991.21 0,74 -0.64 -0.54 11-OCT-99 MWD 8825.51 43.93 105.66 95.40 6690.88 5284.64 -1539.93 5055.30 0.61 -0.56 0.38 11-OCT-99 MWD 8920.61 43.33 106.66 95.10 6759.72 5350.25 -1558.19 5118.33 0.96 -0.63 1.05 1'1-OCT-99 MWD 9015.31 42.93 105.95 94.70 6828.83 5414.99 -1576.37 5180.46 0.66 -0,42 -0.75 i I , I L SURVEY CALCU~TION AND FIELD WORKSHEET Job No. ~51~ Sidetrack No. P~e 5 ' i Company ARCO A~S~, INC. Rig Contractor & No. Doyon Drilling Co. - ~19 Field ALPINE Well Name & No. CD~1/16 PB1 / 16 Suwey Section Name 26 PB1 MWD BHI Rep. MILCHAK/N~LON ~~ WELL DATA Target ~D (~ Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. ~ Slot Coord. ~ 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk~DL per: 1~ 30m~ 10mO Ved. Sec. ~im. 106.84 Magn. to Map Corr. 26.000 Map NoAh to: OTHER SURVEY DATA Suwey Suwey Incl. Hole Course Vedical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ~D Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (~ (DB) ~D) (~ (~ (~ (~ (Per ~00 ~ Drop (-) Left (-) 11 -OCT-99 MWD 9111.34 42.39 106.76 96.03 ~99.45 5480.06 -1594.69 5242.90 0.80 ~.56 0.84 -- 11-OCT-99 MWD 9206.29 42.71 1 ~.02 94.95 6969.40 5544.26 -1612.81 5304.50 0.63 0.34 -0.78 11-OCT-99 MWD 9278.60 42.74 1~.53 72.31 7022.52 5593.32. -1626.56 5351.60 0.48 0.04 0.71 11 -OCT-99 MWD 9357.~ 42.74 1~.~ 78.40 7080.10 5~6.~ -1641.70 5402.61 0.00 0.~ 0.~ Projected Data - NO SURV~ ~,~. , '" SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08304 Sidetrack No. 1 Page 1 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/16 PB1 / i6 Survey Section Name 26 SDTRK MWD BHI Rep. C MILCHAK ~ir~i~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. F__JW 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100ft~ 30m~] 10m[-] Vert. Sec. Azim. 151.94 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (~r) (DD) (DD) (FI] (F-r) (FT) (F-r) Per ~00 F'r) Drop (-) Left (-) MWD 8348.56 46.54 106.86 6355.64 3501.68 -1446.61 4729.21 TIE IN POINT 13-OCT-99 MWD 8393.36 45.59 107.15 44.80 6386.72 3524.01 -1456.04 4760.06 2.17 -2.12 0.65 6 3/4" MIX 1.4 DEG AKO 13-OCT-99 MWD 8423.60 44.57 107.76 30.24 6408.08 3539.29 -1462.47 4780.49 3.66 -3.37 2.02 13-OCT-99 MWD 8458.18 43.92 109.78 34.58 6432.85 3556.88 -1470.23 4803.33 4.49 -1.88 5.84 13-OCT-99 MWD 8490.55 43.99 110.34 32.37 6456.15 3573.61 -1477.93 4824.44 1.22 0.22 1.73 13-OCT-99 MWD 8519.85 44.11 110.78 29.30 6477.21 3588.89 -1485.09 4843.51 1.12 0.41 1.50 13-OCT-99 MWD 8552.81 44.51 112.11 32.96 6500.80 3606.40 -1493.51 4864.94 3.07 1.21 4.04 13-OCT-99 MWD 8583.92 44.69 112.79 31.11 6522.95 3623.26 -1501.85 4885.13 1.64 0.58 2.19 13-OCT-99 MWD 8614.22 44.91 112.89 30.30 6544.45 3639.83 -1510.13 4904.80 0.76 0.73 0.33 13-OCT-99 MWD 8647.26 44.50 114.45 33.04 6567.93 3658.07 -1519.46 4926.09 3.55 -1.24 4.72 .... 13-OCT-99 MWD 8684.91 44.36 114.58 37.65 6594.82 3679.00 -1530.40 4950.07 0.44 -0.37 0.35 13-OCT-99 MWD 8709.75 45.33 114.99 24.84 6612.43 3692.97 -1537.74 4965.97 4.07 3.91 1.65 13-OCT-99 MWD 8742.55 46.95 115.30 32.80 6635.16 3711.90 -1547.79 4987.38 4.99 4.94 0.95 14-OCT-99 MWD 8774.49 48.94 116.15 31.94 6656.55 3731.04 -1558.09 5008.74 6.54 6.23 2.66 14-OCT-99 MWD 8805.68 51.03 115.78 31.19 6676.60 3750.37 -1568.55 5030.22 6.76 6.70 -1.19 ,,, 14-OCT-99 MWD 8838.25 52.51 114.69 32.57 6696.76 3770.88 -1579.45 5053.36 5.25 4.54 -3.35 14-OCT-99 MWD 8870.37 52.77 114.31 32.12 6716.25 3791.15 -1590.04 5076.59 1.24 0.81 -1.18 14-OOT-99 MWD 8900.66 53.29 114.56 30.29 6734.47 3810.35 -1600.05 5098.63 1.84 1.72 0.83 14-OCT-99 MWD 8933.39 56.25 115.01 32.73 6753.34 3831.65 -1611.26 5122.89 9.11 9.04 1.37 · 14-OCT-99 MWD 8965.15 59.53 114.55 31.76 6770.22 3853.09 -1622.53 5147.32 10.40 10.33 -1.45 14-OCT-99 MWD 8995.67 61.20 115.47 30.52 6785.31 3874.29 -1633.74 5171.35 6.07 5.47 3.01 14-OCT-99 MWD 9028.21 64.10 114.48 32.54 6800.26 3897.38 -1645.94 5197.55 9.31 8.91 -3.04 14-OCT-99 MWD 9060.02 65.49 114.30 31.81 6813.81 3920.20 -1657.83 5223.76 4.40 . 4.37 -0.57 14-OCT-99 MWD 9089.00 65.83 114.53 28.98 6825.75 3941.14 -1668.74 5247.81 1.38 1.17 0.79 ;" ' SURVEY CALCULATION AND FIELD WORKSHEET Jou,o. S, e ack,o. I 2'. 5 · '_ [IJ~'-I ::/~--'~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE IJ~r~J~ Well Name & No. CD#1/16 PB1 / 16 Survey Section Name 26 SDTRK MWD BHI Rep. C MILCHAK WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[-] SS~ Target Description Target Coord. E/W Slot Coord. E/W 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft~ 30m~ 10m[~ Vert. Sec. Azim. 151.94 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (OD) (FT) (FT) (IT) (FT) Per 100 F'r) Drop (-) Left (-) 14-OCT-99 MWD 9123.08 66.31 116.13 34.08 6839.58 3966.14 -1682.07 5275.96 4.52 1.41 4.69 · 14-OCT-99 MWD 9155.34 67.03 119.45 32.26 6852.36 3990.66 -1695.88 5302.16 9.71 2.23 10.29 14-OCT-99 MWD 9184.72 68.13 123.00 29.38 6863.56 4014.00 -1709.96 5325.38 11.78 3.74 12.08 14-OCT-99 MWD 9217.39 69.83 126.19 32.67 6875.28 4041.09 -1727.27 5350.48 10.49 5.20 9.76 14-OCT-99 MWD 9250.71 71.13 129.42 33.32 6886.42 4069.74 -1746.52 5375.28 9.93 3.90 9.69 · 14-OCT-99 MWD 9280.34 72.45 131.69 29.63 6895.68 4095.95 -1764.82 5396.66 8.53 4.45 7.66 14-OCT-99 MWD 9313.37 75.42 133.84 33.03 6904.82 4125.92 -1786.37 5419.96 10.95 8.99 6.51 14-OCT-99 MWD 9345.30 78.15 135.81 31.93 6912.12 4155.63 -1808.29 5442.00 10.45 8.55 6.17 14-OCT-99 MWD 9376.01 79.66 136.01 30.71 6918.03 4184.59 -1829.93 5462.97 4.96 4.92 0.65 15-OCT-99 MWD 9407.81 79.51 138.00 31.80 6923.78 4214.81 -i 852.80 5484.29 6.17 -0.47 6.26 15-OCT-99 MWD 9439.65 79.58 139.82 31.84 6929.56 4245.31 -1876.40 5504.87 5.63 0.22 5.72 15-OCT-99 MWD 9471.31 80.22 142.21 31.66 6935.11 4275.92 -1900.63 5524.48 7.70 2.02 7.55 15-OCT-99 MWD 9502.73 81.05 145.24 31.42 6940.22 4306.60 -1925.62 5542.82 9.87 2.64 9.64 t';' i -- 15-O(~T-99 MWD 0544.03 84.57 147.57 41.30 6945.39 4347.37 -1050.74 5565.48 10.20 8.52 5.64 17-0CT-99 MWD 9640.00 90.31 148.10 95.97 6949.68 4442.96 -2040.01 5616.44 6.02 5.98 0.65 4 3/4' M1X 1.2 DEC AKo 17-OCT-99 MWD 9735.40 91.10 146.49 95.40 6948.50 4538.05 -2121.22 5667.91 1.96 0.83 -1.78 17-0CT-99 MWD 0831.59 90.86 148.11 96.19 6946.86 4633.90 -2202.15 5719.87 1.70 -0.25 1.68 17-OCT-99 MWD 9927.85 90.27 150.19 96.26 6945.91 4730.04 -2284.78 5769.23 2.25 -0.61 2.16 17-OCT-99 MWD 10024.24 88.66 151.21 96.39 6946.81 4826.40 -2368.83 5816.39 1.98 -1.67 1.06 , 18-OCT-99 MWD 10120.19 89.28 153.53 95.95 6948.53 4922.32 -2453.82 5860.88 2.50 0.65 2.42 18-OCT-99 MWD 10216.38 90.00 151.43 96.19 6949.14 5018.50 -2539.12 5905.32 2.31 0.75 -2.18 18-OCT-99 MWD 10307.69 88.94 152.73 91.31 6949.98 5109.80 -2619.79 5948.07 1.84 -1.16 1.42 18-OCT-99 MWD 10397.74 89.66 153.66 90.05 6951.08 5199.82 -2700.16 5988.68 1.31 . 0.80 1.03 18-OCT-99 MWD 10493.28 90.34 153.94 95.54 6951.08 5295.31 -2785.88 6030.86 0.77 0.71 0.29 ' I ~J ' I J .,' :"1 J ,' ~ J t J , ,,i,,I J t J t J I J L J I I L · t I I J ! II I II I I I SURVEY CALCULATION AND FIELD WORKSHEET JobNo. 0451.08,304 Sidetrack No. 1 Page 3 O~ 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/16 PB1 / 16 Survey Section Name 26 SDTRK MWD BHI Rep. C MILCHAK ~jllllr~"~i~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build~Walk\DL per: 100ft~ 30mE] 10mD Vert. Sec. Azim. 151.94 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (OD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 18'OCT-99 MWD 10586.05 91.17 153.22 92.77 6949.86 5388.03 -2868.95 6072.13 1.18 0.89 -0.78 · 18-OCT-99 MWD 10679.40 91.03 152.62 93.35 6948.07 5481.35 -2952.06 6114.62 0.66 -0.15 -0.64 18~OCT-99 MWD 10773.25 90.58 153.52 93.85 6946.75 5575.17 -3035.72 6157.12 1.07 -0.48 0.96 ,.. 18-OCT-99 MWD 10803.88 90.00 153.99 30.63 6946.60 5605.79 -3063.19 6170.67 2.44 -1.89 1.53 19-OCT-99 MWD 10835.43 89.76 154.44 31.55 6946.66 5637.31 -3091.60 6184.39 1.62 -0.76 1.43 1~-OCT-99 MWD 10864.75 90.14 153.90 29.32 6946.69 5666.61 -3117.99 6197.17 2.25 1.30 -1.84 19-OCT-99 MWD 10895.32 89.59 151.95 30.57 6946.76 5697.17 -3145.21 6211.08 6.63 -1.80 -6.38 19-OCT-99 ~. MWD 10928.57 89.31 151.62 33.25 6947.08 5730.42 -3174.51 6226.80 1.30 -0.84 -0.99 19-OCT-99 MWD 10958.48 89.62 153.80 29.91 6947.36 5760.33 -3201.08 6240.51 7.36 1.04 7.29 19-OCT-99 MWD 10989.57 89.83 151.69 31.09 6947.51 5791.41 -3228.72 6254.75 6.82 0.68 -6.79 19-OCT-99 MWD 11020.62 90.00 153.63 31.05 6947.55 5822.46 -3256.30 6269.01 6.27 0.55 6.25 19-OCT-99 MWD 11049.72 90.31 152.64 29.10 6947.48 5851.55 -3282.26 6282.16 3.56 1.07 -3.40 19-OCT-99 MWD 11082.00 90.58 152.70 32.28 6947.23 5883.83 -3310.94 6296.98 0.86 0.84 0.19 · 19-OCT'99 MWD 11115.00 90.79 151.06 33.00 6946.83 5916.82 -3340,04 6312.53 5.01 0.64 -4.97 19-OCT-99 MWD 11144.10 90,99 152.65 29.10 6946.38 5945.92 -3365.69 6326.25 5.51 0.69 5.46 19-ocT-99 MWD 11184.32 90.99 152.46 40.22 6945.68 5986.13 -3401.38 6344.79 0.47 0.00 -0.47 · . 19-OCT-99 MWD 11212.04 91.37 152.21 27.72 6945.11 6013.84 -3425.93 6357.65 1.64 1.37 -0.90 19-OCT-99 MWD 11235.03 91.47 152.07 22.99 6944.54 6036.83 -3446.25 6368.40 0.75 0.43 -0.61 19-OCT-99 MWD 11266.97 90.75 153.82 31.94 6943.92 6068.75 -3474.68 6382.92 5.92 -2.25 5.48 . 19-OCT-99 MWD 11297.62. 91.20 153.29 30.65 6943.40 6099.39 -3502.12 6396.57 2.27 1.47 -1.73 19-OCT-99 MWD 11327.72 91.37 151.03 30.10 6942.73 6129.48 -3528.73 6410.62 7.53 0.56 -7.51 ~_ 19-OCT-99 MWD 11358.09 89.66 152.28 30.37 6942.45 6159.84 -3555.46 6425.04 6.97 -5.63 4.12 19-OCT-99 MWD 11390.31 89.49 1 53.55 32.22 6942.69 6192.06 -3584.14 6439.71 3.98 . -0.53 3.94 19-OCT-99 MWD 11420.23 89.86 152.72 29.92 6942.86 6221.97 -3610.83 6453.23 3.04 1.24 -2.77 i .! J ',.,"! J ' I J I J ' I J '! J ! j ! J I J A J t J A. ,~ i ! I J · J I [1[~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyen Drilling Co. - #19 Field ALPINE I Well Name & No. CD#1/16 PB1/'16 Survey Section Name 26 SDTRK MWD BHI Rep. C MILCHAK l~r~l~ WELL DATA Target'l'VD CT) Target Coord. N/S Slot Coord. N/S -330,00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL~ SS[-] · Target Description Target Coord, EJW Slot Coord. E/W 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build~Walk\DL per: lOOft[~ 30m~ 10m~ Vert. Sec. Azim. 151,94 Magn, to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) {FT) (FT) (F-I') (FT) (Per m0 F'r) Drop (-) Left (-) 19-OCT-99 MWD 11450,69 90,31 151,22 30,46 6942,82 6252,43 -3637,72 6467,54 5.14 1,48 -4,92 19-OCT-99 MWD 11481.66 90.45 153.56 30.97 6942,61 6283.40 -3665,16 6481.89 7,57 0.45 7.56 i9-OCT-99 MWD 11512,91 89,79 150,79 31.25 6942,55 6314,64 -3692,79 6496,48 9,11 -2,11 -8,86 20-OCT-99 MWD 11543.23 88,90 152,08 3O.32 6942.89 6344,96 -3719.42 6510.97 5,17 -2.94 4.25 20-OCT-99 MWD 11573.59 89,04 151,98 30,36 6943.44 6375,31 -3746,23 6525,21 0,57 0,46 -0,33 · 20-OCT-99 MWD 11605.23 89.31 151,41 31.64 6943,90 6406.95 -3774.08 6540,21 1,99 0.85 -1.80 20-OCT-99 MWD 11637,00 89,52 153,17 31,77 6944.22 6438,72 -3802.21 6554.98 5,58 0.66 5.54 20-OCT-99 MWD 11652.81 89,52 152,05 15.81 6944,35 6454,52 -3816.24 6562.26 7,08 0.00 -7.08 20-OCT-99 MWD 11696,89 89,07 152,91 44,08 6944,89 6498,60 -3855.33 6582,62 2,20 -1.02 1,95 20-OCT-99 MWD 11730.02 88,83 153.40 33,13 6945,50 6531.71 -3884.89 6597.58 1.65 -0.72 1.48 20-OCT-99 MWD 11761,53 89,49 151,02 31,51 6945,96 6563,22 -3912,76 6612,27 7,84 2,09 -7,55 20-OCT-99 MWD 11789.44 89,86 150,93 27,91 6946,12 6591,13 -3937,16 6625.81 1.36 1,33 -0,32 20-OCT-99 MWD 11821,43 90,34 151.71 31,99 6946,07 6623,11 -3965,23 6641,16 2,86 1.50 2,44 20-OCT-99 MWD 11851.30 90.07 151.28 29,87 6945,96 6652.98 -3991,47 6655.42 1.70 -0.90 -1.44 20-OCT-99 MWD 11880.63 90.21 152.79 29.33 6945.89 6682,31 '4017,38 6669.17 5,17 0.48 5,15 20-OCT-99 MWD 11912,62 90,41 151.84 31,99 6945,71 6714,30 -4045,71 6684,03 3,03 0,63 -2.97 20-OCT-99 MWD 11944,76 90.72 152,10 32.14 6945.40 6746,44 -4074.07 6699,13 1.26 0.96 0,81 20-OCT-99 MWD 11972,05 90,51 152,82 27,29 6945,10 6773,72 -4098.27 6711,75 2,75 -0,77 2.64 20-OCT-99 MWD 12006,20 89.97 153.46 34,15 6944.96 6807,87 -4128.74 6727.18 2.45 -1.58 1,87 20-OCT-99 MWD 12035.02 90.10 154,40 28.82 6944.94 6836,67 -4154,62 6739.85 3,29 0.45 3,26 -- 20-OCT-99 MWD 12065.34 90,31 151.93 30,32 6944.84 6866,98 -4181.67 6753.53. 8,18 0.69 -8,15 20-OCT-99 MWD 12094.86 90.31 151.74 29,52 6944,68 6896,50 -4207.70 6767,47 0,64 0,00 -0,64 -- 20-OCT-99 MWD 12125,31 90.48 153.21 30,45 6944.47 6926,94 -4234.70 6781,54 4,86 , 0.56 4,83 20-OCT-99 MWD 12154.28 88.83 153.66 28.97 6944.64 6955.90 -4260.61 6794,49 5.90 -5.70 1.55 I ~ · · II I IIIII ~' ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-08304 Sidetrack No. 1 Page 5 °Ir 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #19 Field ALPINE Well Name & No. CD#1/16 PB1/16 Survey Section Name 26 SDTRK MWD BHI Rep. C MILCHAK I~WTEK~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -330.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL Target DesCription Target Coord. EJW Slot Coord. E/W 2468.00 Magn. Declination 26.000 Calculation Method MINIMUM CURVATUI Target Direction (DO) Buil~Walk\DL per: 10Oft[~ 30m0 10m~] Vert. Sec. Azim. 151.94 Magn. to Map Corr. 26.000 Map North to: OTHER SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (F'r) (DD) (DD) (FI') (FT) (FT) (F-T) (Per 100 F'r) Drop (-) Left (-) 20-OCT-99 MWD 12188.35 88.77 154.66 34.07 6945.35 6989.94 -4291.27 6809.34 2.94 -0.18 2.94 20-OCT-99 MWD 12219.99 89.04 152.41 31.64 6945.96 7021.56 -4319.59 6823.44 7.16 0.85 -7.11 20-OCT-99 MWD 12248.91 89.11 152.73 28.92 6946.42 7050.47 -4345.25 6836.76 1.13 0.24 1.11 21-OCT-99 MWD 12281.01 89.07 153.80 32.10 6946.93 7082.56 -4373.91 6851.19 3.34 -0.12 3.33 21-OCT-99 MWD 12312.89 89.07 152.05 31.88 6947.45 7114.43 -4402.30 6865.70 5.49 0.00 -5.49 : 2~-OCT-99 MWD 12342.52 89.35 152.30 29.63 6947.86 7144.06 -4428.50 6879.53 1.27 0.94 0.84 21-OCT-99 MWD 12373.92 89.62 152.77 31.40 6948.14 7175.45 -4456.36 6894.01 1.73 0.86 1.50 21-OCT-99 MWD 12405.24 89.55 154.45 31.32 6948.37 7206.76 -4484.41 6907.93 5.37 -0.22 5.36 , 21-OCT-99 MWD 12435.10 89.62 153.67 29.86 6948.59 7236.60 -4511.26 6920.99 2.62 0.23 -2.61 21-OCT-99 MWD 12467.84 89.83 151.79 32.74 6948.74 7269.33 -4540.36 6935.99 5.78 0.64 -5.74 21-OCT-99 MWD 12499.52 90.03 154.35 31.68 6948.78 7301.00 -4568.60 6950.34 8.11 0.63 8.08 21-OCT-99 MWD 12528.90 90,31 152.32 29.38 6948.69 7330.37 -4594.86 6963.53 6.97 0.95 -6.91 21-OCT-99 MWD 12542.28 90.45 152.44 13.38 6948.61 7343.75 -4606.71 6969.73 1.38 1.05 0.90 21-OC~-99 MWD 12600.00 90.45 152.44 57.72 6948.15 7401.47 -4657.88 6996.43 0.00 0.00 0.00 Projected Data - NO SURVEY ,, , , ,. i i ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska,Inc. Field .................... : Colville River Well ..................... : CDI-16 PB1 AP1 number ............... : 50-103-20306-70 Engineer ................. : Dammeyer/St. Amour Rig: ..................... : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference - Permanent datum .......... : Mean Sea Level. Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.67 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 106.80 degrees [(c)1999 Anadrill IDEAL ID6 0C 07] 11-Oct-1999 22:11:48 Page 1 of 5 Spud date ................ : 5-0ct-99 Last survey date ......... : 11-Oct-99 Total accepted surveys...: 99 MD of first survey ....... : 115.00 ft MD of last survey ........ : 9357.00 ft ORIGINAL Geomagnetic data -- Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 05-0ct-1999 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 26.00 degrees Magnetic dip ............. : 80.47 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. I 1144.65 HCNT Reference Dip ............ : 80.47 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections ....... Magnetic dec (+E/W-) ..... : 26.00 degrees Grid Convergence (+E/W-).I 0.00 degrees Total az corr (+E/W-) .... : 26.00 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED n CT '?' 1999 An orege ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.00 2 201.24 0.78 114.94 3 290.75 1.70 116.32 4 381.71 3.14 116.49 5 470.97 4.31 116.98 0.00 86.24 89.47 91.00 89.26 6 562.37 5,93 113.24 7 652.10 6.32 112.90 8 743.85 7.18 113.66 9 833.10 8.02 108.74 10 922.94 8.55 111.19 91.40 89.73 91.75 89.25 89.84 11 1011.73 8.81 111.18 12 1106.98 8,79 110.59 13 1202.37 !0.81 109.77 14 1297.51 13.88 109.54 15 1391.45 14.55 107.66 16 1486.19 16,95 107.04 17 1581.36 '19.41 107.32 18 1675.52 22,01 106.58 19 1770.80 25,46 106.69 20 1866.43 29.14 106.61 88.79 95.25 95.39 95.14 93.94 94.74 95.17 94.16 95.28 95.63 TVD depth (ft) 115.00 201.24 290.69 381.60 470.67 561.70 650.92 742.04 830.50 919.40 11-Oct-1999 22:11:48 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) o.0o o.o0 o 0.58 -0.25 0 2.49 -1.09 2 6.28 -2.80 5 11.99 -5.42 10 20.06 -8.84 18 29.58 -12.59 27 40.30 -16.85 37 52.06 -21.09 48 64.98 -25.52 60 1007.18 78.34 -30.36 1101.31 92.87 -35.56 1195.30 109.08 -41.15 1288.23 129.$9 -47.98 1379.29 152.45 -55.33 1470.47 1~6o.88 1648.95 1736.16 1821.12 21 1961.56 33.15 106.10 95.13 1902.52 22 2056.67 36.70 105.99 95.11 1980.49 23 2152.31 39.40 106.21 95.64 2055.80 24 2247.08 42,39 107.15 94.77 2127.43 25 2344.17 45.08 107.14 97.09 2197.57 26 2440.32 44,82 107.30 96.15 2265.62 27 2533.78 44,54 107.48 93.46 2332.07 28 2578.86 44,40 107.81 45.08 2364.24 29 2711.08 45.85 107.77 132.22 2457.53 30 2805.93 46,31 107.47 94.85 2523.32 72 86 101 120 142 178.16 -62.99 167 207.85 -71.76 195 241.15 -81.46 227 279.49 -92.44 264 323.34 -105.00 306 372.53 -118.84 426.97 -133.89 485.91 -150.23 547.94 -168.05 615~Q6 -187.84 .0o .27 .71 .89 .29 .10 .00 .01 .17 682.98 -207.95 748.70 -227.59 780.27 -237.16 873.95 -265.79 942.27 -28'6.47 , .67 .28 .52 .68 .54 .09 .45 .30 .04 .06 353 4O5 462 521 585 .26 .59 .21 .63 .77 650 713 743 832 897 .65 .36 .46 .67 .79 Page At Azim (deg) 0.00 114.94 115.67 116.13 116.44 0.00 0.59 2.52 6.37 12.16 20.31 29.88 40.66 52.44 65.36 78.75 93.32 109.5A 129.87 152.90 178.57 208.21 241.46 279.76 323.57 372.72 427.11 486.02 548.o~ 6!5.15 683.07 748.79 780.37 874.06 115.79 114.91 114.49 113.72 112.98 112.68 112.40 112.06 111.68 111.22 110.66 110.16 109.72 109.29 108.94 108.59 108.27 108.01 107.86 107.78 107.72 107.69 107.69 107.70 107.70 2 of 5 DLS (deg/ 100f) 0.00 0.90 1.03 1.58 1.31 1.81 0.44 0.94 1.19 0.71 0.29 0.10 2.12 3.23 0.87 2.54 2.59 2.78 3.62 3.85 4.22 3.73 2.83 3.22 2.77 0.29 0.33 0.60 1.10 0.54 S rvy tool type TIP MWD MWD MWD MWD MWD MWD ~WD MWD MWD MWD MWD MWD MWD MWD IVFWD MWD NFWD MWD MWD MWD lVFWD 5FWD NrWD MWD MWD MWD MWD MWD MWD Tool qual type -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-~xis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured In¢l Azimuth # depth angle angle - (ft) (deg) (deg) Course length (ft) 11-Oct-1999 22:11:48 TVD Vertical Displ Displ Total depth section +N/S- +E/W- diSpl (ft) (ft) (ft) (ft) (ft) 31 2901.21 46.07 106.96 95.28 2589.28 1011.02 -306.82 963.47 1011,14 32 2994.92 46,86 107.73 93.71 2653.83 1078.95 -327.07 1028.31 1079,07 33 3091.43 46,69 107.19 96.51 2719.93 1149.27 -348.17 1095.39 1149,40 34 3187.11 46.48 106.79 95.68 2785.69 1218.77 -368.48 1161.86 1218,89 35 3282.35 46.29 106.11 95.20 2851.36 1287.70 -388.00 1227.96 1287.80 Page At - Azim (deg) 107.66 107.64 107.63 107.60 107.54 36 3376.47 46.14 107.16 94.16 2916.51 1355.67 -407.46 1293.09 1355.77 107.49 37 3472.67 46.06 106.55 96.20 2983.22 1424.99 -427.56 1359.43 1425,08 107.46 38 3568.32 45.94 106.81 95.65 3Q49.66 1493.79 -447.31 1425.34 %493,88 107.42 39 3663.58 45.59 106.08 95.26 3116.12 1562.04 -466.63 1490.80 1562,12 107.38 40 3759.62 46.13 106.24 96.04 3183.00 1630.96 -485.81 1557.00 t631,03 107.33 3248.84 3314.84 3381,13 3447.10 3511.44 1699.58 -505.07 1622.86 1699.64 107.29 1768.25 -523.95 1688.89 1768,30 107.24 1836.64 -542.29 1754.80 1836~68 107.17 1906.09 -561.73 1821.47 !906,12 107.14 1975.50 -581.97 1887.87 !975,54 107.13 41 3854.72 46,24 106.36 95.10 42 3949.97 46.04 105.55 95.25 43 4045.23 45.76 105.54 95.26 44 4141.02 47.19 106.97 95.79 45 4235.67 47.15 106.93 94.65 46 4330.45 47.34 106.38 94.78' 3575.79 2045.09 -601.92 1954.54 2045,13 107.12 47 4426.64 47,57 106.97 96.19 3640.83 2115.96 ~622.25 2022.43 2115,99 107.10 48 4521.99 47.62 106.70 95.$5 3705.13 2186.37 -642.63 2089.82 2186,40 107.09 49 4616.47 47.61 106.33 94.48 3768.82 2256.!5 -662.47 2156.73 2256~18 107.08 50 4711.71 47.52 106.62 95.24 3833.08 2326.44 -682.40 2224.13 2326,47 107.06 51 4807,00 47.53 107.14 95.29 3897.43 2396.73 -7Q2.81 2291.39 2396,75 52 4901.76 47.47 106.66 94.76 3961.45 2466.'59 -723.12 2358.23 2466,61 53 4996,44 47,23 107.04 94.68 4025.60 2536.23 -743.31 2424.88 2536~25 54 5091.85 46,86 106.64 95.41 4090.61 2606.06 -763.54 2491.72 2606,08 55 5207.18 46.20 107.21 115.33 4169.96 2689.75 -787.90 2571.79 ' 2689,78 107.05 107.05 107.04 107.04 107.03 56 5302.95 45,69 107.70 95.77 4236.55 2758.58 -808.54 2637.45 2758,60 107.04 57 5398.10 45,09 106.10 95.15 4303.37 2826.31 ~828.24 2702.25 2826,33 107.04 58 5492.59 47.24 107.43 94.49 4368.81 2894.46 -847.91 2767.51 2894~48 107.03 59 5588.11 46,80 107.23 95.~§2 4433.93 2964.34 -868.73 2834.21 2964,36 107.04 60 5683.11 46,56 106.76 95.00 4499.11 3033.45 -888.93 2900.31 3033,48 107.04 3 of 5 DLS (deg/ 100f) 0.46 1.03 0.44 0.37 0.55 0.82 0.46 0.23 0.66 0.57 0.15 0.65 0.29 1.84 0.05 0.47 0.50 0.21 0.29 0.24 0.40 0.38 0.39 0.49 0.68 0.65 1.35 2.49 0.49 0.44 Srvy type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 5EWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ~WD REWD MWD MWD 5~WD MWD ~WD NWD Tool qual type __ 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-~xis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5778.14 46.26 106.72 95.03 62 5873.22 46.03 106.21 95.08 63 5968.90 45.59 106.16 95.68 64 6063.77 45.24 105.24 94.87 65 6159.30 44.79 106.13 95.53 11-Oct-1999 22:11:48 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) Page Total displ (ft) At AZim (deg) 4564.63 3102.28 -908.75 2966.22 3102~31 107.03 4630.51 3170.84 -928.19 3031.97 3170~87 107.02 4697.20 3239.44 -947.31 3097.86 3239,47 107.00 4763.80 3307.00 -965.59 3162.91 3307,01 106.98 4831.33 3374.55 -983.86 3227.96 3374.56 106.95 66 6254,92 45.77 108.50 95.62 4898.62 67 6349.81 44.87 108.80 94.89 4965.34 68 6445.48 44.33 109.01 95.67 5033.46 69 6540.77 46,39 108.63 95.29 5100.41 70 6636.48 45.69 107.77 95.71 5166.85 71 6731.58 45.12 107.75 95.10 5233.61 72 6825.70 46,74 107.78. 94.12 5299.08 73 6920.76 46,27 107.25 95.06 5364.50 74 7016.07 45.91 107.34 95.31 5430.60 75 7111.73 46,01 107.59 95.66 5497.10 94.99 94.23 95.04 95.73 95.05 5562.39 5626.63 5691.86 5758.27 5825.17 76 7206.72 47,16 107.73 77 7300.95 46.88 107.09 78 7395.99 46.43 106.95 79 7491.72 45,73 106.57 80 7586.77 44.79 106.25 81 7682,20 44.05 105.89 95.43 5893.33 82 7777,76 45.85 106.26 95.56 5960.96 83 7873.00 45.48 105.54 95.24 6027.51 84 7968,15 46,78 106.29 95.15 6Q93.46 85 8064.14 46,40 106.26 95.99 6159.42 3442.48 -1004.09 3292.81 3509.92 -1025.66 3356.73 3577.05 -1047.43 3420.29 3644.80 -1069.30 3484.46 3713.67 -1090.82 3549.91 3781.38 -1111.47 3614.40 3849.00 -1132.11 3678.80 3917.95 -1152.86 3744.56 3986.61 -1173.27 3810.12 4Q55.37 -1193.91 3875.71 4124.36 -1214.84 3941.46 4193.30 -1235.47 4007.24 4262.41 -1255.70 4073.33 4331.37 -1275.59 4139.35 4398.88 -1294.66 4204.12 4465.67 -1313.15 4268.30 4533.17 -1331.85 4333.17 4601.28 -1350.51 4398.68 4669.87 -1369.33 4464.64 4739.60 -1388.87 4531.58 4807.75 -1407.60 4597.11 4876.49 -1426.72 4663.15 4945.47 -1446.61 4729.20 5015.18 -1466.39 4796.04 5083.64 -1485.52 4861.78 86 8158.48 46.12 105.64 87 8253.53 46~54 106.66 88 8348.56 46.54 106.86 89 8444.84 46.24 106.10 90 8540.08 45,67 106.35 6224.65 6290.28 6355.65 6422.05 6488.27 94.34 95.05 95.03 96.28 95.24 3442.49 3509,94 3577,07 3644,84 37!3~72 3781,43 3849,05 3918,01 3986,67 4055,44 4124,43 4193.37 4262,49 4331~44 4398,95 4465.73 4533.23 4601,33 4669,91 4739.64 4807,78 4876,53 4945,50 50!5,21 5083,66 106.96 106.99 107.03 107.06 107.08 107.09 107.11 107.11 107.12 107.12 107.13 107.14 107.13 107.13 107.12 107.10 107.09 107.07 107.05 107.04 107.02 107.01 107.01 107.00 106.99 4 of 5 DLS (deg/ 100f) 0.32 0.46 0.46 0.78 0.81 2.04 0.97 0.59 2.18 0.98 0.60 1.72 0.64 0.38 0.21 1.22 0.58 0.49 0.79 1.02 0.82 1.90 0.67 1.48 0.40 0.56 0.89 0.15 0.65 0.63 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD l~D I~WD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 11-Oct-1999 22:11:48 Page 5 of 5 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 91 8635.80 45.06 105.81 92 8730.11 44.46 105.30 93 8825.51 43.93 105.66 94 8920.61 43.33 106.66 95 9015.31 42.93 105.95 Course length (ft) 95.72 94.31 95.40 95.10 94.70 96 9111.34 42.39 106.76 97 9206.29 42.71 106.02 98 9278.60 42.74 106.53 96.03 94.95 72.31 Projected to TD 99 9357.00 42.74 106.53 78.40 TVD Vertical Displ Displ Total depth section +N/S- +E/W- diop! (ft) (ft) (ft) (ft) (ft) 6555.52 6622.49 6690.88 6759.72 6828.83 6899.45 6969.40 7022.52 7080.10 5151.74 -1504.39 5218.13 -1522.20 5284.62 -1539.94 5350.23 -1558.20 5414.97 -1576.37 4927.22 4991.20 5055.29 5118.32 5180.45 5480.04 -1594.69 5544.25 -1612.81 5593.31 -1626.56 At Azim (deg) 106.98 106.96 106.94 106.93 106.92 5151,77 5218,15 5284,64 5350,25 5414,98 5242.90 5480,05 106.92 5304.49 5544,26 106.91 5351.59 5593,32 106.91 5646.51 -1641.70 5402.60 DLS (deg/ lOOf) 0.75 0.74 0.61 0.96 0.66 0.80 0.63 0.48 5646,52 106.90 0.00 Srvy tool type MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1999 Anadrill IDEAL ID6 0C 07] -- -- ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CDi-16~~. API number ............... : 50-103-20306 Engineer ................. : Dammeyer/St. Amour Rig: ..................... : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's PiPe Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : 55.70 ft DF above permanent ....... : 55.70 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.94 degrees 21-Oct-1999 09:01:31 Page 1 of 8 Spud date ................ : 5-Oct-99 Last survey date ......... : 21-Oct-99 Total accepted surveys...: 197 MD of first survey ....... : 115.0Q ft MD of last survey ........ : 12600.00 ft ORIGINAL Geomagnetio data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 05-0ct-1999 Magnetic field strength..: 1144.65 HcNT Magnetic dec (+E/W-) ..... : 26.00 degrees Magnetic dip ............. : 80.47 degrees MWD sUrvey Reference Criteria ~-~ Reference G .............. : 1002.68 ~Gal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.47 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections - -- Magnetic dec (+E/W-) ..... : 26.00 degrees Grid Convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.00 degrees (Total az corr = magnetic dec - grid c0nV) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 0C 07] RECEIVED 1 1999 Alas~ Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 21-0ct-1999 09:01:31 Page 2 of 8 Seq Measured Incl AzimUth # depth angle angle - (ft) (deg) (deg) 1 115.00 0.00 0.00 2 201.24 0.78 114.94 3 290,71 1.70 116.32 4 381,71 3.14 116.49 5 470,97 4.31 116.98 Course TVD Vertical Displ Displ Total length depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) (ft) 0.00 115.00 0.00 0.00 0.00 0.00 86.24 201.24 0.47 -0.25 0.53 0.59 89.47 290.69 2.03 -1.09 2.27 2.52 91.00 381.60 5.16 -2.80 5.71 6.37 89.26 470.67 9.90 -5.42 10.89 12.16 At DLS Azim (deg/ (deg) 100f) 0.00 0.00 114.94 0.90 115.67 1.03 116.13 1.58 116.44 1,31 Srvy Tool tool qual type type TIP - MWD 6-axis MWD 6-axis MWD 6-axis ~WD 6-axis 6 562,37 5.93 113.24 7 652,10 6.32 112.90 8 743,85 7.18 113.66 9 833,10 8.02 108.74 10 922,94 8.55 111.19 91.40 561.70 16.40 -8.84 18.29 20.31 89.73 650.92 23.86 -12.59 27.10 29.88 91.75 742.04 32.28 -16.85 37.00 40.66 89.25 830.50 41.20 -21.09 48.01 52.44 89.84 919.40 50.82 -25.52 60.17 65.36 115.79 1.81 114.91 0.44 114.49 0.94 113.72 1.19 112.98 0.71 ~WD 6-axis MWD 6-axis ~WD 6-axis MWD 6-axis NWD 6-axis 11 1011,73 8.81 111.18 12 1106,98 8.79 110.59 13 1202,37 10.81 109.77 14 1297,51 13.88 109.54 15 1391~45 14.55 107.66 16 1486;19 16.95 107.04 17 1581i36 19.41 107.32 18 1675,52 22.01 106.58 19 1770,80 25.46 106.69 20 1866,43 29.14 106.61 88.79 1007.18 60.97 -30.36 72.67 78.75 95.25 1101.31 71.96 -35.56 86.28 93.32 95.39 1195.30 84.07 241.15 101.52 109.54 95.14 1288.23 99.11 -47.98 120.68 129.87 93.94 1379.29 115.88 -55.33 142.54 152.90 94.74 1470.47 134.18 -62.99 167.09 178.57 95.17 1560.88 155.27 -71.76 195.45 208.21 94.!6 1648.95 178.81 -81.46 227.30 241.46 95.28 1736.16 205.78 T92.44 264.04 279.76 95.63 1821.12 236.63 -105.00 306.06 323.57 112.68 0.29 112.40 0.10 112.06 2.12 111.68 3.23 111.22 0.87 110.66 2,54 110.16 2.59 109.72 2,78 109.29 3.62 108.94 3,85 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis ~4D 6-axis ~WD 6-axis MWD 6-axis ~WD 6-axis MD 6-axis 21 1961~56 33.15 106.10 22 2056,67 36.70 105.99 23 2152,31 39.40 106.21 24 2247,08 42.39 107.15 25 2344,17 45.08 107.i4 26 2440,32 44.82 107.30 27 2533~78 44.54 107.48 28 2578,86 44.40 107.81 29 2711,08 45.85 107.77 30 2805,93 46.31 107.47 95.13 1902.52 271.05 -118.84 353.26 372.72 108.59 4,22 95.11 1980.49 308.93 -133.89 405.59 427.11 108.27 3,73 95.64 2055.80 350.00 -150.23 462.21 486.02 108.01 2,83 94.77 2!27.43 393.68 -168.05 521.63 548.04 107.86 3,22 97.09 2197.57 441.30 -187.84 585.77 6!5.15 107.78 2,77 96.15 93.46 45.08 132.22 94.85 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis NWD 6-axis 2265.62 489.57 -207.95 650.65 683.07 107.72 0.29 NWD 6-~xis 2332.07 536.40 -227.59 713.36 748.79 107.69 0.33 5gWD 6-axis 2364.24 559.00 -237.16 743.46 780.37 107.69 0,60 ~WD 6-axis 2457.53 626.23 -265.79 832.67 874.06 107.70 1.10 NWD 6-axis 2523.32 675.11 -286.47 897.79 942.38 107.70 0.54 MWD 6-axis RECEIVED 1R 1999 AI~, 011 & Gas Cons. Commi~ion Anchorage ANADRILL SCHLUMBERGER Survey Report 21-Oct-1999 09:01:31 Page 3 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft] (deg) (deg) 31 2901,2i 46.07 106.96 32 2994,92 46.86 107.73 33 3091,43 46.69 107.19 34 3187,11 46.48 106.79 35 3282,31 46.29 106.11 course length (ft) 95.28 93.71 96.51 95.68 95.20 TVD depth (ft) 2589.28 2653.83 2719.93 2785.69 2851.36 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 723.96 -306.82 963.47 772.34 -327.07 1028.31 822.52 -348.17 1095.39 871.70 -368.48 1161.86 920.02 -388.00 1227.96 Total At displ Azim (ft) (deg) 1011.14 107.66 1079.07 107.64 1149.40 107.63 1218.89 I07.60 1287.80 107.54 DLS Srvy Tool (deg/ tool qual 100f) type type 0.46 MWD 6-axis 1.03 MWD 6-axis 0.44 NWD 6-axis 0.37 MWD 6-axis 0,55 MWD 6-axis 36 3376,47 46.14 107.16 37 3472,67 46.06 106.55 38 3568,32 45.94 106.81 39 3663,58 45.59 106.08 40 3759~62 46.13 106.24 41 3854,72 46.24 106.36 42 3949,97 46.04 105.55 43 4045i23 45.76 105.54 44 4141102 47.19 106.97 45 4235,67 47.15 106.93 46 4330i45 47.34 106.38 47 4426,64 47.57 106.97 48 4521i99 47.62 106.70 49 46i6~47 47.61 106.33 50 4711~71 47.52 106.62 51 4807.00 47.53 107.14 52 4901.76 47.47 106.66 53 4996~44 47.23 107.04 54 5091,85 46.86 106.64 55 5207~18 46.20 107.21 94.16 2916.51 967.83 -407.46 1293.09 1355.77 107.49 96.20 2983.22 1016.77 -427.56 1359.43 1425.08 107.46 95.65 3049.66 1065.20 -447.31 1425.34 1493.88 107.42 95.26 3116.12 1113.05 -466.63 1490.80 1562.12 107.38 96.04 3183.00 1!61.11 -485.81 1557.00 1631.03 107.33 95.10 3248.84 1209.09 -505.07 1622.86 1699.64 107.29 95.25 3314.84 1256.81 -523.95 1688.89 1768.30 107.24 95.26 3381.13 1303.99 -542.29 1754.80 1836.68 107.17 95.79 3447.10 1352.52 -561.73 1821.47 1906.12 107.14 94.65 3511.44 1401.61 -581.97 1887.87 1975.54 107.13 94.78 3575.79 1450.57 -601.92 1954.54 2045.13 107.12 96.19 3640.83 1500.45 -622.25 2022.43 2115.99 107.10 95.35 3705.13 1550.14 -642.63 2089.82 2186.40 107.09 94.48 3768.82 1599.12 -662.47 2156.73 2256.18 i07.08 95.24 3833.08 1648.4t -682.40 2224.13 2326.47 107.06 95.29 3897.43 1698,06 -702.81 2291.39 2396.75 107.05 94.76 3961.45 1747,43 -723.12 2358.23 2466.61 107.05 94.68 4025.60 1796.59 -743.31 2424.88 2536.25 107.04 95.41 4090.61 1845.88 -763.54 2491.72 2606.08 107.04 15.33 4169.96 1905.05 -787.90 2571.79 2689.78 !07.03 56 5302,95 45.69 107.70 95.77 57 5398,10 45.09 106.10 95.15 58 5492~59 47.24 107.43 94.49 59 5588jll 46.80 107.23 95.52 60 5683,11 46.56 106.76 95.00 4236.55 1954.15 -808.54 2637.45 2758.60 107.04 4303.37 2002.01 -828.24 2702.25 2826.33 107.04 4368.81 2050.07 -847.91 2767.51 2894.48 107.03 4433.93 2099.82 -868.73 2834.21 2964.36 107.04 4499.11 2148.74 -888.93 2900.31 3033.48 107.04 0,82 MWD 6-axis 0.46 MWD 6-axis 0.23 MWD 6-axis 0.66 MWD 6-axis 0.57 MWD 6-axis 0.15 MWD 6-axis 0.65 MWD 6-axis 0.29 MWD 6-axis 1,84 MWD 6-axis 0,05 MWD 6-axis 0,47 MWD 6-axis 0.50 MWD 6-axis 0,21 .MWD 6-axis 0.29 MWD 6-axis 0,24 MWD 6-axis 0,40 MWD 6-axis 0,38 MWD 6-axis 0,39 MWD 6-axis 0,49 MWD 6-axis 0.68 MWD 6-axis 0.65 MWD 6-axis 1.35 MWD 6-axis 2.49 MWD 6-axis 0.49 MWD 6-axis 0.44 MWD 6-axis RECE VE.D Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 21-Oct-1999 09:01:31 Page 4 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 61 5778,14 46.26 106.72 62 5873,22 46.03 106.21 63 5968,90 45.59 106.16 64 6063,77 45.24 105.24 65 6159,30 44.79 106.13 66 6254i92 45.77 108.50 67 6349,81 44.87 108.80 68 6445,48 44.33 109.01 69 6540,77 46.39 108.63 70 6636,48 45.69 107.77 Course length 95.03 95.08 95.68 94.87 95.53 95.62 94.89 95.67 95.29 95.71 TVD depth (ft) 4564.63 4630.51 4697.20 4763.80 4831.33 4898.62 4965.34 5033.46 5100.41 5166.85 71 6731,58 45.12 107.75 95.10 5233.61 72 6825,70 46.74 107.78 94.12 5299.08 73 6920,76 46.27 107.25 95.06 5364.50 74 7016,07 45.91 107.34 95.31 5430.60 75 7111~73 46.01 107.59 95.66 5497.10 76 7206,72 47.16 107.73 94.99 5562.39 77 7300'95 46.88 107.09 94.23 5626.63 78 7395,99 46.43 106.95 95.04 5691.86 79 7491,72 45.73 106.57 95.73 5758.27 80 7586~77 44.79 106.25 95.05 5825.17 81 7682.20 44.05 105.89 95.43 5893.33 82 7777,76 45.85 106.26 95.56 5960.96 83 7873i00 45.48 105.54 95.24 6027.51 84 7968i15 46.78 106.29 95.15 6093.46 85 8064,14 46.40 106.26 95.99 6t59.42 86 8158~48 46.12 105.64 94.34 622~.65 87 8253~53 46.54 106.66 95.05 6290.28 88 8348,56 46.54 106.86 95.03 6355.65 89 8393,36 45.59 107.15 44.80 6386.73 90 8423,60 44.57 107.76 30.24 6408.08 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 2197.24 -908.75 2966.22 2245.31 -928.19 3031.97 2293.18 -947.31 3097.86 2339.9% -965.59 3162.91 2386.63 -983.86 3227.96 2434.99 -1004.09 2484.10 ~1025.66 2533.20 -1047.43 2582.68 -1069.30 2632.46 -1090.82 Total At displ Azim (ft) (deg) 3102.31 107.03 3170.87 107.02 3239.47 107.00 3307.01 106.98 3374.56 106.95 2681.02 -1111.47 2729.52 -1~132.11 2778.77 -1152.86 2827.63 -1173.27 2876.69 -li93.91 3292.81 3442.49 106.96 3356.73 3509.94 106.99 3420.29 3577.07 107.03 3484.46 3644.84 107.06 3549.91 3713.72 107.08 2926.09 -1214.84 2975.24 -1235.47 3Q24.18 -1255.70 3072.78 -1~75.59 3120.08 -1294.66 3614.40 3781.43 107.09 3678.80 3849.05 107.11 3744.56 3918.01 107.11 3810.12 3986.67 107.!2 3875.71 4055.44 107.12 3~66.59 -1313.15 3213.60 -1331.85 3260.89 -1350.51 3308.52 -1369.33 3357.25 -1388.87 3 04.61 -1407.60 3452.55 -1426.72 3501.17 -1446.61 3524.01 ~1456.05 3539.28 -1462.47 3941.46 4124.43 107.13 4007.24 4193.$7 107.14 4073.33 4262.49 107.13 4139.35 4331.44 107.13 4204.12 4398.95 107.%2 4268.30 4465.73 107.10 4333.17 4533.23 107.09 4398.68 4601.33 I07.07 4464.64 4669.91 107.05 4531.58 4739.64 107.04 DLS ~rvy Tool (deg/ tool qual 100f) type type 0.32 MWD 6-~xis 0.46 MWD 6-axis 0.46 MWD 6-axis 0.78 MWD 6-axis 0.81 MWD 6-axis 2,04 MWD 6-axis 0.97 MWD 6-axis 0.59 MWD 6-axis 2.18 MWD 6-axis 0.98 MWD 6-axis 0.60 MWD 6-axis 1.72 MWD 6-axis 0.64 MWD 6-axis 0.38 MWD 6-axis 0.21 MWD 6-axis 1.22 ~WD 6-axis 0.58 ~WD ~-axis 0.49 MWD 6-axis 0.79 MWD 6-axis 1.02 MWD 6-axis 0,82 5CWD 6-axis 1,90 MWD 6-axis 0,67 MWD 6-axis 1.48 MWD 6-axis 0.40 MWD 6-axis 4597.11 48~7.78 10~.02 0.56 NWD 6-axis 4663.15 4876.53 I07.01 0.89 MWD 6-axis 4729.20 4945.50 107.01 0.15 MWD - 4760.05 4977.77 107.01 2.17 MWD 6-axis 4780.48 4999.18 107.01 3.66 MWD 6~axis RECEtVSD Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 21-Oct-1999 09:01:31 Page 5 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 91 8458,18 43.92 109.78 92 8.490,55 43.99 110.34 93 8519,85 44.11 110.78 94 8552,81 44.51 112.11 95 8583,92 44.69 112.79 Course length (ft) 34.58 32.37 29.30 32.96 31.11 TVD depth (ft) 6432.86 456.16 6~0.80 6522.95 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3556.88 -1470.23 4803.32 3573.61 -1477.94 4824.42 3588.89 -1485.09 4843.50 3606.40 -1493.51 4864.93 3623.26 -1501.85 4885.11 Total At DLS Srvy Tool displ Azim (dog/ tool qual (ft) (de~) 100f) type type 5023.29 107.02 4.49 MWD 6-axis 5045.73 107.03 1.22 MWD 6-axis 5066.06 107.05 1.12 MWD 6-axis 5089.02 107.07 3.07 MWD 6-axis 5110.76 107.09 1,64 MWD 6-axis 96 8614~22 44.91 112.89 30.30 97 8647,26 44.50 114.45 33.04 98 8684,91 44.36 114.58 37.65 99 8709,75 45.33 114.99 24.84 100 8742,55 46.95 115.30 32.80 6544.45 6567.94 6594.82 6612.44 6635.16 3639.83 -1510.14 4904.79 3658.07 -1519.47 4926.08 3679.00 -1530.41 4950.06 3692.96 -1537.75 4965.96 3711.90 -1547.80 4987.37 5132.01 107.11 0,76 MWD 6-axis 5155.10 ~07.14 3,55 MWD 6-axis 5181.24 107.18 0.44 MWD 6-axis 5198.60 107.21 4.07 MWD 6-axis 5222.02 107.24 4.99 MWD 6-axis 101 8774149 48.94 116.15 31.94 6656.56 3731.04 -1558.09 5008.73 102 8805~68 51.03 115.78 31.19 6676.61 3750.37 -1568.55 5030.21 103 8838~25 52.51 114.69 32.57 6696.76 3570.88 -1579.46 5053.35 104 8870,37 52.77 114.31 32.12 6716.25 3791.15 -1590.04 5076.58 105 8900~66 53.29 114.56 30.29 6734.47 3810.34 -1600.05 5098.61 5245.48 107.28 6.54 MWD 6-axis 5269.09 107.32 6.76 MWD 6-axis 5294.43 ~07.36 5.25 MWD 6-axis 53%9.77 107.39 1.24 MWD 6-axis 5343.78 107.42 1.84 MWD 6-axis 106 8933~39 56.25 115.01 32.73 6753.35 3831.65 -1611.26 5122.88 107 8965~15 59.53 114.55 31.76 6770.23 3853.09 -162Z.53 5147.30 108 8995~67 61.20 115.47 30.52 6785.32 3874.29 -1633.75 5171.34 109 9028~2! 64.10 114.48 32.54 6800.27 3897.38 -1645.95 5197.54 110 9060~02 65.49 114.30 31.81 6813.81 3920.20 ~1657.83 5223.75 111 9089.00 65.83 114.53 112 9123.08 66.31 116.13 113 9155~34 67.03 119.45 114 9184i72 68.13 123.00 115 9217~39 69.83 126.19 116 9250i71 71.13 129.42 117 9280134 72.45 131.69 118 9313137 75.42 133.84 119 9345~30 78.15 135.81 120 9376,01 79.66 136.01 28.98 34.08 32.26 29.38 32.67 33.32 29.63 33.03 3!.93 30.71 6825.76 3941,14 -1668.75 5247.80 6839.58 3966,14 -1682.07 5275.95 6~52.36 3990.65 -1695.88 5302.15 6863.57 4014.00 -1709.96 5325.37 6875.29 4041.09 -1727.28 5350.46 6886.43 4069.74 ~1746.53 5375.27 6895.69 4095.95 -1764.83 5396.65 6904.83 4125.92 ~1786.38 5419.95 6912.13 4i55.63 -1808.29 5441.99 6918.04 4184.59 -1829.94 5462.96 5370.30 I07.46 9.11 MWD 6-axis 5396.98 i07.50 10,40 MWD 6-axis 5423.28 107.53 6,07 MWD 6-axis 5451.93 107.57 9,31 MWD 6-axis 5480.51 107.61 4,40 ~WD 6-axis 5506.73 107.64 1,38 MWD 6-axis 5537.60 107.68 4,52 MWD 6-axis 5566.76 107.74 9,71 MWD 6-axis 5593.17 107.80 11,78 MWD 6-axis 5622.36 107.89 10,49 MWD 6-axis 5651.89 108.00 9,93 MWD 6-axis 5677.89 108.11 8,53 ~WD 6-axis 57~6.75 108.24 10,95 N56D 6-axis 5734.56 I08.38 10,45 MWD 6-axis 5761.30 108.52 4.96 ~ MWD..6-axis REC. WED Alaska Oit & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 21-Oct-1999 09:01:31 Page 6 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 121 9407,81 79.51 138.00 122 9439.65 79.58 139.82 123 9471,31 80.22 142.21 124 9502,73 81.05 145.24 125 9544~03 84.57 147.57 COurse length (ft) 31.80 31.84 31.66 31.42 41.30 126 9640,00 90.31 148.19 95.97 127 9735,40 91.10 146.49 95.40 128 9831,59 90.86 148.11 96.19 129 9927,85 90.27 150.19 96.26 130 10024,24 88.66 151.21 96.39 131 10120,19 89.28 153.53 132 10216,38 90.00 151.43 133 10307,69 88.94 152.73 134 10397,74 89.66 153.66 135 10493~28 90.34 153.94 95.95 96.19 91.31 90.05 95.54 136 10586,05 91.17 153.22 137 10679~40 91.03 152.62 138 10773i25 90.58 153.52 139 10803~88 90.00 153.99 140 10835~43 89.76 154.44 92.77 93.35 93.85 30.63 3~.55 141 10864175 90.14 153.90 142 10895~32 89.59 151.95 143 10928i57 89.31 151.62 144 10958i48 89.62 153.80 145 10989~57 89.83 151.69 146 11020,62 90.00 153.63 147 11049~72 90.31 152.64 148 11082,00 90.58 152.70 149 1~115,00 90.79 151.06 150 11144,10 90.99 152.65 29.32 30.57 33.25 29.91 31.09 31.05 29.10 32.28 33.00 29.10 TVD depth (ft) 6923.78 6929.56 6935.12 6940.23 6~5.40 6949.68 6948.51 6946.86 6945.91 6946.81 6948.54 6949.14 6949.99 6951.09 6951.09 6949.87 6948.07 6946.76 6946.60 6946.67 6946,69 6946,76 6947.08 6947.36 6947.51 6947.56 6947.48 6947.23 6946.83 6946.38 Vertical bispl Displ section +N/S- +E/W- (ft) (ft) (ft) 4214.81 -1852.81 5484.28 4~45.31 -1~76.41 5504.86 4275.91 -1900.63 5524.47 4306.59 ~1925.63 5542.81 4347.37 -1959.75 5565.47 4442.96 -2040.92 4538.04 -2121.22 4633.90 -2202.15 4730.04 -2284.78 4826.40 ~2368.84 5616.43 5667.90 5719.86 5769.21 5816.38 4922.32 '2453.82 5018.50 '2539. i2 5t09.80 ,2619.80 5199.82 -2700.16 5295.31 ~2785.89 5860.87 5905.31 5948.06 5988.67 6030.85 5388.03 ~2868.96 5481.35 ~2952.06 5575.17 -3035.72 5605.79 ~3063.20 5637.31 ~309~.60 5666.61 -311.7.99 5697.17 -3!45.21 5730.42 ~3t74.51 5760.33 '3201.09 5j91.4I -3228.73 6072.12 6114.61 6157.11 6170.65 6184.38 6197.15 6211.07 6226.79 6240.50 6254.74 5822.46 '3256.31 5 51.5. 5883.83 -3510.94 5916.82 ~3~40.04 5945.92 -3365.70 6269.00 6282.14 6296.96 6312.52 6326.24 Total At DLS ~rvy Tool displ Azim (deg/ tool qual (f%) (deg) 100f) type type 5788.81 108.67 6.17 NWD ~-axis 5815.88 108.82 5.63 MWD 6-axis 5842.27 108.99 7.70 NWD 6-axis 5867.77 109.16 9.87 MWD 6-axis 5900.43 109.40 10,20 ~WD 6-axis 5975.75 109.97 6.02 MWD 6-axis 6051.83 110.52 1,96 ~WD 6-axis 6129.13 111.06 1.70 NWD 6-axis 6205.~6 11t.61 2.25 5[WD 6-axis 6280.26 11~.16 1.98 NWD 6-axis 6353.82 112.72 2.50 NWD 5-axis 6428.05 I13.27 2,31 MWD 6-axis 6499.45 Ii~. 77 1,84 NWD 6-axis 6569.25 114.27 1,31 MWD 6-axis 6643.21 114.79 0,77 ~WD 6-axis 6715.77 I15.29 1,18 MWD 6-axis 6789.93 il5. 77 o, 66 bK4D 6-axis 6864.81 116.25 1,07 MWD 6-axis 6889. i3 ~16.40 2,44 ~WD 6-axis 6914.08 116.56 1,62 MWD 6-axis 6937.33 116.71 2,25 MWD 6-axis 6962.02 116.86 6, 63 MWD 6-axis 6989.31 117.01 1,30 MWD 6-axis 7013.62 !17. i6 7,36 5fWD 6-axis 7038.92 i17.30 6.82 NWD 6-axis 7064.26 117.45 6.27 NWD 6-axis ~087.92 117.59 3,57 ~WD 6-axis 71~4.36 117.74 0,86 NWD 6-axis 7141.69 117.88 5.01 MWD 6-axis . ~WD 7165.84 118 01 5,51 ~=~ 6-axis REC siVED i, ! 2 1999 Oil & Gas Cons. Commi ion Anchorage ANADRILL SCHLUMBERGER Survey Report Seq MeaSured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 151 11184,32 90.99 152.46 152 11212,04 91.37 152.22 153 11235,03 91.47 152.07 154 11266,97 90.75 153.82 155 11297.62 91.20 153.29 course length 40.22 27.72 22.99 31.94 30.65 156 11327,72 91.37 151.03 157 1t358~09 89.66 152.28 158 11390~31 89.49 153.55 159 11420,23 89.86 152.72 160 11450~69 90.31 151.22 161 11481;66 90.45 153.56 162 11512~91 89.79 150.79 163 11543,23 88.90 152.08 164 11573~59 89.04 151.98 165 11605123 89.31 151.41 30.10 30.37 32.22 29.92 30.46 30.97 31.25 30.32 30.36 31.64 166 11637,00 89.52 153.i7 31.77 167 11652,81 89.52 152.05 15.81 168 11696,89 89.07 152.91 44.08 169 1t730~02 88.83 153.40 33.I3 170 11761153 89.49 151.02 31.51 171 11789.44 89.86 150.93 27.91 172 11821~43 90.34 151.71 31.99 173 11851~30 90.07 151.25 29.87 174 11880,63 90.21 152.79 29.33 175 119%2~62 90.41 151.84 31.99 176 11944i76 90.72 152.10 177 11972~05 90.51 152.82 178 12006~20 89.97 153.46 179 12035~02 90.10 154.40 180 12065~34 90.31 151.93 32.14 27.29 34.15 28.82 30.32 TVD depth (ft) 6945.69 6945.12 6944.55 6943.93 6943.41 6942.73 6942.46 6942.70 6942.87 6942.82 6942.62 6942.55 6942.90 6943.44 6943.90 6944.22 6944.36 6944.90 6945.50 6945.97 6946.13 6946.07 6945.96 6945.89 6945.72 6945.40 6945.I1 6944.96 6944.95 6944.84 21-Oct-1999 09:01:31 Vertical Displ Displ section +N/S- +E/W- (ft) (fi) (ft) 5986.13 -3401.39 6344.77 6013.84 -3425.93 6357.64 6036.83 -3446.25 6368.38 6068.75 -3474.69 6382.91 6099.39 -3502.13 6396.55 6729,48 -3528.73 6159.84 -3555.46 6192.06 -3584.15 6221.97 -3610.84 6252.43 -3637.72 Page 7 of 8 6283.39 -3665.16 6314.64 -3692.80 6344.96 -3719.42 63,75.31 -3746.23 6406.95 -3774.09 6438.7~ -3802.21 6454.52 -3816.25 6498.60 -3855.34 6~31.7I -3884.89 6563.22 -391~.76 6591.12 13937.17 6623,11 -3965.23 6652~98 -399t.~8 6682.31 -4017.38 6714.30 -4045.70 Total At displ Azim (ft) (deg) 7199.00 118.20 7221.95 118.32 7241.06 118.42 7267.39 118.56 7292.52 118.70 6410.61 7.317.64 118.83 6425.02 7343.18 118.96 6439.69 7369.92 119.10 6453.21 7394.74 119.23 6467.53 7420.37 119.36 6746.44 -4074.07 6773.72 24098.27 6807.86 -4i28.73 6836.67 -4!54.62 6866.98 -4i81.67 6481.88 7446.35 119.49 6496.46 7472.67 119.62 6510.96 7498.45 119.74 ~525.20 75~4.13 i19.86 6540.20 7551.02 119.99 6554.97 6562.24 6582.61 6597.57 6612.26 6625.80 6641.15 6655.41 6669.17 6684.03 6699.14 6711.75 6727.18 6739.85 6753.53 DLS Srvy Tool (deg/ tool qual 100f) type type 0.47 MWD - 1.64 MWD 6-axls 0.75 MWD 6-axis 5.92 ~WD 6-axis 2,27 5fWD 6-axis 7,53 RK4D 6-axis 6.97 ~WD 6-axis 3.98 ~WD 6-axis 3.04 ~D 6-axis 5.14 ~WD 6-axis 7.57 NWD 6-axis 9.11 NWD 6-axis 5.17 MWD 6-axis 0.57 MWD 6-axis 1.99 NWD 6-axis 7577.89 7591.23 i628.52 7656.39 7683.20 7707.30 7734.85 7760.56 ~785.70 78t3.07 7840.69 7864.06 7893.13 79t7.48 7943.34 120.12 5.58 WND 6-axis i20.18 7.08 MWD - 120.36 2.20 NWD 6-axis i20.49 1.65 RfWD 6-axis 120.61 7,84 MWD 6-axis 120.72 1,36 WWD 6-axis i20.84 2,86 MWD 6-axis 120.95 1,79 ~WD 6-axis 121.06 5,27 MWD 6-axis 121. I9 3,03 MWD 6-axis 121.31 1,26 ~WD 6-axis I21.41 2.75 MWD 6-axis 121.54 2.45 ~WD 6-axis !21.65 3.29 MWD 6-axis 121,77 8.18_ '~W~_. 6-axis REC :IVE 0il & Gas gons. Gommission ANADRILL SCHLUMBERGER Survey Report Seq MeaSured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 181 12094.86 90.31 151.74 182 12125.31 90.48 153.21 183 12154.28 88.83 153.66 184 12188,35 88.77 154.66 185 12219,99 89,04 152.41 186 12248,91 89,11 152.73 187 12281,01 89,07 153.80 188 12312,85 89,07 152.05 189 12342.52 89,35 152.30 190 123~3,92 89,62 152.77 course length (ft) 29.52 30.45 28.97 34.07 31.64 28.92 32.10 31.84 29.67 31.40 191 12405,24 89,55 154.45 192 12435,10 89,62 153.67 193 12467.84 89.83 151.79 194 12499,52 90,03 154.35 195 12528,90 90,31 152.32 196 12542,23 90,45 152.44 31.~2 29.86 32.74 31.68 29.38 13.33 Projected to TD of 12600 ft: 197 12600,00 90,45 152.44 57.77 TVD depth (ft) 6944.68 6944.47 6944.64 6945.36 6945.96 6946.43 6946.94 6947.46 6947.86 6948.15 6948.37 6948.59 6948.75 6948.79 6948.70 6948.61 6948.16 21-Oct-1999 09:01:31 Vertical Displ Displ Section +N/S- +E/W- (ft) ' (fh) (ft) 6896.50 -4207.70 6767.47 6926.94 -4234.70 6781.54 6955.90 -4260.61 6794.49 6989.94 -4291.27 6809.34 7021.56 -4319.58 6823.44 7050.47 24345.25 7082.56 -4373.91 7114.39 -4402.26 7144.06 -4428.49 7175.45 -4456.35 6836.76 6851.20 6865.69 6879.53 6894.02 7206.76 -4484.41 7236.60 -4511.26 7269.33 -4540.36 7301.00 -4568.60 7330.37 -4594.86 6907.94 6921.00 6936.00 6950.34 6963.53 7343.70 74606.67 6969.71 7401.47 ~4657.88 6996.44 Page 8 of 8 Total At DLS ~rvy displ Azim (deg/ tool (ft) (deg) 100f) type 7968.90 121.87 0.64 MWD 7995.12 121.98 4.86 MWD 8019.85 122.09 5.90 NWD 8048.73 122.22 2.94 MWD 8075.77 122.34 7.16 MWD 8100.77 122.44 1.13 MWD 8128.35 122.55 3.34 MWD 8155.83 122.67 5.50 MWD 8181.66 122.77 1.27 NWD 8208.93 122.88 1.73 MWD 8235.87 122.99 5.37 NWD 8261.46 123. t0 2.62 MWD 8289.93 123.21 5.78 MWD 8317.42 123.32 8.11 MWD 8342.87 123.42 6.97 MWD 8354.53 123.46 1,38 MWD 8405.I1 123.65 0,00 ~WD Tool ual ype 6-axis 6-axis 6-axis ~-~xis 6-axis 6-axis 6-axis 6-axis 6-axis 6-~xis 6-axis 6-~xis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 0c 07] REC, VED f',!©V 1 999 Alaska Oil & Gas Cons. Commission Anchorage Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kupamk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files 11/30/99 Scblmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12973 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-26 ~ ~ "~ ~ ~o 99422 c]~ e Tt~PO~.S~. (~9C) 991004 1 CD1-26 99422 MD CDR & IMPULSE 991004 I 1 CD1-26 99422 .TVD CDR & IMPULSE 991004 I 1 CD1-16 Pa1 .~ ~ ~ '~.. 99423 ~C~/~/~ 991012 1 CD1-16 PB1 99423 MD CDR 991012 I 1 CD1-16 PB1 99423 TVD CDR 991012 I 1 CD1-16 PB1 99423 MD ADN 991012 I 1 CD1-16 PB1 99423 TVD ADN 991012 I I ' .,' ~0 'i999 SlGNr=D ~ DAT£: ' ,A~ Oil & Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 11/24/99 Scklumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12965 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Well Job # Log Description Date BL Sepia Color Prints CD CD1-16 -~ qo~.,r"I [ 99424 CDR/ADN (t'DC) 991021 1 CD1-16 99424 MD CDR-IMPULSE 991021 I 1 CD1-16 99424 TVD CDR-IMPULSE 991021 I 1 CD1-45 PH -~ ~-('~'7'~ 99425 CDR/~N/GR 991029 1 CD1-45 PH 99425 MD CDR 991029 I 1 CD1-45 PH 99425 TVD CDR 991029 I 1 CD1-45 PH 99425 MD ADN 991029 1 1 CD1-45 PH 99425 TVD ADN 991029 I I Please sign and return one copy o! this transmittal to Sherrie at the above address or fax to {007) 551-8317. Thank you. ~ ",'.; E'~O 'i999 Alaska 0il & Gas (,0no. L;o{~missi{~i"~ MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. ~' Octl~ Dispatched To: AOGCC Well No CD1-16 Date Dispatche 22-Oct-99 Installation/Rig Doyon 19 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEIVED "~.',, 3 21999 Ala~ ~a 0il & (~as Co~ ~, Commi~ion Ancllom~ e 'Received Bg: Please sign and return to: Anadrill LWD Division 3940 Arctic Bird Anchorage, Alaska 99503 Email: jleblanc@slb.com Fax: 907-561-8417 LWD Log Delivery Vl. 1, Dec '97 Colville River Field CD1-16 Injection Well Completion Plan 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2628' MD / 2399' TVD cemented to surface PRESENT WELL STATUS: 7" CASING RUN AND CEMENTED. TD AND COMPLETION DETAILS ARE AS PER LATEST PLAN. 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope Packer Fluid: 9.6 ppg KCL brine with diesel to 2000' TVD = 2084' MD Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components CD1-16PB1 - cement kick off plug at 8436' MD Est. TOC @ +/-8600' MD Baker Model S-3 Packer (3.875" ID) at +/- 8900' MD (Wireline Entry Guide at +/- 9000') TD at +/- 12600' MD / 6945' TVD 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 9595' MD / 6948' TVD (90 deg) Updated 10/20/99 Re. CDI-16 Packer Setting Depth Subject: Re: CDI-16 Packer Setting Depth Date: Thu, 21 Oct 1999 10:43:50-0800 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Adrnin, Oil & Gas To: Michael D Erwin <MERWIN~maihaai.arco.com> CC: Brian Robertson <BROBERT4~maihaai.arco.com>, Douglas K Chester <DCHESTER~maihaai.arco.com> Mike, ~r~o~ I noticed that I did not respond to this e-mail, tho you and I~did talk about it when you were over here for the meeting on Tuesday the 19th (?). In this case, yes move the packer and tail pipe up hole as you proposed below and we discussed on the 19th. If you have questions, please call me at 793-1226. Blair Wondzell Michael D Erwin wrote: Blair, We are looking for you thoughts on this completion design before we get to running it the end of this week. We found ourselves in a situation where we could not build angle as proposed, and now have higher inclination angles immediately above the Alpine formation. If we run our normal completion spacing, with tail pipe 100' above the formation we would not be able to wireline into the nipple profile. To remedy it, I do not recommend we shorten the tailpipe as considered below, but would prefer to move the packer up a bit higher. Final location of the packer ,due to inclination angles, would be approx 8900' FiD, or 430'+/- above the Alpine formation top. Feel free to call as we can discuss this further if you wish. Perhaps I'll see you at the hearing later this am. thanks ! mike Forwarded by Michael D Erwin/AAI/ARCO on 10/19/99 08:10 AM Brian Robertson 10/18/99 04:23 PM To: Michael D Erwin/AAI/ARCO~RCO cc: Douglas K Chester/AAI/ARCO~3LRCO :~, Subject: CDI-16 Packer Setting Depth " Mike, I'd like to propose that we position our wireline entry guide at +/- 9000' FiD / 6788' ~D / 61 deg inclination. This will allow approximately 100' FiD where we can be assured of obtaining wireline conveyed cement evaluation logs above the top of the Alpine (note at 9123' FiD / 6840' TVD the inclination is 66.3 deg). Note that the top of the Alpine is +/-9335' ~iD / 6909' TVD / 77 deg inclination. I'd also like to propose that we shorten the tailpipe to place the packer as Iow in the well as possible. I propose that we drop at least one of the joints above the nipple and use a 10' pup joint between the nipple and the wireline entry guide. This would place the packer at +/- 8960' ~4D / 6767' TVD / 59 deg inclination. By shortening the tailpipe we will be maximizing the casing coverage - as desired by the AOGCC. Also note that during cement job we had full returns and the job went without a hitch. I therefore have no reason to believe that we will not obtain a very good USIT log (indicating good isolation) at this shallower depth. Please let me know if you require further information before we talk to the 1 of 2 10/21/99 10:44 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection - X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 56' feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 330' FNL, 2468' FWL, Sec.5, T11 N, R5E, UM CD1-16 At target (7" casing point in Alpine)) 9. Permit number / approval number 2290' FNL, 2526' FEL, Sec.4, T11N, R5E, UM .... per APD 99-94 At effective depth 10. APl number 50-103-20306 At total depth 11. Field / Pool 101' FNL, 890' FEL, Sec.9, T11N, R5E, UM ...... per APD Colville River Field/j;~o~,CBiC~°~ 12. Present well condition summary '" ~l~ r~, Total depth: measured 12600 feet Planned depth at TD. true vertical 6945 feet 00T 2 Effective depth: measured 12600 feet Planned depth at TD. 0il & Gas Cons. C0mm'tssi0~ true vertical 6945 feet ~1~),~1, /~ch0ra~e ' casing Length Size Cemented Measured Depth - ~ rue ver"dcal Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2591' 9.625" 425 sx ASL3, 234 sx Class G 2628' 2399' Production 9562' 7" 140 sx Class G 9595' 6948' CD1-16 is planned as an open hole injection well. At time of submission, the 7" casing has just been run and cemented in place. After drilling the horizontal hole section, the well will be displaced to completion brine and completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: October 23, 1999 16. If proposal was verbally approved Oil _ Gas _ Suspended __ Name of approver Date approved Service X 17. I hereby cedlty that~e foregoing is true and correcl to the best of my knowledge. Signed ~// __/I/J/!A ~11~,/~ lltle~-~rilling Team Leader Date FOR COMMISSION USE ONL Y I Approval no~jp Conditions of approval-:~otify Commission so representative may witness Plug integrity _ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~ ~ ORIGINAL SIGNED-BY Approve.(~.by order of the Commission Robert N. Christenson commissioner Date / ..... , .~,,~ " , -,.o® -66 ,' Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc..-~. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 20, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-16 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-16 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is proposed that this annulus be used to inject fluid returned from the next programmed well (CD1-45), which is expected to spud around the 23rd of October. Please find attached form 10-403 and other pertinent information as follows: , 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-16 Well Suspension Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely.~.~ Brian Robertson Senior Drilling Engineer CC. CD1-16 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko · Casing Detail ~f Well: CD1-14 9 5/8" Surface Casin~7 Date: 10/6/99 ARCO Alaska, Inc. Subsidiary of Atlar Subsidiary of Atlantic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Land Ring 37.40 FMC Gen V Hanger 2.36 37.40 Jts 3 to 61 59 Jts 9 5/8" 36# J-55 BTC Csg 2500.79 39.76 Davis Lynch Float Collar 1.55 2540.55 Jts 1 to 2 2 Jts 9 5/8" 36# J-55 BTC Csg 84.72 2542.10 Davis Lynch Float Shoe 1.75 2626.82 2628.57 35 - Bow Spring Centralizers Jt #1 - 12 Jt# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38 40, 42, 44, 46, 48, 50, 52, 54, 56, 58 Leave 7 jts in the shed #62-#68 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 155k Dn Wt - 140k Block Wt - 70k Supervisor: Donald Lutrick ARCO Alaska, Inc. Cementing Details Well Name: CD1-16 Report Date: 10/07/99 Report Number: 3 Rip Name: Doyon 19 AFC No.: 998B14 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: % washout: 9 5/8" 12.25 46 deg at TDI 2628' 2641' Centralizers State ~ype used, intervals covered and spacing Comments: 35 Bow Springs. Jt #1~12 and every other jt to surface. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.1/9.8 29 16 40 21 Gels before: Gels after: Total Volume Cimulated: 23/39/53 7/38/46 1200 bbls Wash 0 Type: Volume: Weight: Comments: GELH20 50 8.4 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LWI 70 425I 10.7 4.42 Additives: D053 -30.0 %, D046 - 0.6%, D079 - 1.5%, S001 - 1.5 %, D124 - 50.0%, D044 - 9.0 % Tail Cement 0 Type: I Mix wtr temp: I No. of Sacks: Weight: Yield: Comments: GI 70I 234 15.8 1.15 Additives: D046 - 0.2 %, D065 - 0.3%, S001 - 0.1% Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 9.5 bpm 9.5 bpm 150k Reciprocation length: Reciprocation speed: Str. Wt. Down: 15' 10 fpm 140k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 197 197 Calculated top of cement: CP: Bumped plug: Floats held: surface Date:10-7~99 yes no Time:16:20 Remarks:Had no hole problems while RIH. Circ and condition mud at 10 bpm w/no losses. Pumped entire job w/100% returns. 65 bbls 10.7 cement to surface. Floats did not hold. Pressure csg to 1000 psi for 4 hrs. Bleed off OK. Cement Company: Rig Contractor: Approved By: DOYON Dona d Lutr ck DS Daily Drilling Report ARCO Alaska, Inc. I Date Rpt No '1 Rig Accept - hrs Days Since Accept/Est: 2.75 / 3 AFC No. 998B14 J 10107/99 3 J 10/05/99 06:00:00 Rig Relase - hrs: I lAM Well: CD1-16 Depth (MD/'TVD) 2638/2406 Prev Depth MD: 2638 Progress: 0 Contractor: DOYON Daily Cost $ 216565 Cum Cost $ 513210 Est Cost To Date $ 500000 Ri~l Name: Doyon 19 Last Cs~l: 9 5/8" @ 2628' Next Csg: 7" @9442' Shoe Test: rea Operation At 0600: MU BHA Upcoming Operations: Csg test, LOT. Drill Ahead MUD DATA DRILLING DATA BIT DATA EH&S : i DRILLS/BOP DATA: : MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSN D I N TST 10105/99 SIZE 10/05/99 WEIGHT ROT WT SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6pp~l 12.25 09/23199 09/28/99 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 45sqc HTC N SPACE 09/27/99 06/21/99 PV/YP SO VVT TYPE TYPE TYPE : FUEL & WATER : GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2560 8/12/13 B75ZC APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 270 8.6 2638 10/05/99 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 85 mi/30 Tin 114 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ~ ' WEATHER &' 6.5% 2524 CD1-39 : i PERSONNELDATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 29 178bbl III 16.22/6.02 / CD1-16 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 19 10 1 I 2 I I 20- 35 3,0 3h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 80° 9.5 s.s 161 I 183- 263 1000 LGS SPM I TFA TFA INJECTION FLUIDS CHILL FACTOR °F 3.55 1.5% III .594 Water Base Muds 983 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 1 65o III lS11511511ol I IIIII 40 Other 90 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 24 $7696 III 12000 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 1 $16026 I I 2141FC IA I I I 1113 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 10 MI I I E II I ER lTD I I I 10317 PERSONNEL TOTAL 36 TIME I END HOURS I CPS CODE I HOLE SECT IPHASE CPS I : :: :::,: OPERATIONSFROMO000;O000 12:00 AM 01:30 AM 1.50 WlPERTRP SURF Making Hole Cont' POH to HWDP. RIH to TD. 01:30 AM 03:00 AM 1.50 ClRC SURF Making Hole Circ and condition mud. 03:00 AM 04:30 AM 1.50 TRIP_OUT SURF Making Hole POH. No problems. 04:30 AM 06:30 AM 2.00 BHA SURF Making Hole LD BHA. 06:30 AM 12:00 PM 5.50 CASG SURF Casing and Clear floor. Rig up to run csg. PJSM. RIH w/9 5/8" csg. CBU Cementing at 1534'. 12:00 PM 12:30 PM 0.50 CASG SURF Casing and MU hanger. Land csg at 2628'. MU cement head. Cementing 12:30 PM 02:30 PM 2.00 ClRC SURF Casing and Circ and condition mud at 10 bpm w/no mud loss. Cementing 02:30 PM 04:30 PM 2.00 CEMENT SURF Casing and Pump 50 bbls viscosofied water w/Ted nut plug for Cementing marker. Test lines to 2500 psi. Dowell pumped 50 bbls spacer, 425 sx Lead (334 bbls), 234 sx tail (48 bbls). Displaced wi mud w/rig pumps. Bumped plug. Floats did not hold, Pressure csg to 1000 psi. SI. 04:30 PM 08:30 PM 4.00 PRB_MISC SURF Casing and WOC Cementing 08:30 PM 10:00 PM 1.50 OTHER SURF Other Bled off press. OK. LD LJ. Flush out diverter. Clear floor. 10:00 PM 11:00 PM 1.00 NU_ND SURF Other ND diverter. 11:00 PM 11:30 PM 0.50 NU_ND SURF Other Install well head. Daily Drilling Report: CD1-16 10/07/99 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-16 Date: 10/8/99 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,628' TMD -- 2,399' TVD Hole Depth: 2,688' TMD 2,442' TVD Mud Weight: 9.7 ppg Length of Open Hole: 60' 785 785 psi EMW - + Mud Weight = + 9.7 ppg 0.052 x 2399 o.o52 x 2,399' EMW = 15.9 ppg Pump output = .101 BPS Fluid Pumped = 1.1 BBL BLED BACK =.8 BBLS TIMEUNE 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,800 psi 2,200 psi -- 2,1 O0 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,800 psi 1,200 psi 1,1 O0 psi 1,000 psi 900 psi 800 psi 700 psi -- 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 86 stk stk stk stk stk stk stk slk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE 0 stks 110 psi 0 stks 100 psi 2 stks 230 psi 2 stks 320 psi ................................................. t i- .............. -~- ................................ .................... .4___s_t__k__s_ ...... _4__o__o___p_s_] ...................... __4__s__t.k__s_ ...... .?_4..o..R.s)...j 6 stks 540 psi 6 stks 870 psi , ............... ~ ............... ~ ................. ~ ,. .............. .~. ............................... 8 stks 660 psi 8 stks 1,040 ps, 10 stks 770 psi 10 stks .__1_,_2__4_0___p__s_!.(' '- .............. '--'1--1--~'~(-~--'---:~§[i--I~-~---" ................. ¥~-~;~i~-- 1,450 psit~L .............................. · ~ ................. i- .............. ..i- ................................ ..................................................................... Lk..s. .... ! ............... 1 ............... .1 ................. y ............... .i ............... .i ................. · ..i I SHUT IN TIME J SHUT IN PRESSURE .................. ._.2_..o...m.j_n. .................. j....7__5..o_.p.s_i._ 3.0 min i 740 psi 4.0 min.: 730 psi 5.0 m~n ~i ,,, 720 16 stks 1,920 psi .................. .... ,_ 20 stks 2,400 psi ............... --r- ................................ .1 .................. ._2.!_.s__t.k_.s- .... .............. .J. ............... ............... .2. ............... i. ................ .i SHUT IN TIME '''r' ................................ I ................................. .2_,_5_9.9_p__s_L.1 5.0 min 2,470 psi 15.0 min . 2,430 psi '-~'~)'.'~'~J'~" 2,420 psi: _.3.g:.o....m.i..n. ................... .2.,.4.1_o..R.s.!.{ ............... "J'l ................................. 7.0 min ~ j 710 psi , . ................ ., .......... -.--.- j ............... , ............. ~ ................... -j. ............... 8.0m~n , : 710ps, ................ ! ............... ! ................. ! ............... 9.0min , , 710psi , : ............... 1 ............... -{ ................................................................ ._j.o_:_o...m.j.n__! ............... j___Z.o..o...p, sj...! ................ ~ ............... [ ................. NOTE: STROKES TURN TO MINuTEs DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY · CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-16 Date: 10/16/99 Supervisor: MIKE WHITELEY [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X 7" 26# L80 BTC MOD Casing Setting Depth: 2,628' TMD Hole Depth: 9,595' TMD 2,399' TVD ~ Mud Weight: 9.7 ppg Length of Open Hole: 5,259' 560 560 psi EMW = + Mud Weight = + 9.7 ppg 0.052 x 2450 .052 x 2450 EMW = 14.1 ppg Fluid Pumped = 10.0 bbl BLED BACK =3.25 bbl 700 psi 600 psi 500 psi m 400 psi ~.. 300 psi 2o0 ps~ t --- // .-e-- LEAK-OFF TEST --- / -'e--CASING TEST .......... ~.,,,,,- LOT SHUT IN TIME 100 psi -- -- -4~- CASING TEST SHUT IN TIME ~ TIME LINE 0 psi I I I I 0 stk 3 stk 6 stk 9 stk 12 stk 15 stk 18 stk 21 stk 24 stk 27 stk 30 stk 33 stk STROKES NOTE: STROKES TURN TO MINuTEs DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES 0BBLS 0 psi 40 psi 1 ! 70 psi BBLSi 130 psi 2.0 BBLSi 180 psi CA TEST DATA FOR CSG TEST STROKES PRESSURE 0 stks ............... ~ ............... i,. ................ r ............................................ -~ r 2.5 BBLSi 250 psi 3.0 BBLS 290 psi 3.5 BBLS 350 psi ............... ~ ................................. ~ ................................................ ................. _4_.__0_._B._B__L..S_ .... .4__2..o_._p_sj ..................................................... 4.5 BBLS 470 psi ................. ~..0...B..B.._S__ .... .sJ..o.._p.s.j .................................................... 5.5 BBLS 560 psi i ............... ~ ................................. r .............. ~- ............... r ................. 6.0 BBLS 585 psi 6.5BBLS 610 psi i ............... J ............... J ................. & ~ .............. -~ ............... ~ ................ J ................... Z:.0..B..B..L..s_ ...... ~_~..L.p. sj ...................................................... ................ Z...S..~.~.L..S. .... ~_S_.~__.p.s..~ ..................................................... ................. ~..9...B..B._L..s. .... ~.L.P. SJ .... ............... · .,i- ............... r, ................ ,-i ............... ..~....S...B...B_.L__S_ .... ~.S.f...r,.s.j ...................................................... 9.0 BBLS 600 psi [ J ,J · ~. .J i ............................................... i. .............. ..4.. ............................... 9.5 BBLS 586 psi ~ 10.0 BBLS 613 psi SHUTIN TIME ................................................. I ................................................. ............... · ~ ............... ,.~ ................. ~1 ~. .............. ~ ................................. I I ~. .............. .L. ............... ~ ................. ...................................0.0 min '~§[~'~'~1'"[ : ................................................. 1' ............................... Ir 1.0 min 515 psi j , ................................................. · ............... -i,- ............... i- ................ ,.~ ...2_. p_m. j.n. ...................... ~.o.L.p. sj._! ................................ , .................. 3.0 min 490 psi i ........... ~ .... '~ ............... 'l ............. ':---t '- .............. '~ ................ ~ ................. 4.0m~n ~ 481ps, ~ ............... · i ............... ~ ................. t ............................... " ................. mb ' ' ' 5.0 , 471pst ~ ............... r .............. T ............... i ................. .............................. ,-i ............. ~---f i ............... -!.. ............................... · i i i ~ ._.7...0...m..I.n...: ............... .,___.4..5..8. p._..s.!.__,. ~. ............................... ., ................. 8.0min [ ~ 453psi J ~ I ............................... -I ............. ~---t I ............... -f- ............... I- ................ -I : 90min ~ : 449 DSt : : : ~ , · ~ , ,- .............. 4 ............... 4 ................. t ,- .............. -I- ............... I- ................ -I I ' i I ' ! i i i LJ.°.:.°__.m.j.n..i ............... ,'_...4--4..4..-P.S-!.__t ',.. .............. z ............... ,'.. ................ .,' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-16 Date: 10./16/99 Supervisor: MIKE WHITELEY Reason(s) for test: I--I Initial CAsing Shoe Test [] Formalion Adequancy for Annular injection f-'] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36~ J-55 BTC CSG X 7" 26# LB0 ElTO MOD Casing Setling Oepth: 2,628' TMD 2,399' TVD 7" Shoe Deplh: 9,595' TMD 6,948' TVD Mud Weight: 9.7 PPg . Length of Open Hole: 5,972' EMW: 560 560 psi + Mud Weight _ + 9.7 ppg 0.052 x 2399 .o52 X 2399 EMW = 14.2 ppg '21~ p:[ UD3 Fluid Pumped = 10.0 bbl .... BLED BACK jl'l ME LINE 1 · : ' ' ~ /'lONe m,~te~c~s I ' · -LO1 SHUT IN TIME J .:,.. --..-- CASING ~ESI' SHUt IN TIME J'--: / I --6- ...... ! -~. r ' ~ - ~ , ,' -- ~OK~ LEAK-OFF DATA MIN UTES FOR LOT STROKES PRESSURE 0,5 BBLS,. 40psi .............. 2.0 BBLS 180 psi CASING TEST DATA FOR CSGTEST SI'ROKES PRESSURE F .............. "m ............. ~' .............. 'i ~. ........... 4..._o__~.LL~..4 ................ i ! i mm ~ I ~...~ ......... .,m.... ............. ~ ............ 1' ............ *. ............. ! ..............I .............. iG._O_.8..~..L..S.. 585 psi i 6.SBBLS 610 psi j ,' ............... ~l~i~§-~'-~-33 psi '[ '. .............. £T:.f. ~A.L..S.J__~.3. ..P.s.!__i i 18,0BBLS 641 psi ~ .............. ............... ................ i~:-~-~-~r~r--~-~-a.--: ::::::::::: t .............. i ............................... i-'~:a'~'~"l ............... T.Z'~r"! :--i:~';~',.~"~ ............. ~_ ~'~i'"!: . ......... ~ .... . ....................:---, 2.0 mmn ~ ~ 503 psi l'"~:a-~a"i ............... ,-;i~ii)¥a--'[ i .............. r--~:'~-~-~q .............. F~--~-a-'-! i ............. T ............ I ................ ! i 5.0rain j :,. 471 psi i'-'~U'F~i-~"i .............. i -~-I~',~i'"[ i- ............. '-[ ............ 4 .............. l"~:~'~f~"] ............... ,T'-;i~"['i,;i'"~ ' , ' / r i i t 9.0mln , I 449pm , ........... ~ .............. ~ ......... 10.0 min't : 444 psi ] ] [ j | NOTE: STRCKES TURN 'TO MINUTES DURING "SHUT IN T!ME":see time fbe above NOTE' TO CLEAR DATA, HIGHLIGHT AND PRESS THE OELETE KEY MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-16PB1 --~,'~ ' © Date Dispatche 18-Oct-99 Installation/Rig Doyon 19 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEIVED ,~.,,? 2' 1999 A~~ OI & Gas Cc ns. Commission Ancho~ ~e Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Bird Anchorage, Alaska 99503 Email: jleblanc@slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 _ TONYKNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 30. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Doug Chester Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Colville River Unit CD 1-16 ARCO Alaska, Inc. Permit No: 99-094 Sur. Loc. 330'FNL. 2468'1%VL. Sec. 5, T11N. R5E. UM Btmhole Loc. 101'FNL. 890'FEL. Sec. 9. TllN. R5E. UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste ~x411 be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records. FIT data. and anv CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission may witness the tests. Notice mav be given bv contacting the Commission petroleum field inspector on the lXjorth Slope pager at 659-3607. Sincere v~. -~ /~7_~/ Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC~ Department of Fish & Game, Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen[ Service X Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation ,fr~,~ Alpine Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL-Er"J¢-'-'-'-'-'-~ 37~0 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 330' FNL, 2468' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 2290' FNL, 2526' FEL, Sec. 4, T11N, R5E, UM CD1-16 #U-630610 At total depth 9. Approximate spud date Amount 101' FNL, 890' FEL, Sec. 9, T11N, R5E, UM 10/01/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 13 13,082' MD Crosses Sec4 to feet 23.2' @ 660' Feet 2560 6,966' TVD feet Sec 9, T11N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 90° Maximum surface 2454 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantit7 of cement Hole Casing Wei~lht Grade Coupling Length MD TVD MD TVD /include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2599' 37' 37' 2636' 2400' 498 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9544' 37' 37' 9581' 6966' 139 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9043' 37' 37' 9080' 6826' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface O~/G/~~ Intermediate Production Liner Perforation depth: measured true vertical , ,: 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Ddlling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 ,&AC 25.050 requirements X 21. I herebyceTattheforegoing~,~,~~istrueandcorrecttothebestofmyknowledge Signed ~ '""" r ~'~- ~J'r ~ Title Drilling Team Leader Date Permit Number APl number Approval date ~.7~ See cover letter for ~" ~ - ~ ~ 50- ~/(:~,_-~ -- .2.. ~ _.~ ~' - Other requirements Con~liti°ns of approval Samples required Yes ~) Mud Icg required Yes Hydrogen sulfide measures Yes ~ Directional survey required ~-'~'~'~.,,) No Required working pressure for ROPE 2M ('~1~I) 5M 10M 15M v Other: ORIGINAL SIGNED BY Robert N. Chfistenson by order of .... ~-~' Commissioner the commission Date -'/ Approved by Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine: CD1-16PB1 (Pilot Hole) ~.- ~C)1-16 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 Y2" hole to a point +/- 120' below the base of the Alpine Sand. Set 500 ft cement plug #1 from TD to +/- 8942'. Set 500 ft cement plug #2 from +/- 8942' to +/- 8442'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 8730' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. 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. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 1/2, 12.6 #, L-80 tubing with production packer. Land hanger. Install BPV. Nipple down BOP. Install tubing head adapter assembly. Remove BPV. Install test plug. Pressure test adapter assembly to 5000 psi. Remove test plug. Circulate in inhibited brine and diesel freeze protection. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Set BPV and secure well. Move rig off. This well will be logged through tubing with a CBL/GR/CCL to determine cement isolation above the top of the Alpine. This logging will be done after the rig moves off location. , 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 13. 14. 15. 16. 17. 18. 19. Note: Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-13 will be the closest well to CD1-16 (23.2' at 660' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 19.4' at 680' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. However, there are no faults progosed within 500 ft of the proposed target polygon. Good drilling practices will be followed to ensure that mechanically induced losses are kept to a minimum. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-16 will be injected into the annulus of a permitted well. The CD1-16 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-16 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi CD1-16 & CD1-16 PB1 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 ~" Section - 6 1/8" point- 12 ¼" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 18 - 22 10 minute gels <18 23 - 27 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at +_ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 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 Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Treat mud with fluid loss additives prior to coring. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with +_ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. Colville River Field CD 1-16PB1 Pilot Hole - Prior to Sidetracking RKB - GL: 37' 9.8 ppg drilling mud in hole Top Alpine Reservoir at 9164' MD / 6914' TVD (+/- 46 deg inc.) Pilot Hole TD at 9442' MD / 7106' TVD (+/- 46 deg inc.) 16" 4' Conductor to 11 Surface Casing 2636' MD / 2400' TVD cemented to surface Cement Plug Top of cement plug dressed off to 8730' MD / 6724' TVD (+/- 46 deg inc.) -- Top of Cement Plug #1 at +/- 8942' Updated 9/1 3/99 Colville River Field CD 1-16 Completion Plan 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2636' MD / 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope Packer Fluid: 9.6 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components CD1-16PB1 - cement kick off plug at 8730' MD TOC @ +/-8780' MD (Minimum of 500' MD above top Alpine) Baker Model S-3 Packer (3.875" iD) at +/- 9080' MD (Wireline Entry Guide +100' above top Alpine) TD at 13082' MD / 6966' TVD '~'~iiii~iii!iiiiii~:.~,~, .... 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 9581' MD / 6966' TVD (90 deg) Updated 9/13/99 Colville River Field CD1-16 Completion with Isolation Contingency Options 16" Conductor @ 114' MD RKB - GL = 37' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2636' MD / 2400' TVD cemented to surface Packer Fluid: 9.6 ppg KCL brine with diesel to 1200' 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide TOC @ +/-8780' MD (500' MD above Alpine)"~:!i!i Tubing tail to include: 4-1/2' Tbg Joints (2) HES 'XN' (3.725' ID) 4-1/2' Tbg Joint (1) and WLEG Note-Baker-lock all components Baker Model S-3 Packer (3.875' ID) at +/- 9080' MD (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe 7" 26 ppf L-80 BTC Mod Production Casing @ 9581' MD / 6966' TVD (92 deg) TD at 13082' MD / 6966' TVD Updated 9/13/99 CD1-16 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 the Alpine CD1-16 well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MDFFVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2636 / 2400 14.2 1086 1532 7" 9581 / 6966 16.0 3151 2454 N/A 13082 / 6966 16.0 3151 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the 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) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of 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 = [(10.9 x 0.052)-0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3151 - (0.1 x 6966') = 2454 psi 3. Drilling below intermediate casing (7") ASP = FPP- (0.1 x D) = 3151 - (0.1 x 6966') = 2454 psi Alpine CD1-16 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 -3500 P( -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpine, CDI~-~6PB1 & CD1-16 Well Cementinq I~quirements 9 5/8" Surface Casing run to 2636 MD / 2400' TVD. Cement from 2636' MD to 2136' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2136' to surface with Arctic Set Lite 3. Assume 500% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2136'-858') X 0.3132 ft3/ft X 1.5 (50% excess) = 600.4 ft3 below permafrost 858' X 0.3132 ft3/ft X 6 (500% excess) - 1612.4 ft3 above permafrost Total volume = 600.4 + 1612.4 = 2212.8 ft~ => 498 Sx @ 4.44 ft3/sk System: Tail slurry: 498 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 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 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 9581' MD / 6966' TVD Cement from 9581' MD to +/- 8780' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9581'- 8780')o X 0.1268 ft3/ft X 1.4 (40% excess) = 142.2 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft3 shoe joint volume Total volume = 142.2 + 17.2 = 159.4 ft3 => 139 Sx @ 1.15 ft3/sk System: 139 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 1.15 ft3/sk CD1-16PB1 Cement Plug #1: 9442' MD to 8942' MD = 500'. Cement from 9442' MD (CD1-16 PB1 total depth) to 8942' with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 ft3 => 197 Sx @ 1.15 ft3/sk CD1-16PB1 Cement Plug #2: 8942' MD to 8442' MD = 500'. Cement from 8942' MD to 8442' MD (288' MD above the sidetrack depth of 8730') with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 ft3 => 227 sx @ 1.00 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement Alaska, I Sfrucfure : CD#1 Field : Alpine Field Well : 16PB1 Location : Norfh Slope, Alaska 400 400 800 1200 1600 2000 2400 2800 Q_ ~ 5200 5600 ~oo 44o0 5200 5800 6000 6400 6800 7200 7600 40O RK8 Elevotlon: 56' KOP 2.00 4,00 DLS: 2.00 deg per 100 ff. 6.00 End InlUol Bid Permofrost Wesf, Sok 9,99 Begin Trn to 12.98 15.98 18.98 21.97 24.97 DIS: 3.00 deg per 100 ft 27.97 50.97 53.97 59.97 C40 45.97 EOC 9 5/8 Cosing C50 C20 Crea[ed by jor~s For: ti Roberteon Dote pl~ted : 8-5~-19~ Plot ~femn~ C~[nates o~ in feet ~emn~ ~t ~lB. [ Tree Ve~l D~s a~ ~ CO~n ~19). 106.84 AZIMUTH 5732' (TO TD) ***Plane of Proposal*** K-5 K-2 AVERAGE ANGLE 46.26 DEG Albion -97 Albion-96 HRZ KOP - Sider,rock Miluveoch A Alpine D Top Alpine Bose Alpin ~ ~ TD i i i i i 0 400 800 I [ II I I I I I I II I II I II I I 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 Verficol Section (feel) -> Azimufh 106.84 wifh reference 0.00 S, 0.00 E from slof #16 i i i i r i 5200 5600 6000 cre=t~ ~t io.~ For: B Robert~on Dote plotted: B-5ep-199r~ Plot Reference Es 16 Version ~rdlnatls are In f~t rlfarln~ alot ~16. I ITru. V. rflcal ~p,h ..... E~ RKB (D~n ,19).I I I INT~Q I ARCO Alaska, Inc. Structure : CD#I Well : 16 400 ~. 800 12o0 160o 2000 2400 2800 52oo 1200 16oo 400 800 ~\~b 330' FNL, 246B' FWL SEC. 5, T11N, RSE Q) 2000 (D c' 2400 0 U3 2800 I V 3200 3600 4000 Field : Alpine Field Location : North Slope, Alaska East (feet) -> ,3600 4000 4400 4600 5200 5600 6000 6400 6800 7200 7600 400 0 CD1-16 PB1 TD LOCATION: 2008' FNL, 2616' FEL SEC. 4, T11N, R5E /. TGT - EOC - CsgPt CD1-16 TD LOCATION: 101' FNL, 890' FEL SEC. 9, T11N, R5E 4400 4800 5200 CD1-16 CASING PT LOCATION: 2290' FNL, 2526' FEL SEC. 4, T11N, RSE I I I I I I I I I I I I I I I I I [ I I I I I I I I I I I I I I [ I I I I I I I 400 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 East (feet) -> 400 800 1200 1600 2000 0 2400 --h .-i- 2800 v I v 3200 5600 4000 4400 4800 5200 Cmcted ~W j~es For: B Rober~on Do~e plotled: B-~p-199B ~rdlnotes ore rn fm~t reference =lot ~16. I ITrue V. rtlcol ~pth ...... f~RKB (O~n ,19).~ ARCO Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : 16PB1 Location : Nor-th Slope, Alaska Point KOP End Initial Bid Permafrost West Sak Begin Trn to Tgt C40 EOC 9 5/8 Casing C50 C20 K-3 K-2 Albian-97 Albian-96 HRZ K-1 LCU ,Miluveach A Alpine D Top Alpine Base Alpine TD Pt PROFIL MD 300.00 650.00 858.42 1049.85 1100.00 2320.92 2409.71 2655.55 2644.23 3164.92 4647.45 4980.11 7673.25 8147.66 8415.23 8827.45 8961.96 9100.81 9125.95 91 64.45 9270.04 9442.1 6 Inc 0.00 7.OO 7.0O 7.O0 7.00 43 60 46 26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 46.26 E COMMENT DATA Dir TVD North East V. Sect 112.00 300.00 0.00 0.00 0.00 112.00 649.15 -8.00 19.80 21.27 112.00 856.00 - 17.51 45.55 46.56 112.00 1046.00 -26.25 64.98 69.80 112.00 1095.78 -28.54 70.65 75.89 106.91 2181.00 - 184.18 559.14 588.52 106.84 2245.86 -202.38 619.14 651.22 106.84 2400.00 -249.65 775..31 81 4.58 106.84 2406.00 -251.47 781 .,31 820.65 106.84 2766.00 -360.45 1141.37 1196.85 106.84 5791.00 -670.77 21 66.55 2267.95 106.84 4021.00 -740.40 2396.57 2508.29 106.84 5883.00 - 1504.12 4258.87 4454.04 106.84 6211.00 - 1 403.42 4586.92 4796.80 106.84 6396.00 -1459.43 4771.95 4990.12 106.84 6681.00 - 1545.71 5057.00 5287.94 106.84 6774.00 -1573.87 5150.02 5385.12 106.84 6870.00 - 1 602.95 5246.03 5485.44 106.84 6886.00 - 1 607.78 5262.03 5502.1 6 106.84 6914.00 -1616.25 5290.04 5531.42 106.84 6987.00 - 1 638.35 5563.05 5607.70 106.84 7106.00 - 1 674.38 5482.07 5732.05 Deg/lO0 2.00 0.00 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 ~! ~0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ARCO Alaska, Inc. Structure: CD#1 F~eld : Alpine Field Well : 16 Location : North Slope, Alaska 5000- 5200 5400 56O0 5800 6000 6200 6400 6600 68o0 7000 7200 7400 7600 151.94 AZIMUTH 7849' (T0 TD) ***Plane of Proposal~** ~, jo.,= For: B Robertson D~t. plott,d: ~-$,p-1999 Plot R~for~nc~ ~rdtnotH ore ;n fe~ r~eren~ clot ~16. \ \ X, Albion-96 \ HRZ b*q \ TARGET ANGLE 90 DEG KOP - Sidetrock Pt \ End Bid & Trn~ ,=5'~ q.~ K-1 '~. Continue Bid & Trn LCU Miluveoqh A X~ ~ ' Alpine D Alpine X ~~ , TD [ i i , i i i i [ i i i i i i i i [ [ i i i i i i i i i i i i i i i i i i i i , i i i i i i i i i i i i 3200 5400 3600 5800 4000 4200 4400 4600 4BO0 5000 5200 5400 5600 5BO0 6000 6200 6400 6600 6BO0 7000 7200 7400 7600 7800 BO00 82(: Verfical Section (feel) -> Azimuth 151.94 with reference 0.00 N, 0.00 E from slot #16 Crsot~d by ]oneaFOr: B Robertlton oaie platted: 8-.~p-199g Plot Refersnce I'a 16 Version 1~. Coordinates ars rn feet reference slot ~116. True Vertical Depths or~&r~l~:i~RKB (Ooyon ~lg). I ARCO Alaska, Inc. Structure: CD#1 Well : 16 Field : Alpine Field Location : North Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 KOP - Sidetrack Pt 8750.00 46.26 106.84 6613.63 -1525.32 4989.61 5692.92 0.00 End Bid & Trn 8794.56 52.04 107.57 6655.84 -1539.77 5036.23 3727.61 9.00 K-1 8835.47 52.04 107.57 6681.00 -1549.51 5066.99 5750.67 0.00 Continue Bid & Trn 8962.54 52.04 107.57 6759.15 - 1579.76 51 62.50 3822.29 0.00 LCU 8987.00 55.24 109.90 6774.00 -1586.01 5180.91 5856.46 ~.~0 Miluveach A 9169.00 63.30 125.15 6870.00 - 1 658.13 531 6.87 3964.05 9.00 Alpine D 9206.07 65.55 127.89 6886.00 -1678.02 5343.75 3994.24 9.00 Alpine 9280.55 70.18 133.09 6914.00 - 1722.70 5395.99 4058.25 9.00 TGT- EOC - CsgPt 9581.52 90.00 151.94 6966.00 -1956.59 5573.47 4348.15 9.00 TD 13081.70 90.00 151.94 6966.00 -5045.65 7219.84 7848.51 0.00 ARCO Alaska, Inc. CD~I 16PB1 slot #16 Alpine Field North Slope, A1 aska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 16 PB1 Vers. #1 Our ref : prop3560 License : Date printed : 8-Sep-1999 Date created : 31-Aug-1999 Last revised : 8-Sep-1999 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.863,w150 55 33.914 Slot Grid coordinates are N 5975798.867, E 385894.093 Slot local coordinates are 328.73 S 2468.93 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <O-8580'>,,Bergs2,Bergschrund#2 PMSS <1863.7896'>,,Bergs2A,Bergschrund #2 26 Version#6,,26,CD~1 26 PB1 Version #1,,26PB1,CD~1 PMSS <9146 - ???'>,,39,CD~1 PMSS <0.10224'>,,39PB1,CD~1 PMSS <0.12055'>,,40,CD~1 PMSS <562 - 12134'>,,37,CD#1 PMSS <384 - 14477'>,,23,CD~1 PMSS <0-11300'>,,13,CD~1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <O-7331'>,,1PB1,CD~1 PMSS <0-8168'>,,35,CD~1 PMSS <0-10796'>,,24,CD~1 PMSS <0-10548'>,,19,CD~1 PGMS <O-10255'>,,WD2,CD#1 PMSS <0-10255'>,,WD2,CD#1 PMSS <0-9236'>,,22,CD~1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 27-Aug-1999 5544.3 6540 18-Jun-1998 3560.1 7840 6-Sep-1999 2372.1 7300 31-Aug-1999 100.2 240 8-Sep-1999 230.0 100 5-Sep-1999 230.0 100 28-Jun-1999 240.1 100 26-Aug-1999 210.1 0 18-Aug-1999 58.4 940 15-Ju1-1999 23.2 660 27-~un-1999 149.5 220 18-~un-1999 149.5 220 28-Jun-1999 189.9 100 28-Jun-1999 57.6 1177 28-Jun-1999 29.8 100 28-2un-1999 1058.8 1522 28-2un-1999 1060.1 1500 28-~un-1999 60.4 100 0 7140. 0 7840. 0 7300. 0 240. 0 100. 0 100 0 100 0 0 0 940 0 9000 0 220 0 220 0 100 .8 1177 .0 100 .2 1522 .0 1500 .0 100 ARCO Alaska, Inc. CD~i 16 $1 ot #16 Alpine Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 16 Version#3 Our ref : prop3564 License : Date printed : 8-Sep-1999 Date created : 31-Aug-1999 Last revised : 8-Sep-1999 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.863,w150 55 33.914 Slot Grid coordinates are N 5975798.867, E 385894.093 Slot local coordinates are 328.73 S 2468.93 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-8580'>,,Bergs2,Bergschrund#2 PMSS <1863-7896'>,.Bergs2A,Bergschrund#2 26 PB1 Version #1,,26PB1,CD~l 26 Version~6,,26,CD~1 PMSS <9146 - ???'>,,39,CD~1 PMSS <O-10224'>,,39PB1,CD~l PMSS <562 - 12134'>,,37,CD~1 PMSS <384 - 14477'>,,23,CD~1 PMSS <0-11300'>,,13,CD~1 PMSS <5946 - 10289'>,,1,CD~1 PMSS <O-7331'>,,1PB1,CD~l PMSS <0-12055'>,,40,CD~1 PMSS <0-8168'>,,35,CD#1 PMSS <0-10796'>,,24,CD~1 PMSS <0-10548'>,,19,CD~1 PGMS <O-10255'>,,WD2,CD~1 PMSS <0-9236'>,,22,CD#1 Closest approach with 3-D Mini Last revised Distance M.D. 27-Aug-1999 4232.8 13081.7 10580 0 200 0 7300 0 100 0 100 0 O0 940 0 660 0 200 0 200 0 100 0 100 0 1177 8 100 0 1522 2 100 0 18-Jun-1998 3557.8 31-Aug-1999 100.2 6-Sep-1999 2372.1 8-Sep-1999 230.0 5-Sep-1999 230.0 26-Aug-1999 210.1 18-Aug-1999 58.4 15-Ju1-1999 23.2 27-Jun-1999 149.6 18-Jun-1999 149.6 28-Jun-1999 240.1 28-Jun-1999 189.9 28-2un-1999 57.6 28-Jun-1999 29.8 28-Jun-1999 1058.8 28-2un-1999 60.4 mum Distance method Diverging from M.D. 13081.7 10580.0 200.0 13081.7 100.0 100.0 13000.0 12280.0 8968.7 200.0 200 0 10730 0 100 0 1000O 0 100 0 1522 2 100 0 b~ Jo.,, For: B Robertson Dote plotted: g-S~p-19gfll Plot Rlflrsnco tS 16 VErSIon ;3. ~rdlnotls orl In flit rlflrln~ slot ~16. I ARCO Alaska, Ir c. Structure: CD#1 Field : Alpine Field Well: 1 6 Locofion : North Slope, Alosko East (feet) -> 60 50 0 50 60 90 120 150 180 210 240 270 300 330 560 390 420 450 480 510 540 570 600 630 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 600 O0 120 500 500 ~° ~ ~. ~oo,4~oo 1 ~ ~oo~-Z~ ] 30 ~~ 500 1400~ ~ 600 ~1500 ~900 ~ 1~00 1000~~1000 .... ~ ~700 11~_ 11 O0 _ 1200 . _ gO 120 .... ' --- 1300 - ~ ~ 1800 1600- ~ ~ ~ ~ ~ ~ ~00 1 ~00 1900 v '%700 120 ~800 150 ~ 900 180 210 240 150 120 9O 60 30 0 30 60 90 120 15O 18O 22~°'~ -_ , , , 240 ~-~o ~o ~o Created by jonee For: B Robertson Dote plotted: 9-5ep-1999 Plot Re~erence la t6 PO1 Ver~. t~1. ~rdlnat~ are rn feet referen~ slot ~16. INT~ 1000 1200 14oo ARCO Alaska, Inc. Structure : CD#1 Well : 16P61 Field : Alpine Field Location : North Slope, Alaska East (feet) -> 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 5200 5400 5600 3800 4000 4200 4400 4600 4800 200 ~01 ' I ' ' ' I I I I ' I I I I I I I ' I I I I I ' I I I ' ' ' ' I ' I I I I I I~--~ ' I I I zouu ~_.~....~u ~ ~- ~ ......... ~ ~ '50~--_ OD _ . ~u° ~ ~ ~ 270~ ~ -00 ~00o ~ ~. ~ -oo % ~ 2100 ~ ~ ~5900 uO ~ ~/Q ¢~ ~ ~ ~41~0 0 ~ 800 ~2500 1600 1800 2000 22OO 2400 "%2700 \ % 29OO \ \ 3100 \ ~ 3300 %3500 \ 3700 \~3900 '% 4100 % 4300 \ ~ 4500 ~ 4700 2600 , , ~ , . ~ . , , ~ ~ ~ . 400 600 800 1000 1200 1400 1600 --- ,..4500 '" -.-,~4500 '-- -..o~4700 '" --.49o0 "' ---~ ~5100 '" ~ 5300 5500 ,..,, 5700 ~' ~. 5900 "- ~ 6100 '" -,. 6500 \ \4900 \ 5100 \ \oN5500 %5500 \ % 5700 \ 1800 2000 2200 2400 2600 2800 3000 3200 5400 5600 5800 4000 4200 4400 4600 4800 East (feet) -> 200 2OO 4OO 600 800 0 1000 ~ 1200 ~ --I- 1400 I 1600 1800 2000 2200 2400 26OO I:~ lo.ss For: B Robertzon] Dote p~tt~cl: 9-5ep-1999 I Plot Reference rs 16 PB! ve~, ~. ] ~t~ om ;n feet mf~e~ slot ~16.~ I 0 Alaska, Field : Alpine Field Lo¢=fion: North Slope, Al=sk=l Eesf (feet) -> 5200 5600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 800 400 400 800 1200 1600 2O00 2400 2800 3200 3600 I V 4ooo 4400 4800 5200 5600 6000 6400 6800 7200 7600 I I I ~) I 800 4OO 0 03800 4_~100, _.4~:)0 ~700 ~000 _5300 5600 5900 6200 65C)0~,,6800 ~ 0 ~0 800 \ ~-~.~8oo '"' ..~ 5600 ~ X 1200 '~' ~ 5900 ~ \ '"" --.0.._620O -'"' '"-- ~._6500 661 ~ _~'-_ _.~ 6800 6800~ ~X~~ O0 1600 6966 \ \ \ k 6966 \\ 4100~XN \\ 35oo~ \ 2900~\ 50 \ 3200~ \ ..... .................... 3200 3600 4000 4400 4800 5200 56~ 6000 6400 6800 7200 7600 8000 8400 8800 Eosf (fool) -> 2000 2400 2800 5200 3600 I 4ooo V 4~00 4800 5200 5600 6000 64OO 6800 7200 7600 ARCO Alaska, Inc. Post Office B~5'~ -100360 Anchorage, Alaska 99510-0360 Telephone 907 2'/'6 i215 September 14, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-16 (& CD1-16 PB1) Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD1 drilling pad. The intended spud date for this well is October 1, 1999. It is intended that Doyon Rig 19 be used to drill the well. CD1-16 PB1 will be drilled through to the base of the Alpine Sand at an inclination of approximately 46©. This will allow evaluation of the reservoir interval. CD1-16 will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing the horizontal section will be drilled and the well completed as an open hole injector completion. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed pilot hole schematic. 6. Proposed completion diagram. 7. Proposed completion diagram with open hole isolation options. 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9. Proposed cementing program and calculations. 10. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian R~b~! Senior Drilling Engineer Ai~CO Amsk:~. lnc 's ~: Subsidiary of A!!anlicRichfieldCompan,, Attachments --' CC: CD1-16 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1 O54 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com ARCO Alaska, Inc. Post Office BS~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 14, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-16 (& CD1-16 PB1) Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD1 drilling pad. The intended spud date for this well is October 1, 1999. It is intended that Doyon Rig 19 be used to drill the well. CD1-16 PB1 will be drilled through to the base of the Alpine Sand at an inclination of approximately 46©. This will allow evaluation of the reservoir interval. CD1-16 will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing the horizontal section will be drilled and the well completed as an open hole injector completion. At the end of the work program, the well will be closed in awaiting field start up. 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: , , 5. 6. 7. 8. 9. 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian R~;/bertson Senior Drilling Engineer ARCO Alaska. Inc. is a Subsidiary of At!anlicRichfieldCompany Attachments CC; CD1-16 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: The First National Bahk of Chicago-0710 Chicag0¢!::lll inois Payable Through Republic Bank Shelbyville, Kentucky 73-426 839 AUGUST 27, 1999 0997587 STATE OF ALASKA. i. ALASKA OIL '&': GAS CONSERVATION COMMI 3001 PORCUPINE 'DRIVE **', ~ivoID AFTER 90 DAYS **~ : . .. EXACTLY ***********IOO DOLLARS AND' O0 CENTS ¢*********** 100.00 TRACE NUMBER: 230099011 ,' E 5OOqqO l, ],,' ':08 :l, qoh ~r--., ~,: 0 q q? 58 WELL PERMIT CHECKLIST COMPANY //,--"~_-<::~ WELL NAME~'/~---¢' ~____.~/_/z~ PROGRAM: exp ~ dev ~ redrll __ serv .~, wellbore seg ann. disposal para req __ FIELD & POOL / ~O/) ~-~,c~ INIT CLASS /- ~,-.-,'~,,,~/,~ ADMINISTRATION 1. Permit fee attached .............. " ......... 2. Lease number appropriate ................... 3. Unique well name and number .................. . 5. 6. 7. 8. 9. 10. 11 AP_P-..R DATE 12. ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21 22. 23. 24. 25. AP~R, DATE 26. 27. 28. 2g. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. · If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to .~O~C~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOL AREA Y N Y N Y N Y N Y N Y N Y N Y N Y N Y,N Y N Y N Y N (~)U Y N ,N UNIT# ~ .5"<:::~'z:~ ON/OFF SHORE ~ ,,~ GEOLOGY 30. 31. 32. AP.,~P~R DA?TE 33. ~___. _?//~,-~/~ 34. ANNULAR DISPOSAL 35. APPR DATE Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... Y N Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory o~] Y N With proper cementing records, this plan /~c~t,- (A) will contain waste in a suitable receiving zone; . . .' .... CY.)' N (B) will not contaminate freshwater; or cause drilling waste... to surface; .~ ~ ~_ ,~ /~.~(_~z--~,~ I,,~7© ~,~o~,~.~-~ i'~,~,-p~,v~5 ~./V,"OOL_~.~, (C) will not impair mechanical integrity of the well used for disposal; ~ N (D) will not damage producing formation or impair recovery from a L.~'~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. '~') N GEOLOGY: ENGINEERING: UIC/Annular COM MISS ION..2___.-~--.-. - - JDH ~ Comments/Instructions: c:\msoffice\wordian\diana\checklist