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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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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y Samantha Carlisle at 8:09 am, Apr 25, 2022 'LJLWDOO\VLJQHGE\(ULFD/LYLQJVWRQ '1 28 :HOOV&KLHI(QJU2 &RQRFR3KLOOLSV $ODVND,QF&1 (ULFD/LYLQJVWRQ ( HULFDMOLYLQJVWRQ#FRQRFRSKLOOLSVFRP 5HDVRQ ,DPDSSURYLQJWKLVGRFXPHQW /RFDWLRQ $QFKRUDJH$. 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im Regg P.I. Supervisor 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. CD 1-06 COLVILLE RI UNIT CID 1-06 Sre: Inspector Reviewed By: P.I. SuprvJ Comm Well Name COLVILLE RIV UNIT CD1-06 API Well Number 50-103-20341-00-00 Inspector Name: Lou Laubenstein Permit Number: 200-083-0 Inspection Date: 6/12/2021 Insp Num: mitt -01-210612143001 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-06Type j j G 4VI) 6622 Tubing 3810 3810- 3810 - 3810' PTD 2000830 Type Test SPT jest psi 1656 jA 1340 x2000 ' 1985 1985 - BBL Pumped: 0.9 BBL Returned: 0.9 OA 440 445 j 445 - aas -i Interval 4YRTST Notes: Thursday, June 17, 2021 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 19,2017 P.I.Supervisor rM (8 171 11 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-06 FROM: Bob Noble COLVILLE RIV UNIT CD1-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-06 API Well Number 50-103-20341-00-00 Inspector Name: Bob Noble Permit Number: 200-083-0 Inspection Date: 6/11/2017 a Insp Num: mitRCN170612094750 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well cm-06 ' Type Inj G ' TVD 6622 ' Tubing 3500 - 3500 " 3500 - 3500 " PT D Pumped: - BBL Returned: 301 Type Test SPT Test psi 1656 - IA 1530 2500 ' 2480 - 2480 ' BBL l - ---1 OA 380 - 380 • 380 ' ---380 1 Interval 4YRTST P/F P Notes: scoNE© AUG 2 2 2D17. Monday,June 19,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 24,2015 TO: Jim Regg Z2,,,.. 2-12q S P.I.Supervisor r`1 `r SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD 1-06 FROM: Johnnie Hill COLVILLE RIV UNIT CD1-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry riff-- NON-CONFIDENTIAL Comm Well Name COLVILLE R1V UNIT CDI-06 API Well Number 50-103-20341-00-00 Inspector Name: Johnnie Hill Permit Number: 200-083-0 Inspection Date: 2/20/2015 Insp Num: mitJWHl50221144447 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-06 , ;Type Inj 1 o TVD T 6622 - TubingT 3500 ! 3500 , 1 3500 -I 3500 - I I PTDL 2000830 - ;Type Testi SPT(Test psi 1656 -T IA 1440 2200 - 2185 - 1 2185 - li -- Interval 4YRTST IP/F P - OA 1 525 525 - ; 525 . 1 525 – – L— — — 1 i 1 L J Notes: 1 2bbls diesel used , SCANNED t,,,: ; Tuesday,February24,2015 Page 1 of I Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, February 17, 2015 10:43 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; McKee, Garrett L;ALP DS Lead and Simops Coord Subject: RE: CD1-06 (PTD 200-083)Alpine dark start well Attachments: image001.png Chris- This email is to inform you of the current status of CD1-06(PTD 200-083)Alpine facility"dark start" well. The original intention of swapping the well to production after 4-5 days of injection has changed due to complications during the swap. Several attempts were made but the well met the minimum temperature range of the piping during the conversion. The well was brought back on injection,therefore since the well will be on injection longer than originally expected a state witnessed MIT-IA will be scheduled as soon as reasonably possible. All other portions of the plan will proceed as planned. Please let me know if you have any questions or disagree with the plan forward. Cheers, Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 ,r WELLS TEAM sEa 1 . con000'P++illps Fr. : Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: '•ay, February 06, 2015 11:12 AM To: NSK Pro. em Well Supv; Hunt, Jennifer L(DOA) Cc: Senden, R. er Subject: [EXTERNA E: CD1-06 (PTD 200-083)Alpine dark start well Jan, Thank you for the email. As discussed,you will need to report the volumes i '-cted as well as produced on the monthly reporting. I copy Jenni so she may make a note in our database for when the wel ,:s as "injector with production" in the near future. All else is acceptable—and the <30 days production guideline with. .t a sundry is still in effect. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 18,2013 Jim Regg P.I.Supervisor 1�? '(l'l 113 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD 1-06 FROM: Jeff Turkington COLVILLE RIV UNIT CD1-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv--gge-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-06 API Well Number 50-103-20341-00-00 Inspector Name: Jeff Turkington Permit Number: 200-083-0 Inspection Date: 6/12/2013 Insp Num: mitJAT130614190457 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-06 Type Inj N-ITVD 6622 IA 590 1990 1990 1990 , 2000830 SPT 1655 PTD • Type Test, Test psi - OA soo soo• 500 500 - Interval ',4YRTST P/F P — Tubing 3450 3450 3450 3450 • Notes: 1.2 bbl diesel to fill SCANNED FEB 2 0 1014 Tuesday,June 18,2013 Page 1 of 1 • MEMORANDUM To: Jim Regg / P.L Supervisor ~G'~~j ~ 7~~'ZI~~ ~ FROM: $pb NOI71C Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD]-06 COLVILLE RIV LJNIT CDl-06 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: COLVILLE RN i1NIT CD1-06 Insp Num: mitRCN090617204221 Rel Insp Num: API Well Number: 50-103-20341-00-00 Permit Number: 200-083-0 ~ Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. wej~ CDl-06 T~,pe jn~. ~, T~ 6622 ,/ jA 1320 3010 ~ 2990 2990 ~ P.T.D 2000830 TypeTest SPT Test psi so~o / QA 400 400 400 400 Interval 4YRTST P~' P ~ Tubing 3532 3532 3532 3532 Notes: Mi n - ~~5~' ~n-°S5w~2 t6 ~5~~ ~ , ''':'~'~`~``. °t~,~f= . `F ~~(~~t, 1. Monday, June 22, 2009 Page 1 of 1 Message • • Maunder, Thomas E (DOA) From: Wiess, JORDAN F (JORDAN.F.Wiess@conocophillips.com] Sent: Thursday, August 02, 2007 12:01 PM To: Roby, David S(DOA); Uidrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Page 1 of ~ ~ . Dave, a~-o~~ p, As a result of receiving these interpretations, CPAI has initiated lean gas injection into CD1-02, t CD1-05 and CD1-21 (with CD1,-06 and CD1-14 previously on lean gas injection). CD1-11 is on long-term continuous miscible gas injection (no WAG) because _it is twinned.with CD1-05. When it reaches the end of its miscible gas EOR service, it will be converted to continuous lean gas injection as well. Also, after the facility shut down in August, CD2-06 and CD2-07 will start on lean gas WAG. Jordan ~~~~~~~~ .~1,~ ry -~~~: ~.t~~ i , -----Origin al Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August O1, 2007 3:45 PM To: Wiess, )ORDAN F; Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Jordan, One more thing, could you please tell us which three wells have been converted to lean gas injection, and email us when wells are converted in the future, so that we can put a note in the appropriate well files? Thanks again, Dave Roby Phone: 907-793-1232 email: dave, ro~ alaska.aov From: Wiess, JORDAN F [mailto:JORDAN.F.Wiess@conocophillips.com] Sent: Wednesday, August O1, 2007 8:18 AM To: Roby, David S(DOA); Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Dove R, Dave Uldrich is out of the office until mid/end of next week. I will ensure he provides you a prompt reply upon his return. Thanks for your time last week. ~~ ~-.Z~~C ~.9 Q ~~ 8/17/2009 Message ~ ~ Page 2 of ~ ~-. Jordan -----Original Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August 01, 2007 8:15 AM To: Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, ]ORDAN F; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order David, I do have one request for you. During the meeting it was mentioned that normal laboratory testing to demonstrate miscibility wasn't working because of the way the samples were obtained and analyzed and that the MMP values that the lab determined were in error by several hundred psi. Could you please provide a short note, an email would be fine, to explain these problems and what you are doing to ensure miscibility? Thanks in advance, Dave Roby Phone: 907-793-1232 email: dave.robv aC~.alaska.gov_ From: Uldrich, David 0 [mailto:David.O.Uldrich@conocophillips.com] Sent: Tuesday, ]uly 31, 2007 4:46 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, JORDAN F Subject: AOGCC Guidance on Alpine Area Injection Order Dave: I wanted to thank you and Tom very much for meeting with Jordan and myself last week. We appreciate your time and efforts to clarify the issues that we raised through the draft request for amendment of the Alpine area injection order. Having confirmation from you that the existing area injection order and State regulations permit post-MWAG lean gas injection, we are moving ahead with the plans we discussed with you. As we discussed with you, CPAI believes that the injection of lean gas in the post-MWAG injectors will enhance the recovery from the Alpine reservoir. As a result of the guidance that we received from you and Tom on behalf of AOGCC, CPAI has started lean gas injection into 3 wells that were previously used for miscible gas injection. These conversions, and several others we intend to implement later this summer, will help us manufacture gas that is miscible for the Alpine reservoir as well as the Fiord and Nanuq-Kuparuk reservoirs. In addition, we anticipate that the expanded lean gas injection will generate increased recovery through pressure maintenance and some reduced residual oil saturations. Thanks again for you help. David Uldrich Staff Reservoir Engineer Alpine Development Engineering ATO-1766 ConocoPhillips Alaska Inc. e~ (907) 265-6828 ~ David.O.Uldrich@conocophillips.com 8/17/2009 . . ConocóPt,illips Alaska ,2,PR P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 sCANNED APR 0 9 2007 O...oq;3 dJ) Dear Mr. Maunder: .,~ Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 "" , CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 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.A ?!16!200? 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 easing 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.~--- ..... ~i' --3.6 CD1-3 10' 1.4 MI ~ 8.5 CD1-4 7.3:~' I P 6.0 ..... CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl §.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 ~ ,. CD1-22 1.83' 0.3 P 1.8 CD1-2~ 15.42' 2.1 -- MI 12.7 CD1-24 2' 0.3 P 1~.8 CD1-25 5.~6' 0.8 P"' 4.8 .-- . CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.--(~' ~,. 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 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 C'D2-17 18---' --2.5 I'~J 15.1 CD2-19 11.66' 1.6 P 9.7 C-D2~22 13.5-~- 1.8 INJ ~ 0.9 CD2-25 27.25' 3.7 ~ ....... 22.~ CD2-26 10.42' 1.4 INJ ......... 8.5 C D2-~ 8.5' ---1.2 INJ 7.2 CD2-33 ~ 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 C1~2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 IN-~- ..... ~.0 CD2-48 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 ~lpIfl~ L~ement Iop Pill (_ 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 well 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 of 2 4/24/2003 7:55 AM ~p~ne L;ement I'op I-ill [o ' I Name: AOGCC ALPINE cement top outs 04-16-03. xls AOGCC ALPI NE cement top outs 04-16-03.xlsI Type: EXCEL File (application/msexcel) ....................................................................................... ..................................................................... r"~Cement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc Type: WlNWORD 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 Permit to Drill 2000830 MD 16023 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CDt-06 Operator PHILLIPS ALASKA INC. 6847 Completion Dat 7/10/2000 ,,'"/ Completion Statu 1GINJ Current Status 1GINJ APl No. 50-103-20341-00-00 UIC Y REQUIRED INFORMATION Mud Log N._Qo Sample No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~.~ Fmt (data taken from Logs Portion of Master Well Data Maint) Inter~al Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments 3575 13307 Open 8/18/2000 09696~'~J575-13307 3560 16023 Open 8~29~2000 09698 '"3~60-16023 VISION 475-MD 2/5 FINAL 3588 16023 OH 8/28/2000 3588-16023 6/21/00THRU VISION 475-TVD 2/5 FINAL 3095 6835 OH 8/28~2000 3095-6835 6/21/00 THRU SRVY RPT 0 13308 OH 7/2012000 SCHLUM 0-13308. SRVY RPT 0 16023 OH 8/10/2000 SCHLUM 0-16023.64 USIT 5 FINAL 11700 12830 CH 8/18/2000 BL(C) 11700-12830 ADN-TVD 2/5 FIELD 3100 6900 OH 8/18/2000 3100-6900 PB1 ~-~ CDR-MD 2/5 FIELD 3588 13265 OH 8/18/2000 3588-13265 PB1 CDR-TVD 2/5 FIELD 3100 6900 OH 8/18/2000 3100-6900 PB1 -~' ADN-MD 2/5 FIELD 3588 13265 OH 8/18/2000 3588-13265 PB1 9696 I OH 8/18/2000 9696 ~CHLUM CDPJADN/GR PB1 9698 1-3 OH 8/29~2000 9698 -"~'CHLUM GPJCDR/ADN/IMP 6/21/00 Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Permit to Drill 2000830 DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. COLVILLE RIV UNIT CDI-06 Operator PHILLIPS ALASKA INC. MD 16023 TVD 6847 Well Cored? Y Chips Received? Analysis Re.c~.iv~.d? Completion Dat 7/10/2000 Completion Statu 1GINJ Current Status Daily History Received? Y / N Formation Tops ~ / N 1GINJ APl No. 50-t03-2034'1-00-00 UIC Y Comments: Compliance Reviewed By: Date: .( MEMORANDUM TO: Julie Heusser Chairman THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve State of Alaska Alaska 011 and Gas Conaervation Commission ,~~~e~"0'~ DATE: March 30, 2001 ~:lrt~ ~ SUBJIECT:~ PhillipsMechanical Integrity Tests CD1 Alpine ~,~ [~.~-O \ Colville River Unit Alpine Petroleum Inspector NON- CONFIDENTIAL " ' ' Packer D~ .... Pret~t Init~l'" 15'Min. 30Min. ' ' ' W~,~I CD~-~ I m~.J.I Sw If'V-D-l~ I'T.~."'I ~ I "~ I 4~ ! ~ ~1 ! P:T.D.} 19~ Im~l 'P' ITrot"il ~72~ lC=~'l..~ '1 ~ i ~ ] '2~..., P~. ! ~ w~l c~'~'l~y.~.j:l s I m.V.D.I ~ I m~;l,, ~ I So, I ~ I So. I.~.~1 I ,P.T.D.I 2~17~ I~.~tl , I.rm-,I ~F~ I'c=~gl o ! ~.! ~ I ~9~'1 w~q,~ol~ I T~,~J.I N ',;I~.v.D."I ~ I~ub'~al =0' I =0 '1 =0 'i 20' !~! ~ P.T.D.~ ~=0 i~ym~t[' P I T~t'~'l ~0 IC~,nol. o' I.'~ I i~0 I~ ~ i' P~ .! ~ "w~l 'c0~'~ I'TvmkJ..l" e..' I T.V.O~'I ~ i'~=,~'1 ~S~ I. =~ I'=S~ I =S~ I'P~l ~ P:T.D.I 1~128 ITy~l P IT-tmil.!S~"'l'C"in.l 7~ :1 105o,! ..!~11'~ i.. P~ '1 e N~: , , "wa,cD~ I.fy-,.j.! ~ I T.V.D.~i ~Y"i T~"'I 2~ '1 2~ i"2~ l.'2~'l'i~l.. '" i ...... P.T.D.I ~2 IT~mtl P .I T. tmil. ,1,~1 .I.c.i~ ! 0 .I ~ I 1.~' J ~_ I .P~ I E N~: ,, P,T.D.i, ~O~.,.ITy.~I.. P ,,,IT.t,m!.l .1~83 I C~i.01 o .I !8~ I' 1~ I. 1~1 P~. I e N~: ' , ,, .... Wdti Cbl-~O'"I T~.J. I' '" '1 T.V.0. I .20 I fu~. I 220~. I ~2~"1' '~2~ "1,.=~ I t.~tl, t 'P.T.D.I'~o IT~! ~ Im~"~l l~'i~inol o I!~! ~o~ .I.,1~ I N~: Cle~s 2 dispo~! W~ll . , ..... wa, c,,-= T.V.,: I I I -' P.T.D:I '~ i~~tl P ,. I T"t"~l '1.0. I C-~ I ' .0 ~ooo 1om,, '~' I" ~ i ~ N~: This W~I fail~ a,pre~ious t~t ................ . , ,. .,,, , Type INJ. fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring I= Initial Test G = GAS INJ. P=- Standard Pre~ure Test ' 4= Four Year Cy~ S= SALTWATER INJ. 'R= Internal Rad'__~.~__'ve Trm:er Suwey ' V= Required, by Vadance N = NOT INJECTING A= Temperature Anomaly Survey W=- Test during Workover D= Differential TemPerelure Test O= Other (desCribe in notes) Test'$ Details I traveled to the Phillips Alpine location and wimessed the initial mechanical integrity tests on 9. injection wells. All pretest pressures were observed for 1 hour+ while waiting for pumping cqmpmont to arrtvc and were found to be stable. A standard annulus pressure test was thon poTormed with all 9 wells ~ mechanical i ,nt~,~ity. -, -~-~--- ~. . M.I.T.'s pertormecl: ~..." Number ot Failures!. 9. Total Time during tests: Attachments: ~c: MIT report form 5/12/00 L.G. 010330-MIT Alpine-CS 4/4101 ) ) Casing Detail 9518" Surface Casing ~\~~S~~!~H~I!s-J~~~~'J~;; dCX:)-06 ~ lumber Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH Well: Date: 3 to 87 Doyon 19 RKB to LOS FMC Gen V Hanger 85 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 2 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 36.20 2.41 3455.30 1.55 80.10 1.80 1 to 2 TO 12 1/4" Surtace Hole 3587.36 RUN TOTAL 59 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #32 (On stop rings of Jt #1 & #2) #34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 707274767880828486 ~f£Ð OCT 3 12005 Use Best-a-Life 2000 pipe dope Remarks: Up Wt - No Data On Wt - No Data Block Wt - 70k Supervisor: Scott 0 Reynolds CD1-06 6/20/00 DEPTH TOPS 36.20 38.61 3493.91 3495.46 3575.56 3577.36 ) ) Phillips Alaska Drilling I Well Name: CD1-06 Rig Name: Doyon 19 CP: Date:6-20-00 Tlme:22:21 HRS Remarks:Could not reciprocate casing. Casing hung up close to surface after Initially landing hanger. Casing could only be picked up 1.8'. Possible that hanger was hanging up on flange between diverter spool and starting head or at a centralizer at the base of the conductor. Had full returns throughout cement lob. 150 bbl8 of 10.8 ppg cement returns. Pumped 1st Blozan wash with nut plug and celloflakes 75 bbls ahead of regular Blozan wash with just nutplug. Saw 1st Inlcator (nutplug + celloflakes) @ 330 bbls into lead. (20 bbls past calculated) Switched to tail cement with 333 bbls lead pumped. Saw 2nd indicator @ 434 bbls cumulative pumping - compared to a calculated value of 386 bbls. (This calculates to a washout value of 12.5% which confirms washout calculations made before drill string was POOH. Casing Size 9.625" Centrallzer8 Comments: Total - 59 Bow Springs Mud Comments: Wash 0 Comments: Spacer 0 Comments: Lead Cement 0 Comments: Tall Cement 0 Comments: Displacement 0 Comments: Calculated top of cement: SURFACE I Cement Company: Dowell Report Date: 06/2012000 AFC No.: 998C09 Cementing Details Report Number: 1 I Field: ALPINE I Hole Diameter: 12.25" Angle thru KRU: na Shoe Depth: 3577' LC Depth: 3494' % washout: 12.5 State type used, in/elVals covered and spacing Ran 1 bow spring per It 1 st 32 Its and every other It to surface. Weight: PV(prlor cond): PV(after cond): YP(prior con d): 9.7 30 13 35 Gels before: Gels after: Total Volume Circulated: 12/56/89 219/12 1077 bbls Type: Volume: GELH20 40 bbls Type: Volume: ARCO B45 50 bbls Type: Mix wtr temp: ti0 Weight: AS III Lite 70 DEG 10.7 Additives: 30% D053, 0.6% D046, 1.5% D079, 1.5% S001, 50% D124, 9% BWOW Type: Mix wtr temp: Weight: G 70 DEG 15.8 YP(after cond): 11 Weight: 8.4 Weight: 10.5 Yield: 4.44 Yield: 1.17 Additives: 0.2% D046, 0.3% D065, 1% S001 Rate(before tail at shoe): 8 BPM Rate(tall around shoe): 7.5 BPM Str. Wt. Up: NA Str. WI. Down: NA Reciprocation length: o Reciprocation speed: o Theoretical Displacement: 250 BBlS Actual Displacement: 247 BBlS Bumped plug: YES Str. WI. in mud: 110K Floats held: YES I Rig Contractor: DOYON Approved By: Scott D Reynolds Phillips Alaska Drilling AFC No. Date Rpt No 998C09 06120/2000 4 Well: CD1..()6 Depth (MDrrVD) Contractor: DOYON Rig Name: Dovon 19 Operation At 0600: Testing BOPE Upcoming Operations: PU BHA #2. RIH & test casing. MÙD DATA MUD TYPE SPUD WEIGHT 9.7ppg VISCOSITY 48sqc PV/yp 13/11 GELS 2/9/12 APIWL 10 HTHP WL mV30 mln SOLIDS 9% HOLE VOLUME 270bbl MBT 25 ph 8 LGS 8.5% PIT VOL 185 DAILY MUD $8509 TOTAL MUD $23056 COMPANY MI ·.BHNb¢SQRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: tiME I ENb 12:00 AM 12:30 AM 12:30 AM 01:30 AM 01:30 AM 03:00 AM 03:00 AM 04:00 AM 04:00 AM 05:30 AM 05:30 AM 08:00 AM 08:00 AM ·09:30 AM DRILLING DATA OEPTH 3588 ROTWT 150k PUWT 160k SOWT 140k A VG DRAG 10k MAX DRAG TRO BTM 10k TRO OFF 8k PUMP PRES 1800 12020 I I PUMP NO 1121 I LINER 5Z 5.5161 I SPM 1 751751 I GPM2 26413141 I SPS 1 III SPP 1 III MUD WT 9.611 I 112 1/4 MXC1 HWDP. 0355 128.27 HOURS 0.50 1.00 1.50 1.00 1.50 2.50 1.50 Daily Cost $ 316002 Last Csg: 9 5/8" @ 3577' BIT NO. 1 SIZE 12 1/4 MAKE HTC TYPE SERIAL NO F57DH DEPTH OUT DEPTH IN 115 FOOTAGE 3473 ADT/AST 33.67/16.01 WOB2 30·35 RPM 1 169·229 TFA 0.546 JETS 121121101181 I BIT COST ~ULL ( ï'll 1 1069.86 OD 5 5 OPS CODE DRIL CIRC WIPERTRP WIPERTRP CIRC TRIP _OUT BHA Daily Drilling Report: CD 1-06 06/20/2000 ) Rig Accept· hrs 06/18/2000 08:30:00 PM Days Since Accept/Est: 3.15 /3.2 3588/3095 Prev Depth MD: 3544 Cum Cost $ 616896 Next Csg: 7" @ 13482' BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADTlAST / WOB2 RPM 1 TFA JETS III I I BIT COST ~ DULL I I II GRADE III EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG INJECTION INJECTION WELL CD1-27 SOURCE WELL CD1-06 RATE (bpm) 4 PRESSURE (psi) 1220 INJECTION FLUIDS Water Base Muds 990 Diesel 80 o o o TOTAL VOL (bbl) 1070 TOT FOR WELL (bbl) 31204 ) Daily Drilling Report Rig Relase - hrs: Progress: 44 Est Cost To Date $ 610000 Shoe Test: DRILLSlBOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 06/11/2000 06117/2000 LAST H2S DRILL 05116/2000 LAST CONFINED SPACE 03/07/2000 LAST FIRE DRILL 05/31/2000 LAST SPILL DRILL 06/19/2000 FUEL & WATER FUEL USED 1620 DRILL WATER USED· BBLS POTABLE WATER USED· BBLS 950 104 WEATHER & PERSONNEL DATA TEMP OF 47 WIND SPEED 13 WIND DIRECTION 50° CHILL FACTOR OF 33.59 ARCO PERSONNEL CONTRACTOR PERSONNEL 26 MISC PERSONNEL 5 TOTAL 47 C 1.5, DC SHORT NM, STAB NM, MWD, UBHO SUB, 2' DC NM, STAB NM, DC NM, XC, 3'HWDP, JARS, SERVICE PERSONNEL 15 ID 4.26 3.00 WEIGHT 19.5 49.3 DRILLÞiÞEbÁT'A GRADE CONNECTION G105 4-1/2 IF HWDP 4-1/2 IF LE~ GTH HOLE SECT I pHASE OPS SURF Making Hole SURF Other SURF Other SURF Other SURF Other SURF Other SURF Other CLASS 2 PREM PREM I OPERAtIÖN$.FAÖrvf()()Oo~Ò()OO Drill f/3544' tJ3588'. ART=0.27 hrs; AST=0.20 hrs. Pump nutplug sweep - reset stroke counter· sweep at surface at 6000 strokes. Gauge hole strokes = 5290. Calculate hole WO @ 12%. POOH tJHWT @ 1071'. Tight hole @ 2000' & 1675'. 25k overpull. RIH - no hole problems. Pump nutplug sweep - reset stroke counter· sweep at surface at 6200 strokes. Gauge hole strokes = 5290. Calculate hole WO @ 14.5%. POOH. Tight @ 1200' & 870'. 35k overpull. LD DC's & BHA. - Page 1 ) 09:30 AM 11 :30 AM 2.00 PREP SURF Casing and Remove balls and clear floor. RU slips - elevators - stablng Cementing board & Franks fill-up tool. 11:30 AM 12 :00 PM 0.50 SAFETY SURF Casing and PJSM - running 9-5IS" casing. All hands take lunch before Cementing start of casing lob. 12:00 PM 04 :30 PM 4.50 RUN_CSG SURF Casing and Run 9-5/8" casing tl3577'. Cementing 04:30 PM 07 :30 PM 3.00 CIRC SURF Casing and Land hanger in starting head. PU for PU & SO weights - Cementing casing hangs up with no stretch after pulling 1.8'. Possibly hanging up @ centralizer @ base of conductor or hanger Is hanging up at dlveter spool flange. Can not reciprocate casing. Circulate & condition mud for cement lob. 07:30 PM OS :00 PM 0.50 PREP SURF Casing and LD fill-up tool and blow down top drive. Cementing OS:OO PM 10:30 PM 2.50 CMT _CSG SURF Casing and Pump 40 bbl blozanlnutpluglcelloflake marker. Follow wn5 Cementing bbls mud & 40 bbl blozanlnutplug pre-flush. Pump 5 bbls wtr & test lines. Drop btm plug - pump 50 bb110.5 ppg ARCO spacer - pump 333 bbls lead cement & 102 bbls of 15.8 ppg tall. Drop top plug & pump 20 bbls wash wtr. Turn over to rig for displacement. Bumped plug 247 bbls Into displacement. (250 bbls calculated). Floats held. CIP @ 22:21 hrs. 10:30 PM 12:00 AM 1.50 OTHER SURF Casing and LD cement head & landing loint. RD elevators & balls. Clear Cementing floor of slips - elevators - balls & tongs. 24.00 Supervisor: SCOTT REYNOLDS ~ No r¿~p(ë>c.~\1"'o"-.... Daily Drilling Report: CD1-06 06/20/2000 Page 2 Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 36# J-55 BTC Casing Setting Depth: 3,571' TMD Hole Depth: 3,608' TMD 3,090' TVD 3,1031 TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 31' EMW= Leak-off Press. + Mud Weight = 1,030 psi + 9.6 ppg 0.052 x TVD 0.052 x 3,090' EMW for open hole section = 16.0 ppg Used cement unit Rig pump used Pump output = 0.0997 bps Ruid Pumped = 1.5 bbls Fluid Bled Back = 1.2 bbls NO #2 2.800 psi 2.700 psi 2.600 psi 2.500 psi 2.400 psi 2.300 psi 2.200 psi 2.100 psi 2.CXXJ psi 1.900 psi 1.800 psi 1,700 psi w 1.600 psi ~ 1.500 psi ~ 1.400 psi ~ 1.300 psi a.. 1 ,200 psi 1,100 psi I.CXXJ psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi loopsl o psi o 11111 111111111 IIIIIIIIMIII~I~I~I" /~Æ~~~ucfl / ~lEAK-oFFTEST ~CASfNG TEST --lOT SHUT IN TIME ~ P>.a";,,,wc ...::- ~~~I~~ETEST SHUT IN TIME - '·"S:-~-1::-;:.···;~;t"'_r:;:' ,-- -..,...\~~ rP 30 STROKES 40 50 10 20 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIMEn:see time line above Modified by Scott Reynolds MINUTES MINUTES CASING TEST DATA LEAK-OFF DATA lIJ roR roR LOT STROKES PRESSURE CSG TEST STROKES r - ! 0 ----- T 0 psi -1 ¡-- - : 0 stks i ~- I 1 0 i 110 ··1 J, · 2 tk I ~__ __-- _ _ ~ . ..-_ ~ pSI -I ~\..f)_ IS s I ~___+ 2.0 i _! 8~ ps!_ 1 ~'tlC) _ _ I 4 stks f- ~-----4 _ 3.0 _ j 250 psi 1 f). 1 6 stks I I 4.0 - I' 330-p_si 'I . 0__ ----I' 8 stks _ · -------t- rt:- 1--------4-- 5.0 _ i 40~ psi ]Jç). _ __I 10 stks ~ I--____________~-- 6.~ ~__ 480 I?si q 0 _- i- 12 s~ks i L____J _ 7.~. 'I 570 psi ~'? .1 14 stks .1 ~____-m--__ ~_ 8.0 i _ 660 psi <¡t? _ _1_.16 stksj , I. 9.0 I 74(t~ .5 Ù .1 18 stks ~I t----- = - !- -10.0- (f 790 øsi' c;,o I 20 stks I 1------- -i-- ....-:-- I , r--------- . i _~_11.0 850 psi>;. 0 1 22 stks i I 12.0 900 psi I ~0 I 24 stks I r-- -- ~ -1-- 13.0 950 psi I ftO --- tl 26 stks ~--- ---- I I .è - t--- ---1 14.0 990 psi ~O i 28 stks ~___-I 15.0 1,030 psi ~ i 30 stks I- I , I l-, ____ _ __ I,', 31 stks : - i - 1- -1 . t----- I +-- -1 t-.--- i ---- 1---------1----------+------ - ------ i 1-- - 1 ~-- _n - --4------- -+ -i I i . . . I , I t--- - -- --1 - -------+ 1 ~ SHUT ~N TIME i I I O.Omin I ~-------- -- 1----- --I - f ~--1 0 . ! , ". mln ~--------__1......-...H.-.....__t-..H......·..---....·1 ~ 2.0 min t ¡¡I I :- ,_ ~_~HUT IN TlME_1 SHUT IN PRESSURE ~. 3.0 min i I 0.0 min I . _ "I 1,030 psi L 4.0 min 1,1 I- - f 'u I 1.0 min I _! 1,000 psi I 5.0 min .1 ~-.! I , ! _~.O m~nl i 980 psi i _ 6.0 m~n i ~. ~.O m~~ ___ i _930 psi ~ 7.0 m~n 1____ I 4.0 mln . 'I 910 psi I I 8.0 mln . ¡ ·1-- it-· t-- I 5.0 r.n~n --1- _~ _I - 90~ psi i i 9.0 mlni__.._ - I 6.0 mln I I' __ 890 psi , I 10.0 min I t- 8 0 . - 1 860 . ! I 15 0 . -. I- --' min. _ i-- I pSI I I . mln 1 ~_-1 0.0 min j 820..R.si I i 20.0 min -I ~__!?O_ m!n i _ --..,_. ~ 800 t"~~1 1 I 25.0 min i L 13.~_~iñ_J__ __ \ _ 8~~ PS! J L 30.0 mint. PRESSURE o psi 14~ psi 420 psi 600 psi 760 psi _ 94º psi 1 ,~50 psi 1,170 psi 1 ,300 psi 1,490 psi · 1,650 psi 1,810 psi 1,960 psi I 2,110 psi 2,270 psi I 2,450 psi 2-,_51_0 ps! - I -I -- ! . i , --t ! SHUT IN PRESSURE ì 2,510 psi I - I 2,450 psi f 2,450 psi ! 2,450 psi I 2,450 psi i 2,425 psi I 2,425 psi I I 2,425 psi t 2,425 psi I 2,425 psi t 2,425 psi 1 2,425 psi 1 2,425 psi I 2,415 psi ! 2,415 psi & - - - LIGHT AND PRESS THE DELETE KEY ) ) ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM CONIPANY Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Casing Detail 7" Casina Well: Date: CD1-06 7/3/00 LENGTH DEPTH TOPS Doyon 19 RKB to LOS 34.40 FMC Gen V Hanger 1.61 34.40 ) 3 to 328 326 Jts 9-5/8· 36# J-55 BTC Csg 13378.84 36.01 Davis Lynch Float Collar 1.45 13414.85 ts 1 to 2 2Jts 9-5/8· 36# J-55 BTC Csg 82.06 13416.30 Davis Lynch Float Shoe 1.70 13498.36 13500.06 Run one straight blade cent.fjt on jts # 1-#3 (total- 3). Run one turbulator per joint on joints #4-#32 ( total - 29) Run one straight blade centrilizer/ joint on joints on #244, #245,and # 246. (total 3). Use Best-o-Llfe 2000 pipe dope Torque pipe to base of triangle - check every jt. Record displacement. CBU @ shoe. Clrc and cond mud to 9.8 ppg at 6100·, 8600', and11 ,500'. Brreak circ slow - circ @ 4.5 bpm. Remarks: Supervisor: MIKE WHITELEY Ph ¡nips Alaska Drillina I Well Name: CD1-G6 Rig Name: Doyon 19 Casing Size 7" Centralizers Comments: Mud ëomments: WIsh 0 Comments: Spacer 0 Comments: I._ad Cement 0 Comments: tällcêment 0 Comments: DlsPläcørnènt 0 bòmments: Calculated top of cement: 11800' Hole Diameter: 8.5 ') Angle thru KRU: 66 Report Date: 07/0412000 AFC No.: 998C09 Shoe Depth: 13500 ) Cementina Details I LC Depth: 13414 Report Number: 15 Field: COLVILLE % washout: ? State type used. Intervals covered and spacing RAN 8 3/8" OD STRAIGHT BLADE CENTRALIZERS ON JTS '1,2,&:3, $&:JTS , 244,245, &: 246 (TOTAL· 6). RAN 8 3/8" OD TURBULATORS ON JTS , 3 - 32 ( 29 TOTAL). Weight: PV(prior cond): PV(after cond): VP(prlor cond): . VP(after cond): 9.7+ 7 7 17 16 Gels before: 919/10 Type: ARCO Type: ARCO B45 Type: Additives: Type: G Gels after: 51719 Mix wtr temp: Mix wtr temp: 70 Total Volume Circulated: 2340 BBLS Volume: 20 Volume: 50 BBLS No. of Sacks: No. of Sacks: 263 Weight: Weight: 15.8 Rate(before taU at shoe): 7.7 BPM Additives: 0.2% D046ANTIFOAMER, 0.27% D065 DISP., 0.2% D800 RETARDER, 0.25% D156 F.L ADDtTlVE. Reciprocation length: 15 Theoretical Displacement: 415 Rate(tail around shoe): 8.0 BPM Reciprocation speed: 30 FPM Actual Displacement: 415 Bumped plug: YES Floats held: YES CP: Date:7-4-2000 Time: Remarks:FULL RETUNS THROUGHTOUT JOB - RECIPICATED PIPE. WELL BREATHING - SI 4 HRSWAITING ON CEMENT TO SET. -------... cement Company: Dowell I Rig Contractor: DOYON Approved By: MIKE WHITELEY Weight: 8.4 PPG Weight: 12.5 PPG Yield: Yield: 1.15 Str. WI. Up: 350K Str. Wt. Down: 150 K Str. WI. In mud: 294K ) Phillips Alaska Drilling AFC No. Date Rpt No 998C09 07/0312000 17 ') Rig Accept - hrs 06/1812000 08:30:00 PM Daily Drilling Report Days Since AcceptlEst: 16.15/14 Rig Relase - hrs: Well: CD1-Ð6 Depth (MDffVD) Contractor: DOYON Dally Cost $ 334759 Rig Name: Doyon 19 Last Csg: 9 5/8" @ 3577' Operation At 0600: INSTALLING PACKOFF. Upcoming Operations: CHANGE RAMS-TEST BOPE. MUD DAtA MUD TYPE LSND WEIGHT 9.6ppg VISCOSITY 38sqc PVIYP 7116 GELS 5/7'9 APIWL 6.0 HTHP WL 13.0mV30 mln SOLIDS 4.9% HOLE VOLUME 906bbl MBT 18.0 ph 10.0 LGS 6.3% PIT VOL 780 DAILY MUD $2051 TOTAL MUD $267317 COMPANY MI BHADESCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: ..:<tJ:íMË(' < ',:'ËND.,. 12:00 AM 01 :00 AM 01 :00 AM 03:30 AM 03:30 AM 05:00 AM 05:00 AM 08:00 AM 08:00 AM 10:00 AM 10:00 AM 11 :00 AM TOTAL 18.5" STC HOLE OPENER, STAB NEAR BIT, DP COMP SRV NM, 2'STAB NM, XO, HWDP, JARS, 773' HWDP. DRILLPIPE DATA' . GRADE CONNECTI,ON G105 4·1/2 IF HWDP 4-1/2 IF 13510/6838 Prey Depth MD: 13510 Cum Cost $ 2499522 Next Csg: 7" 0 13482' PRILLlNGDATA BIT ÖATA EH&S DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) 13510 4 N ROT WT SIZE SIZE EMPLOYER 8.5 PUWT MAKE MAKE SPILL 300-450 STC N SOWT TYPE TYPE TYPE 85-150 AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) 0862M6980 MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG 06/2512000 TRQ BTM DEPTH IN DEPTH IN INJEGJ10N TRQ OFF FOOTAGE FOOTAGE INJECTION WELL CD1-25 PUMP PRES ADTIAST ADTIAST SOURCE WELL III I I CD1-Ð6 PUMP NO WOB2 WOB2 RATE (bpm) 1121 1 0 LINER SZ RPM 1 RPM 1 PRESSURE (psi) 5.51611 182 - 282 0 SPM 1 TFA TFA INJECTION FLUIDS 701721 I 0 GPM2 JETS JETS 250 I 305 I I III1I II1I1 0 0 SPS 1 BIT COST BIT COST 30 I 40 I 30 I 40 0 0 SPP 1 DULL DULL TOTAL VOL (bbl) 350 I 400 I 400 I III III 0 450 MUD WT GRADE GRADE TOT FOR WELL (bbl) 9.61 I I III III 9224 4 999.98 fD 4.26 3.00 WEIGHT 19.5 49.3 OD 5 5 Progress: 0 Est Cost To Date $ 2500000 Shoe Test: 16.0 , ..[)F\ILL$lSOlfbAT'A LAST BOPIDIVERT LAST BOPIDRILL TST 06/26/2000 0612812000 LAST H2S DRILL 0511612000 LAST CONFINED SPACE 03107/2000 LAST FIRE DRILL 0613012000 LAST SPILL DRILL 06/2412000 FUEL ¡WATER FUEL USED 1770 DRILL WATER USED· BBLS , POTABLE WATER USED - BBLS 250 117 WEATHER&: PERSÖNNEL DATA TEMP of ,43 WIND SPEED 4 WIND DIRECTION 20° CHILL FACTOR OF 43.00 ARCO PERSONNEL 2 CONTRACTOR PERSONNEL 27 MISC PERSONNEL 5 SERVICE PERSONNEL 15 49 CLASS 2 PREM PREM , LeNGTH 0355 201.84 HRS J HOURS OPSCODE HOLE SECT' ' pHASEdP!!; 1.00 CIRC S1P1 Casing and CIRC AND COND MUD. Cementing 2.50 CASG S1P1 Casing and RUN 7" CSG F/61 00' T/8570'. Cementing 1.50 CIRC S1P1 Casing and CIRC AND COND MUD. Cementing 3.00 CASG S1P1 Casing and CONT TO RUN CSG T/11500'. Cementing 2.00 CIRC S1P1 Casing and CIRC AND COND MUD. Cementing 1.00 CASG S1P1 Casing and CONTTO RUN CSG T/12440'. Cementing Daily Drilling Report: CD1-06 07/03/2000 Page 1 ) ) 11:00 AM 05:00 PM 6.00 PRB_CSG S1P1 Ca81ng and PUMP IN AND PUSH CSG WITOP DRIVE T/13500'-WORKING Cementing EACH JOINT SEVERAL TIMES. 05:00 PM 10:00 PM 5.00 CIRC S1P1 Ca81ng and CIRC 0 7 BPM 650 PSI-WORKING CSG. Cementing 10:00 PM 10:30 PM 0.50 CASG S1P1 Casing and UD 1 JT-MIU HANGER-LDG JT-LAND HGR-R/U CMT Cementing HEAD-EST CIRC . 8 BPM. 10:30 PM 11:00 PM 0.50 CIRC S1P1 Casing and CIRC AND COND MUD. Cementing 11:00 PM 12:00 AM 1.00 CEMENT S1P1 Casing and PJSM-TEST LINES T13500 PSI-PUMP 20 BBL WASH-50 BBL Cementing SPACER-54 BBL 15.8 CMT. 24.00 Supervisor: MIKE WHITELEYIPAT REILLY J Daily Drilling Report: CD1-06 07/03/2000 Page 2 ) Phillips Alaska Drilling AFC No. Date Rpt No 998C09 0710412000 18 ) Rig Accept - hrs 0611812000 08:30:00 PM Daily Drilling Report Days Since AccepVEst: 17.15/15 Rig Relase. hrs: TOTAL 161/8" MILL TOOTH BIT, 4 3/4" aD MACH 1X AKO 0 DEG MOTOR, 3JTS 3.5" HWDP, JARS, 2JTS - 31/2" HWDP. . DRILLPIPE DATA WEIGHT GRADE CONNEp'nON 13.3 S135 3-1/21.F. 15.5 G-105 3-1/2" I.F. ·1' .··:.:;,fpRÞßÄm'ø,~.$;EBØJ.4Qij,QP!;;QQPQ:.;·:.::: DISPLACED CEMENT WITH RIG PUMPS AT 8 BPM- RECIPICA TED I FULL RETURNS. BUMPED PLUG TO 3500 PSI- HELD 5 MIN. PLUG DOWN AND J.C. @ 0110 HRS. FLOATS HELD. WELL BREATHING - SI WELL. WOC 4 HRS WITH WELL SI. RD CEMENTING HEAD AND LD LANDING JT. PULLED WEAR RING. INSTALLED 7" PACKOFF AND TESTED TO 250 PSU 5000 PSI. CHANGED TOP PIPE RAMS TO 31/2" X 6" VBR'S. SET TEST PLUG AND RU TO TEST BOP'S. Well: CD1-o6 Depth (MDrrvD) 13510/6838 Prey Depth MD: 13510 Contractor: DOYON Dally Cost $176908 Cum Cost $ 2676430 Rig Name: Doyon 19 Last Csg: 7· 0 13500' Next Csg: NIA Operation At 0600: RIH TO 11,000' Upcoming Operations: TEST 7· CSG - DRILL OUT .'MÛb.DA'I'A D81LLlNGDATA BIT DATA Eft'S MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LSND 13510 4 5RR N WEIGHT ROT WT SIZE SIZE EMPLOYER 8.6ppg 8.5 61/8 VISCOSITY PUWT MAKE MAKE SPILL 38sqc STC HTC N PVNP SOWT TYPE TYPE TYPE 8/15 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) 5/10/12 0862M6980 893ZB APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG 4.8 13510 07/0412000 HTHP WL TRQ BTM DEPTH IN DEPTH IN 13.6mV30 mln 13510 13510 INJECTION SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL 8.0% 0 0 CD1-25 HOLE VOLUME PUMP PRES ADTIAST ADT/AST SOURCE WELL 442bbl III 0/0 I CD1.()6 MBT PUMP NO WOB2 WOB2 RATE (bpm) 18.0 1121 I 0-0 3.5 ph LINER SZ RPM1 RPM 1 PRESSURE (psI) 8.8 5.5161 I 0-100 945 LGS SPM 1 TFA TFA INJECTION FLUIDS 6.3% 01011 OPEN Water Base Muds 1193 PIT VOL GPM2 JETS JETS Diesel 181 I II I1III IIIII 45 Fresh Water 100 DAILY MUD SPS 1 BIT COST BIT COST $11910 I II $2500 $0 0 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) $279227 III 1111NOIA III 1338 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) MI III X 11 I NO I CSG III 10562 JJHA.DE$GRIPTiÓN BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: r;~i¡}fOOE~:;:; .g'EeND?: ·1··.·. 12:00 AM 01:15 AM OD 3.5 3.5 ID 2.766 2.062 5 224.39 DAH-0673 . HöCïFìs'.. 1.25 ôËÜ::;:ÖOr5e< .. CEMENT A0Ieseö'r P1 IÞHASE.óPS Casing and Cementing 01:15 AM 05:15 AM 4.00 CEMENT P1 Other 05:15 AM 06:00 AM 0.75 CASG Pi Other 06:00 AM 07:30 AM 1.50 BOPE PROD Casing and Cementing Daily Drilling Report: CD1-06 07/04/2000 Progress: 0 Est Cost To Date $ 2500000 Shoe Test: . ..Qa LLSlBORlQÄTÄ LAST BOPIDIVERT LAST BOPIDRILL TST 0612612000 07/0412000 LAST H2S DRILL 0511612000 LAST CONFINED SPACE 03/0712000 LAST FIRE DRILL 06130/2000 LAST SPILL DRILL 0612412000 FUEL & WATER FUEL USED 1456 DRILL WATER USED - BBLS POTABLE WATER USED - BBLS 730 119 WEATHER & PER$OHNEL..DÄTA TEMP of 39.9 WIND SPEED 23 WIND DIRECTION 260° CHILL FACTOR OF 16.28 PHILLIPS PERSONNEL CONTRACTOR PERSONNEL 26 MISC PERSONNEL 5 SERVICE PERSONNEL 18 50 C,LASS:2 PREM PREM LENGTH Page 1 ) ) 07:30 AM 12:00 PM 4.50 BOPE PROD Other PJSM. TEST BOP'S AS PER POUCY TO 250 PSI LOW AND 3500 PSI HIGH. HYDRIL TO 2500 PSI. ACCUMULATOR DRILL NO LEAKS. TEST WITNESS WAIVED BY JOHN SPALDING WITH AOGCC. PULLED TEST PLUG AND SET WEAR BUSHING. 12:00 PM 02:00 PM 2.00 OTHER PROD Other L.D.15 STANDS 5" DP OUT OF. DERRICK. RAN L.O.T. ON 9 5/8" X 7" ANNULUS AND FREEZE PROTECTED WITH 65 BBLS DIESEL 02:00 PM 06:00 PM 4.00 EVAL PROD Evaluation R.U. SCHLUMBERGER. RAN USIT LOG FROM 12,830'- 11700'. TOC 012,420'. POOH. 06:00 PM 07:00 PM 1.00 EVAL PROD Evaluation R.D. SCHLUMBERGER. 07:00 PM 07:30 PM 0.50 CLN_OUT PROD Trip In MAKE UP BHA - 6 1/8" MILL TOOTH BIT ON STRAIGHT MOTOR. 07:30 PM 12:00 AM 4.50 TRIP _IN PROD Trip In RIH PICKING UP 3112" DP TO 5380'. 24.00 Supervisor: MIKE WHITELEY )aily Drilling Report: CD1-06 07/04/2000 Page 2 Well Name: CD1-Q6 7/4100 Supervisor: MIKE WHITELEY Date: Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7 II 26# L80 BTCM CSG Used cement unit YES Riç¡ pump used 1.300 psi 1.1 00 psI UXJO psi 900 psi 800 psi w c.::: 700 psi => U) en w 600 psi /::t: 0- 500 psi 400 psi 300 psi 200 psi 100 psi 10 Casing Setting Depth: 3,577' TMD Hole Depth: TOC - 12400' 3090' Mud Weight: 9.8 ppg Length of Open Hole Section: 8,823' EMW= 950 + Mud Weight = 950 psi + 9.8 ppg 0.052 x TVD 3090' EMW for open hole section = 15.7 ppg Pump Rate = .5 BPM Fluid Pumped = 18.0 bbls Fluid Bled Back = 0.0 bbls l~níÍlll ~ \ 11111111 j~"1111111 \TIM8-UNE"< . \::'.":-:: I - .~ --- - - "---.- .. . ... .- ~MiN.)jie:llcici::"· , . . . - -- - - - I ~LEAK-OFF TEST ~CASING TEST -1:1- LOT SHUT IN TIME -:k- CASING TEST SHUT IN TIME _ -+- TIME LINE 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds FOR LOT BBLS PRESSURE r-- -1 -- 0 1 0 psi r ~----- ~ I-~ ~ - --- -' ~-- I-~_ __ _ : 1.0 r _121 psi ~ ~____, 2.0 I 308 psi r I J.--------- i __-_ 3.0_ -t-- 390 psi _¡ ~_.-. I----ml-- 4.Q _ ~ _ 459 ps!_ J ~ n ~. . _n--_~- 5.0 _ 1-- 530 psi --I t I : 6.0 : 591 psi I , I - - - ----f- u - 1 1 r L 1 7.0 __.1 651J?~!---i t 1-_ -_ --~ ___ª.O !. 712 psi ---i Î-- ~- _ _1_ 9.~ r 772 psi ¡ Í--- _ _ l I 10.0 828 psi I r- 1 1--_-_ · 11 ~O _ 1 888 psi --i ~_ _ _ _ 12.0. i ~44.'psi ¡ ~-------- r ~~3.~ n__~- 9!4 psi --I 1--_____ 1_ ~ t'!·O -- i 1 ,018 psi I ~------ _-¡ 15-"~____ i 1,043 psi -I I I 16.0 I 1,063 psi I --------------~ .--. ----+--- --- --I I I 17.0 I 1,088 psi : ---------------4- -- ----+ 1 I I 18.0 I 1,088 psi I ----------4-------+--- - - - I I I I I I I I I ---------I--------+ -- 1 I I I I ~------ ..- i -------- --+ ----.-- ~-i I . I . , . I . ------ J- ---------1 -- --, ~--- - ----- ~_."._"_.......__..._¡".""."........._.........~ ¡¡I I ¡ ~~-~-IN TlME_ i m-- __~HUT IN PRESSUR~ ,~ ~-- O.~ min i ___ -J __1,088 psi i ~- _1.0 min J _ _ _ 967 psi i !--~:O m!~_ J 93~ p~! -I r ~__~:º- min l-u ____-- ~__ 910 psi i ~ I 4.0 min I 882 psi I t-------· --I - --. ---- -- I ~O min -l _ ¡ _ 867 psi _ ¡ I 6.0 min I I 857 psi I ---- . .--1------ I w-f ; 7.0 min : : 846 psi I to- - -I---' f ~_~:O min _. i.. _ __ 1 841 psi i ~ _~.O min ¡ ____-_ I ~6 psi I L..!..O.O "!!~J____J. 826 psi J LEAK-OFF DATA MINUTES «J PRESSURE -í 0 stks I 0 psi -:~ - f- f --1- I . , . . , 1 - I I ---t----- ~ I -+------ - i ~ --i- --j +- - i -- ·1---· ! -I --- 1 - -- i-I i- j ~---- ! i t- ---- i --I t------- I I ~ 1 1 : . I t- - - - I t i- . ----- -+- -- 1 , , , Î------- -I _u - -- -----i , , , . , , 1------- I - - 1- , , , I , , 1 1 . I SHUT I~ TIME I SHUT IN PRESSURE ~ O:O_-m!n lOpS! _ I i 1.0min 2.0 min 3.0 mil.:'__ i ___ 4.0 min i-- 5.0 mini 6.0 '!tin __I 7:0 mini 8.0 min 'I }- - ~ 9.0 min I . - - I 10.0 min I - 1 ~-- - I 15.0 min : - 2 . ~. 0.0 mln _ I 25.0 min I 30.0 min . . - - - &---- fli."..r nll.....r g rua~, II.". ~ A Stbsldlary of PHILLIPS PETROL ElM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES , ------i ------i I , - 1 i . i f .-," I , -f , I - . I i , 1 t - 1- j , ---- j I , --- r . ---- --I --I NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ,~8'1ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended BI Abandoned r-~ Service r~ Gas Injection well 2. Name of Operator . 7. Permit Number Phillips Alaska, Inc. ] ~ 200-083 / 3. Address V[~l~_ _ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ,. '~~ i 50-103-20341-00 & 50-103-20341-70 4. Location of well at surface {~. ~ ! 9. Unit or Lease Name 258' FNL, 2538' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385965, 5975870) i CC';.,',:;...'." ~;2,[ '~ Colville River Unit At Top Producing Interval , . ', .'~, :-: i 10. Well Number 2369' FSL, 1746' FWL, Sec. 34, T12N, RSE, UM ( ASP: 395762, 5978354) i -?/-/-~-'.-%~--- I CD1-06 & CD1-06PH1 At Total Depth , .... :'" '-'- ~ ~ 11. Field and Pool 84' FNL, 2213' FEL, Sec. 3, T11 N, R5E, UM (ASP: 397054, 5975883) L.T. J22:.'.-..;;..'7..~:7'~ CoMIle River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feetI ADL 25559, 25557 & 372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions June 18, 2000 July 8, 2000 July 10, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost 16023' MD /6847' TVD 13414'60' MD /xx TVD YES r'~ No DI N/A feet MD 1571' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SE'i-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I'rOM 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 3577' 12.25" 425 sx AS III LW, 496 sx Class G 7" 26# L-80 Surface 13500' 8.5" 263 sx Class G CD1-06 PB1 cement plug dressed off to 12550' to start CD1-06 sidetrack 24. Per~orations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 12668' 12611' Open hole completion 6.125" OH from 13500'-16023' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13305'-12805' 197 sx 15.8 cement 12805'- 12305' 227 sx 17 cement Date First Production Method of Operation (Flowing, gas lift, etc.) N/A 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) 24-Hour Rate > 28. CORE DATA Bdef description of Ilthology, porosity~ fractures, apparent dips and pressence of oil, gas or water. Submit core chips. .,^ RECEIVED SEP 2 5 2.000 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate 29. ( 30. (" GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverecl and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alpine D 13223' 6796' Base Alpine N/A 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby cert~ that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed A~,~,'~ ~2 Title Alpine Drlllin,q Team Leader Date G, C, Alvord Prepared by Sharon AIIsup-Drake INSTRUCTIONS 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. RECEIVED Item 28: If no cores taken, indicate 'none". Form 10-407 SEP 2 5 2.000 Naska 0il & Gas Cons. Commission Aach0rage Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-06 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:06/18/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20341-00 06/17/00 (D1) MW: 8.7 VISC: 300 PV/YP: 10/95 APIWL: 28.0 TD/TVD: 115/115 (115) DRILLING @ 500' SUPV:REYNOLDS/REILLY Move rig over CD1-06. Accept rig ~ 20:30 hrs. 6/17/00. 06/18/00 (D2) MW: 9.6 VISC: 140 PV/YP: 7/50 APIWL: 17.0 TD/TVD: 2290/2222 (2175) DRILLING AHEAD @ 2650' SUPV:REYNOLDS/REILLY Function test diverter. Pre-spud meeting. Spud and drill from 115' to 2290'. 06/19/00 (D3) MW: 9.6 VISC: 140 PV/YP: 25/50 TD/TVD: 3544/3075 (1254) POOH TO RUN 9-5/8" CASING SUPV:SCOTT REYNOLDS APIWL: 10.0 Drill from 2290' to 2295'. Poor penetration rate. Hole packing off. Mix and pump nut plug sweep. Drill from 2295' to 2875'. Change swab & liner on 92 mud pump. Circulate around nutplug sweep with pump 91. Drill from 2875' to 3544'. 06/20/00 (D4) MW: 9.7 VISC: 48 PV/YP: 13/11 APIWL: 10.0 TD/TVD: 3588/3095 ( 44) TESTING BOPE SUPV:SCOTT REYNOLDS Drill from 3544' to 3588' Pump nutplug sweep. POOH to 1071'. Tight hole @ 2000' & 1675'. RIH. Pump nutplug sweep. POOH. Tight ~ 1200' & 870'. PJSM. Run 9-5/8" casing. Pump cement. 06/21/00 (D5) MW: 9.6 VISC: 43 PV/YP: 7/16 APIWL: 9.0 TD/TVD: 3608/3102 ( 20) DRILLING AHEAD AT 4400'. SUPV:MIKE WHITELEY ND diverter. NU BOPs and test to 250/3500 psi. Circ bttms up. Kick drill followed by well kill drill, drill out plug, FC @ 3503' and F.S. ~ 3587'. Drilled 20' new formation to 3608'. Performed FIT to 16.0 ppg EMW. 06/22/00 (D6) MW: 9.7 VISC: 44 PV/YP: 9/29 TD/TVD: 6137/4080 (2529) DRILLING AHEAD AT 6820' SUPV:MIKE WHITELEY APIWL: 6.2 Displaced hole with clean 9.6 ppg LSND mud. Drilled from 3608' to 4615'. Pumped sweep around and circ hole clean for wiper trip. Made wiper trip to 3550'. No problems. Drilled from 4615'-6137'. Circ hole clean for wiper trip. Made wiper trip to 4600', no problems. RECEIVED SEP 25 2000 Alaska Oil & Gas CoP, s. Commission Anchorage Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/23/00 (D7) MW: 9.7 VISC: 43 PV/YP: 7/23 APIWL: 7.4 TD/TVD: 8484/4986 (2347) DRILLING AHEAD AT 9025' SUPV:MIKE WHITELEY Circ, start sweep around. Drill from 6137' to 7661'. Circ hole clean for wiper trip. Made 20 stand wiper trip to 5750'. No problems. Hole in good shape. Circ, start sweep around. Drill from 7661' to 8484'. No problems. 06/24/00 (DS) MW: 9.6 VISC: 45 PV/YP: 7/28 APIWL: 6.8 TD/TVD:10229/5666 (1745) MAKING WIPER TRIP SUPV:MIKE WHITELEY Drill from 8484' to 9183'. Circ hole clean for wiper trip. wiper trip to 7280'. Drill from 9183' to 10229'. 06/25/00 (D9) MW: 9.6 VISC: 45 PV/YP: 8/22 APIWL: 6.3 TD/TVD:l1900/6332 (1671) DRILLING AHEAD AT 12326' SUPV:MIKE WHITELEY Drill from 10229' to 10707'. Kick drill. Pump sweep around and circ hole clean for wiper trip. Made wiper trip to 8803'. Drilled from 10707' to 11900'. Circ hole clean for wiper trip. Made wiper trip to 9940'. 06/26/00 (D10) MW: 9.7 VISC: 47 PV/YP: 12/24 APIWL: 5.7 TD/TVD:13308/6924 (1408) TRIPPING IN OPEN ENDED TO SET CEMENT PLUG. SUPV:MIKE WHITELEY/PAT REILLY Drilled from 11900' to 13308' Sweep hole, circ cl'ean for wiper trip. Made wiper trip to 10900'. RIH. Circ hi vis nut plug sweep. TOOH. 06/27/00 (Dll) MW: 9.6 VISC: 36 PV/YP: 8/ 9 APIWL: 7.2 TD/TVD:13308/6924 ( 0) TESTING BOPE. SUPV:MIKE WHITELEY/PAT REILLY Continue TOOH, observe well @ shoe 3587', continue TOOH. RIH w/3.5" DP stinger to spot cement kick off plug. PJSM. Spot cement plug 91 from 13305'-12805'. Pump cement. POOH. CBU, rotate and reciprocate @ 12807'. No cement to surface. PJSM. Spot cement kick off plug from 12805' to 12305', pump cement. POOH. Circ bottoms up, rotate and reciprocate. No cement to surface. Observe well. 06/28/00 (D12) MW: 9.8..VISC: 45 PV/YP: 9/22 APIWL: 4.4 TD/TVD:13308/6924 ( 0) KICKING OFF @ 12,557' SUPV:MIKEWHITELEY/PAT REILLY PJSM. Test BOPE to 250/3500 psi. Continue to test BOPE, bag test OK but oil leaking from system, changed out hydril and test 250/2500. RIH with kickoff assembly. Wash and ream from 11917', tight ~ 11950', wash to 12012'. Wash / ream from 12012' to 12293', intermittent packoff. Work through several times. Back ream and wash from 12293' to 11912', continued packoff. Wash/ream from 11912' to 12007', RIH to 12198', wash/ream to 12300'. Circ hi vis n~~~.~ Tag cement ~ 12300' drill to 12390' SEP 25 2000 Nask~ 0il & Gas Cons, Oommission Anchorago Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/29/00 (D13) MW: 9.8 VISC: 45 PV/YP: 9/26 APIWL: 4.2 TD/TVD:13090/6770 ( 0) SLIDING 13,261' SUPV:MIKE WHITELEY/PAT REILLY Continue to drill cement from 12550'. Circ hi vis nut plug sweep. Time drill from 12550' to 13090'. Fire drill. 06/30/00 (D14) MW: 9.8 VISC: 43 PV/YP: 9/26 APIWL: 4.2 TD/TVD:13510/6838 (420) TRIPPING OUT @ 6100' SUPV:MIKE WHITELEY/PAT REILLY Drill from 13090' to 13510'. Circ hi vis nut plug sweep. Observe well, TOOH to 10484'. No problems. RIH to 13510' Circ hi vis nut plug sweep. PJSM. RIH. Circ. 07/01/00 (D15) MW: 9.9 VISC: 44 PV/YP: 8/22 APIWL: 4.3 TD/TVD:13510/6838 ( 0) LAYING DOWN DRILL PIPE. SUPV:MIKE WHITELEY/PAT REILLY Back'ream from 8550' to 7399'. POOH to 6533'. Back ream to 3587' (shoe), packoff. Observe well, continue to POOH wet. RIH with hole opener assembly. 07/02/00 (D16) MW: 9.8 VISC: 41 PV/YP: 7/17 APIWL: 4.0 TD/TVD:13510/6838 ( 0) RUNNING 7" CASING ~ 9500' SUPV:MIKE WHITELEY/PAT REILLY Continue to RIH to 13273'. Est circ and ream from 13273' to 13510'. Circ sweeps and condition mud. Check flow, POOH to 12132' POOH. PJSM. RIH with 7" casing. Circ and condition mud. 07/03/00 (D17) MW: 9.6 VISC: 38 PV/YP: 7/16 APIWL: 6.0 TD/TVD:13510/6838 ( 0) INSTALLING PACKOFF. SUPV:MIKE WHITELEY/PAT REILLY Circ and condition mud. Run 7" casing from 6100' to 8570' Circ and condition mud. Continue to run casing. PJSM. Pump wash and spacer and cement. 07/04100 (D18) TD/TVD:13510/6838 ( SUPV:MIKEWHITELEY MW: 9.6 VISC: 38 PV/YP: 8/15 0) RIH TO 11,000' APIWL: 4.8 Displaced cement with rig pumps, reciprocated / full returns. Bumped plug. Floats held. Well breathing, SI well. Installed 7" packoff and tested to 250/5000 psi. Set test plug. PJSM. Test BOPs to 250/3500 psi. No leaks. Pulled test plug. Ran LOT. Freeze protected. Ran USIT log from 12830' to 11700'. 07/05/00 (D19) MW: 9.6 VISC: 39 PV/YP: 7/11 APIWL: 7.3 TD/TVD:13530/6839 ( 20) DRILLING AHEAD ~ 13540' SUPV:SCOTT REYNOLDS RIH to 13404'. Circ and condition mud. Test 7" casing to 3500 psi. Tag at 13412'. Drill cement, float equipment and 20' new hole to 13530'. Circulate and condition mud for LOT. Perform FIT to 12.5 ppg EMW. Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 07/06/00 (D20) MW: 9.2 VISC: 48 PV/YP: 10/23 APIWL: 4.4 TD/TVD:14414/6845 (884) UP T/04:00 HRS - DRILLED DOWN 1 & 1/2 STNDS - LOSSES C SUPV:SCOTT REYNOLDS RIH to 13530'. No hole problems. CBU. Displace LSND mud with Flo-Pro mud. No losses. Drill from 13530' to 14266'. Flow decrease from 19% to 14%. Initial loss rate while pumping. Pump LCM pill. Losses down. Drill from 14266' to 14414'. Hole losing 250 bph. Monitor static losses. Spot LCM pill. Pump out to 13500'. Monitor static losses. Pump LCM pill. RIH to 14414' 07/07/00 (D21) MW: 9.3 VISC: 49 PV/YP: 11/23 APIWL: 4.0 TD/TVD:15218/6844 (804) WIPERTRIP TO SHOE @ 13500' LOSSES @ 40-60 BPH. TOTAL SUPV:SCOTT REYNOLDS Drill from 14414' to 14560'. Loss rate @ 180 bph bypassing shakers. Pump nutplug LCM pill. Loss rate slowed. Drill from 14560' to 14972'. CBU. Pump out to 14266'. Spot LCM pill. Pump out to 13506'. Squeeze LCM pill away. Drill from 14972' to 15218'. 07/08/00 (D22) MW: 9.2 VISC: 50 PV/YP: 11/28 APIWL: 4.0 TD/TVD:16023/6848 (805) TOTAL LOSSES FROM 06:00 HRS PREVIOUS DAY APPROX 1400 SUPV:SCOTT REYNOLDS Drill from 15218' to 15524'.Circulate and monitor losses. Monitor well, well breathing. Pump out to shoe @ 13500'. No hole problems. Circulate lovis sweep around. Taking returns across shakers. Flow check well, minor breathing. RIH, wash last 100' to bottom. Drill from 15524' to 15647'. Pump nutplug. Continue to bypass shakers. Drill from 15647' to 16023'. Pump nutplug LCM pills. Circulate while rotating and reciprocating. Monitor well, well breathing. Pump out of hole to 15500' 07/09/00 (D23) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:16023/6848 ( 0) RUNNING 4-1/2' COMPLETION. LOSSES ~ 10 BPH. SUPV:SCOTT REYNOLDS Continue wipertrip to 15524'. Observe well, minor breathing. RIH to 16023'. Spot viscosified brine to shoe @ 13500'. PJSM. Displace with brine. Repair skate. 07/10/00 (D24) TD/TVD:16023/6848 ( SUPV:SCOTT REYNOLDS MW: 9.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) MIRU ON CD1-40 - SPOTTING GIS UNIT AND SETTING 2-WAY C Continue to run 4.5" completion. NU to BAL-O nipple and test to 5000 psi, good. MU hanger, attach dual SSSV control lines, test to 5000 psi, good. ND BOPE. RU SSSV control lines in wellhead and test to 5000 psi, good. NU tree and test to 5000 psi, good. Set BPV. Release rig @ 00:00 hrs. 7/11/00. Date: 08/28/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 07/11/00 (D25) TD/TVD:16023/6848 ( SUPV:SCOTT REYNOLDS MW: 0.0 VISC: 0) N/A 0 PV/YP: 0/ 0 APIWL: 0.0 Continue to do MIT tests. Set BPV and secure well. Release rig @ 0100 hrs. 7/11/2000. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-O0037 Sidetrack No. Page 1 of 6 i~ '-{l_r~-'l Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No.' PAD CD#1/6 PHI'! 6 Survey Section Name CD1-6 PH1 MWD BHI Rep. D NEWLON ~1'~"~~ WELL 'DATA Target TVD (~r) Target Coord. N/$ 8lot Coord. N/8 -~6.&1 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W ' - Slot Coord. F./W 2~38:57 Magn. Declination 25.780 Calculation Method MINIMUM CURYATURE Target Direction ~oo) Buil~Walk\DL per: 100ft~ 30m[-I 10ml-I . Vert. Se~. Azim. 7~ .g~ Magn. to Map Corr. ~$.780 Map North to: OTHER SURVEY DATA Survey Survey. Incl. Hole' Course Vertical -Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction -Length 'I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F~ (OD) (OD) (FT) (FT) - (FT) ~ (Per ~00 FT) Drbp (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT . 18-JUN-00 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 1.5 DEG AKO -- 18-JUN-O0 MWD 203.51 0.66 312.42 88.51 203.51 -0.25 0.34 . -0.38 0.75 0.75 18-J UN-00 MWD 292.70 1.01 313.19 - 89.19 292.69 -0.88 1.23 -1.33 0.39 0.39 18-JUN-00 MWD 382.00 1.00 319.42 89.30 381.97 -1.56 2.36 -2.41 0.12 -0.01 -18-JUN-00 - MWD 469.00 0.18 66.66 87.00 468.97 -1.71 2.99 -2.78 1.23 -0.94 18-JU N-00 MWD 561.00 1.36 122.71 92.00 560.96 :0.88 2.46 -1.73 1.38 1.28 18-JUN-00 MWD 650.00 2.50 125.38 89.00 649.91 0.94 0.76 0.75 1.28 1.28 ! 18-JUN-00 MWD 738.00 3.63 121.82 88.00 737.78 3.88 -1.82 4.68 1.30 1.28 18-JUN-00 MWD 828.00 5.34 117.19 90.00 827.50 8.66 -5.23 10.82 1.94 1.90 -5.14 · 18-JUN-00 MWD 917.00 7.22 119.18 89.00 915.97 15.37 -9.85 19.39 2.13 2.11 2.24 18-JUN-00 MWD 1007.00 9,60 120.91 90.00 1004.99 24.14 '-16.47 30.77 2.66 2.64 1.92 18-JUN-00 MWD . 1102.00 11.24 120.75 95.00 1098.42 35.43 -25.27 45.52 1.73 . 1.73 -0.17 . 18-J U N-00 MWD 1198.00 11.34 120.90 96.00 1192.56 47.78 -34.90 61.66 -0.11 0.10 0.16 -- 18-J UN-00 MWD 1293.00 11.69 116.67 95.00 1285.65 60.74 -44.02 78.28 0.96 0.37 -4.45 18-J U N-00 MWD 1388.00 13.68 104.16 95.00 ' 1378.35 ~7.08 -51.09 97.78 3.56 2.09 -13.17 18-JUN-00 MWD 1483.00 14.13 100.97 95.00 1470.56 96.72 -56.04 120.05 0.94 0.47 -3.36 18-JUN-00 MWD 1579.00 14.87 98.73 96.00 ' 1563.51 117.95 -60.14 143.73 0.97 0.77 -2.33 18-JUN-00 MWD 1674.00 16.56. 94.25 '95.00 1654.96 141.36 ;63.00 169.29 2.19 1.78 -4.72 18-JUN-00 MWD 1768.00 .19.26 90.76 94.00 1744.39 168.42 -64.19 198.15 3.09 2.87 -3.71 18-JUN-00 MWD 1864;00 21.81 87.13 96.00 1834.29 200.62 -63.51 231.80 2.97 2.66 -3.78 18-JUN-00 MWD 1958.00 21.83. 87.59 94.00 i921.56 234.30 -61.90 266.70 0.18 0.02 0.49 18-JUN-00 MWD 2054.00. 24.34 85140 96~00 2009.86 270.73 -59.56 304.26 2.76 2.61 -2.28 18-JUN-O0 MWD 2149.00 .26.83 82.30 95.00 2095.55 310.86 -55.. 12 345.03 2.98 2.62 -3.26 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-(x)037 Sidetrack No. Page 2 of 6 ~1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/6 PH1/6 Survey Section Name CD1-6 PH1 MWD BHI Rep. D NEWLON IN"~"~~ WELL DATA Target TVD (Fr) Target C0ord. N/S Slot Coord. N/S -256.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSL [~ SS[- Target Description Target Coord. EJW Slot Coord. E/W 2538.57 Magn. Declination 25.780 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft[~ 30mQ 10m0 Vert. Sec. Azim. - 71.91 Magn. to Map Corr. 25.780 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) (FT) (FT) (FT) (F'r). (Per 100 FT) Drop (-)' Left (-) 19-JUN-00 MWD 2244.00 28.84 80.03 95.00 2179.55 354.64 -48.28 388.85 2.39 2.12 -2.39 19-JUN-00 MWD 2339.00 31.12 78.73 95.00 2261.84 401.70 -39.52 435.50. 2.50 2.40 -1.37 19-JUN-00 MWD 2434.00 32.83 77.82 95.00 2342.42 451.70 -29.28 484.75 1.87 1.80 -0.96 19-JUN-00 MWD 2529.00 35.19 -76.52' 95;00 2421.17 504.61 -17.47 536.55 2.60 2.48 -1.37 19-JUN-00 MWD 2624.00 37.48 75.03 95.00 2497.69 560.76 -3.62 591.10 2.58 2.41 -1.57 - 19-JUN-00 MWD 2720.00 39.73 74.30 96.00 2572.71 620.58 12.23 - 648.86 2.39 2.34 -0~76 19-JUN-00 MWD 2814.00 42.05 74.97- 94.00 2643.76' 682.04 28.53 708.19 2.51 2.47 0.71 19-JUN-00 MWD 2910.00 44.79 73.10 96.00 2713.49 747.97 46.70 771.61 3.15 2.85 -1.95 19-JUN-00 MWD 3005.00 47.39 72.92 95.00 2779.37 816.39 66.70 837.06 2.74 2.74 -0.19 19-JUN-00 MWD 3100.00 50.84 73.58 95.00 2841.54 888.18 87.38 905.83 3.67 3.63 0.69 19-JUN-00 MWD 3196.00 53.83 74.66 96.00 2900.19 964.11 108.16 978.91 3.24 3.11 1.13 19-JUN-00 MWD 3290.00 56;92 74.18 94.00 2953.60 1041.38 128.94 1053.41 3.31 3.29 -0.51 19-JUN-00 MWD · 3385.00 60.16 74.32 95.00 3003.17 1122.34 150.93 1131.39 3.41 ' 3.41 0.15 20-JUN-00 MWD 3481.00 63.75 74.38 96.00 3048.30 1206.97 173.78 1212.97 '3.74 3.74 0.06 20-JUN-00 MWD - 3528.00 64.31 75.00 47.00 3068.88 1249.18 184.94 . 1253.72 1.68 1.1 9 1.32 22-JUN-00 MWD 3685.00 66.62 75.53 157.00 3134.07 1391.74 .221.26 1391.84 1.50 1.47 0.34 6 3/4' M1XL 1.2 DEG AKO 22-JUN-00 MWD 3780.00 66.50 74.83 95.00 3171.86 1478.76 243.55 1476.10 0.69' -0.13 -0.74 22-JUN-00 MWD 3875.00 66.00 72.51 95.00 3210.13 1565.67 267.99 1559.54 2.30 -0.53 -2.44 22-JUN-00 MWD 3969.00 66.69- 72.98 '94.00 3247.84 ' 1651.76 293.53 1641.77 0.87 0.73 0.50 22-JUN-00 MWD 4065.00 -67.13 . 72.72 96.00 3285.49 1740.06 319.57 1726.15 0.52 .0.46 -0.27 22-JUN-00 MWD 4160.00 67.00 71.90 95.00 3322.51 1827.54 346.16 1809.50 0.81 -0.14 -0.86 22-JUN-00 MWD 4254.00 66.54 72,05 94,00 3359.59 1913.92 372.89 1891.64 0.51 -0,49 0,16 22-JUN-00 MWD 4351.00. 68.10 71.61 97.00 3396.99 2003.42 400.80 1976.67 1.66 1.61 -0.45 22-JUN-00 MWD 4447.00 67.99 71.48 . 96.00 3432.88 2092.45 428.98 2061.13 .0.17 -0.11 -0.14 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00037 Sidetrack No. Page 3 of 6 Company PHILLIPS ALASKA. Rig Contractor & No. Doyon Drilling - Rig: INC. Co. #1 9 Field ALPINE FIELD Well Name & No. PAD CD#1/6 PHi / 6 Survey Section Name CD1-6 PH1 MWD BHI Rep. D NEWLON I~Jr~ ~ WELL DATA Target TVD (FT) Target Ooord. N/S Slot' Ooord. N/S -256.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SSQ Target Description Target Ooord. E/W Slot Ooord. E/W 2538.57 Magn. Declination 25.780 Calculation Method MINIMUM CURVATURE Target Direction (oD) Buil~Walk\DL per: 100ft~ 30m0 10m0. Vert. Sec. Azim. 71.91 Magn. to Map Corr. 25.780 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) (OD) (OD) (FT) (FT) (FT) (FT). (Per 100 FT) D~op (-) Left (-) 22-JUN-00 MWD 4541.00 67.84 71.30 94.00 3468.22 2179.55 456.78 2143.68 0.24 -0.16 -0.19 ,~.~,~ 22-JUN-00 MWD 4536.00 68.08 71.10 95.03 3503.87 .2267.60 485.16 2227.04. 0.32 0.25 -0.21 22-JUN-00 MWD 4731.00 68.69 71.36 95.00 ' 3538.87 2355.92 513.57 2310.66 0.69 0.64 0.27 22-JUN-00 MWD 4826.00 68.64 70.88 95:00 3573.43 2444.40 542.21 2394.39 0.47 -0.05 -0.51 22-JUN-00 MWD 4920.00 68.30 71.80 94.00 3607.93 2531.83 570.19 2477.24 0.98 -0.36 0.98 - 22-JUN-00 MWD 5017.00 68.38 71.78 97.03 3643.73 2621.98 598.36. 2562.87 0.08 0.08 -0.02 22-JU N-00 MWD 5113.00 67.50 72.57 96.00 3679.79 - 2710.95 625.59 2647.57 1.1 9 -0.92 0.82 22-JUN-00 MWD 5208.00 67.99 72.74 95.00 37t 5.77 2798.87 651.81 2731.49 0.54 0.52 0.18 22-JUN-00 MWD 5303.00 68.30 73.04 95.00 3751.13 2887.03 677.75 2815.76 0.44 0.33 0.32 22-JUN-00 MWD 5397.00 66.87 73.64 94.00 3786.97 2973.90 702.66 2899.01 1.63 -1.52 0.64 22-JU N-00 MWD 5492.00 66.85 72.59 95.00 3824.31 3061.23 728.03 2982.60 1.02 -0.02 -1.11 22-JUN-00 MWD 5586.00 66;69 72.60 94.00 3861.38 3147.61 753.87 3065.03 0.17 -0.17 0.01 22-JUN-00 MWD - 5682.00 66.41 72.40 96.00 3899.59 3235.67 780.36 3149.02 0.35 - -0.29 -0.21 22-JUN-00 MWD 5777.00 66.55 72.44 95.00 3937.50 3322.78. 806.66 3232.06 '0.15 0.15 0.04 . -- . 22-JIJN-00 MWD - 5872.00 66.10 72.45 95.00 3975.65 3409.78 832.91 3315.01 0.47 -0.47 0.01 22-JUN-00 MWD 5967.00 66.33 72.23 95.00 4013.96 3496.71 859.28 3397.85 0.32 0.24 -0.23 22-JUN-00 MWD 6064.02 66.56. 71.98 97.02 4052.73 3585.64 886.61 3482.48 0.33' 0.24 -0.26 23-JUN-00 MWD 6159.79 66.54 71.70 95.77 4090.84 3673.50 913.99 3565.96 0.27 -0.02 -0.29 23-JUN-00 MWD 6254.00 66.56- 71.55 '94.21 4128.33 3759.93 941.24 3647.99 0.15 0.02 -0.16 23-JUN-00 MWD 6349.00 -66.17 . 71.53 95.00 4166.42 3846.96 968.79 3730.54 0.41 -0.41 -0.02 23-J UN-00 MWD 6445.00 65.44 71.33 96.00 4205.77 3934.52 996.68 3813.55 0.78 -0.76 -0.21 23-JUN-00 MWD 6540.00 65.12 71.45 95.00 4245.49' 4020.81 1024.22 3895.33 0,36 -0.34 0,13 23-JUN-00 MWD 6636.00. 65.13 70.62 96.00 4285.87 4107.89 1052.52 3977.69 0.78 0.01 -0.86 23-JUN-00 MWD 6731.00 ..66.50 71.09 95.00 4324.79 4194.54 1080.94 4059.56 1.51 1.44 0.49 = [ !_r~ '_ I =(--1 CompanY PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & NO.. PAD CD#1/6 PHI'/6 Survey Section Name CD1-6 PH1 MWD BHI Rep. D NEWLON I~I~'"~1~ WELL OATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -255.61 Grid Correction 0.000 Depths Measured From: FIKB Target Description Target Coord. E/W Slot Coord. E/W 2538.57 Magn. Declination 25.780 Calculation Method MINIMUM CURVATURE Target Direction (oD) Builc~Walk\DL per: 100ft~ 30m[--I lomr-1 -reft. Sec. Azim. 71.91 Magn. to Map Corr. 25.780 Map North to: OTHER SURVEY DATA Survey Survey · Incl. Hole Course Vertioal 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/ (FO (F-r) (Fi') - '(Per 100 FT)Drop (-) Left (-) 23-JUN-O0 MWD 6826.00 67.57 71.68 95.00 4361.86 4282.00 -- 1108.86 4142.45 1.26 1.13 0.62 23-JU N-O0 MWD 6921.00 67.63 70.48 95.00 4398.06 -4369.82 1137.34 4225.54 1.17 0.06 -1.26 23-JU N-O0 MWD 7016.00 67.60 71.52 95.00 4434.24 4457.65 1165.94 4308.59 1.01 -0.03 1.09 23-J UN-O0 MWD 7111.00 68.22 71.21 95.00 4469.97 4545.68 1194.07 4392.00 0.72 0.65 -0.33 23-J UN-00 MWD 7206.00 68.75 71.16 95.00. 4504.81 4634.05 1222.57 4475.66 0.56 0.56 -0.05 · 23-JUN-O0 MWD 7300.00 68.46 72.47 94.00 4539.10 4721.57 1249.88 4558.81 1.33 -0.31 1.39 23-JUN-O0 MWD 7491.00 69.23 73.13 191.00 4608.03 4899.67 1302.56 4728.97 0.52 0.40 0.35 23-JUN-O0 MWD 7587.00 67.38 73.29 96.00 4643.52 4988.85 1328.32 4814.36 1.93 -1.93 0.17 23-JUN-00 MWD 7680.00 68.03 73.99 93.00 4678.80 5074.85 1352.56 4896.92 0.99 0.70 0.75 23-JUN-O0 MWD 7776.00 66.72 73.82 96.00 4715.73 5163.41 1377.12 4982.06 1.37 -1.36 -0.18 23-JUN-00 'MWD 7871.00 67.00 73.71 95.00 4753.06 5250.72 1401.55 5065.94 0.31 0.29 -0.12 23-JUN-O0 MWD 7967.00 67.29 73.50 96.00 4790.35 5339.14 1426.51 5150.80 0.36 0.30 -0.22 23-JUN-00 MWD- -8062.00 67.53 73.06 95.00 4826.84 5426.83 1451.75 5234.80 0.50 · 0.25 -0.46 23-JUN-O0 MWD 8157.00 67.72 72.68 95.00 4863.01 5514.66 .1477.62 5318.75 0.42 0.20 -0.40 -- 23-JUN-00 MWD · 8252.00 67.72 72.17 95.00 4899.02 5602.57 1504.17 5402.56 0.50 0.00 -0.54 23-J UN-O0 MWD· 8347.00 67.91 71.62 95.00 4934.90 5690.53 1531.50 5486.17 0.57 0.20 -0.58 23-JUN-O0 - MWD 8445.00 68.30 71.68 98.00 4971.44 5781-.46 1560.13 5572.48 0.40' 0.40 0.06 24-J UN-00 MWD 8539.00 67.17 71.46 94.00 5007.06 5868.45 1587.63 5655.00 1.22 -1.20 -0.23 24-JUN-00 MWD 8633.00 67.30· 70.78 94.00 5043.43 5955.12 1615.68 5737.02 0.68 0.14 -0.72 . 24-JUN-00 MWD 8727.00 67.08 70.48 94.00 5079.87 6041.75 1644.42 5818.76 0.38 -0.23 -0.32 24-JUN-O0 MWD 8823.00 67.09 70.31 96.00 5117.25 61'30.14 1674.09 5902.06 0.16 0.01 -0.18 24-JUN-O0 MWD 8918.50 66.79 69.73 95.50 5154.66 6217.96 1704.11 5984.64 0.64 -0.31 -0.61 24-JUN-00 MWD 9012.00 . 65.61 70.62 93.50 5192.39 6303.47 1733.13 6065.11 1.53 -i .26 0.95 24-JU N-O0 MWD 9109.00 65.36 71.92 97.00 5232.64 6391.72 1761 ;47 6148.69 .1.25 -0.26 1.34 ' i J IL. .J L J :11[~1-'1=[...-1 Company PHILLIPS ALASKA, INC. Rig Contractor& No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No.' PAD CD#1/6 PH1/6 Survey Section Name CD1-6 PH1 MWD BHI Rep. D NEWLON i~lrr~~ WELL DATA Target'l'VD (Fr) Target Coord. N/S Slot Coord. N/S -256.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE] SS~ Target Description 'Target Coord. E/W ' ' Slot Coord. E/W 2538.57 Magn. Declination 25.780 Calculation Method MINIMUM CURVATURE Target Direction (DO) Buil~Walk\DL per: lOOff[~ 30m~ 1Omo Vert. Sec. Azim. 71.91 Magn. to Map Corr. 25.780 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) (DO) (DD) '~ (F'r) (FT) (FT) . (Per loo Fi') Drbp (-). Left (-) 24-JUN-O0 MWD 9204.92 68.30 71.65 95.92 5271.91 6479.23 1788.82 6231.82 1.01 0.98 -0.28 ~ . 24-JUN-O0 MWD 9300.00 66.45 71.92 95.08 5310.02 . 6566.34 1816.05 6314.56 0.30 0.16 0.28 24-J UN-O0 MWD 9395.00 66.83 71.37 95.00 5347.69 6653.55 1843.52 6397.34 0.67 0.40 -0.58 24-JUN-O0 MWD 9491.00 67.40 -72.05 96.00 5385.02 6741.99 1871.27 6481.31 0.88 0.59 0.71 24-JUN-O0 MWD 9585.00 67.66 71.74 94.00 5420.95 6828.85 1898.26 6563.88 0.41 0.28 -0.33 24-JUN-O0 MWD 9680.00 67.63 70.60 95.00 5457.08 6916.71 1926.62. 6647.03 1.11 -0.03 -1.20 24-JUN~O0 MWD 9775.00 68.15 70.35 95.00 5492.84 7004.69 1956.04 6729.98 0.60 0.55 -0.26 24-JUN-O0 MWD 9871.00 67.90 71.44 96.00 5528.76 7093.70 1985.17 6814.10 1.08 -0.26 1.14 24-JUN-O0 MWD 9967.00 68.27 70.84 96.00 5564.59 7182.75 2013.97 6898.39 0.70 0.39 -0.63 24-JUN-00 MWD 10063.00 67.06 71.76 96.00 5601.07 7271.54 2042.44 6982.49 1.54 -1.26 0.96 24-JUN-O0 MWD 10159.00 67.39 70.72 96.00 5638.24 7360.05 2070.90 7066.30 1.06 0.34 -1.08 _ 24-JUN-O0 MWD 10253.00 65.88 71.88 94.00 5675.52 7446.33 2098.57 7148.03 1.97 -1.61 1.23 25-JUN-O0 MWD 10349.00 68.26 71.71 96.00 5714.46 7534.08 2125.99 7231.39 0.43 - 0.40 -0.18 25-JUN-O0 MWD 10443.00 66.07 70.89 94.00 5752.44 7620.06 .2153.55 7312.83 '0.82 -0.20 -0.87 ' -'x -- 25-JUN-O0 MWD 10538.00 66.19 70.58 95.00 5790.88 7706.92 2182.22 7394.84 0.32 0.13 -0.33 25-JUN-O0 MWD. 10630.00 66.16 71.06 92.00 5828.05 7791.06 2209.87 7474.33 0148 -0.03 0.52 25-JUN-O0 - MWD 10728.00 66.47. 69.53 98.00 5867.42 7880.77 2240.13 7558.81 1.46' 0.32 -1.56 25-JUN-O0 MWD 10823.00 66.44 69.29 95.00 5905.37 7967.77 2270.76 7640.34 0.23 -0.03 -0.25 25-JUN-O0 MWD 10917.00 66.58- 71.39 94.00 5942.64 - 8053.94 2299.76 7721.52 2.05 0.15 2.23 _ 25-JUN-O0 MWD 11015.00 -67.02 . 71.37 98.00 5981.44 8144.02 2328.52 7806.88 0.45 0.45 -0.02 25-JUN-O0 MWD 11108.00 67.37 70.83 93.00 6017.49 8229.74 2356.29 7887.99 0.65 0.38 -0.58 25-JUN-O0 MWD 11205.00 67.85 70.98 97.00 6054.44 8319.41 2385.63 7972.74 0.52 0.49 0.15 25-JUN-O0 MWD 11300.00. 67.03 72.45 95.00 6090.89 8407.14 2413.15 8056.04 1.67 -0.86 1.55 25-JUN-O0 MWD 11395.00 67.46 71.96 95.00 -6127.63 8494.74 2439.93 8139.45 .0.66 0.45 -0.52 iija,I SURVEY CALCULATION AND FIELD WORKSHEET No. Sidetrack No. age 8 ot 6 II '- [1[~ '- I =~1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & N°. PAD CD#1/6 PHi ! 6 Survey Section Name CD1-6 PH1 MWD BHI Rep. D NEWLON I~rr~~ WELL DATA Target TVD 0~-r) Target Coord. N/S Slot Coord. N/S -256.61 Grid Correotion 0.000 Depths Measured From: RKB Target Desoription Target Coord. E/W ' ' Slot Coord. E/W 2538.57 Magn. Deolination 25.780 Calculation Method MINIMUM CURVATURE Target' Direction (nD) Buil~Walk\DL per: lOOftl~I 30ml-I 10m I-I - Vert. Sec. Azim. 71.91 Magn. to Map Corr. 25.780 Map North to: OTHER SURVEY DATA Survey Survey- Incl. Hole Course Vertioal Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction ' Length TVD Section N(+) /S(-) E(+) /W(-) DL Bu!ld (+) Right (+) Comment Type (FT) (OD) (OD) (FT) (FT)' (FT) (FT)- (Per 100 FTJ Drop (-) Left (-) 25-JUN-00 MWD 11491.00 67.25 71.33 96.00 6164.59 8583.34 -.- 2467.83 8223.54 0.64 -0.22 -0.66 25-JUN-00 MWD 11586.00 65.88 74.18 95.00 6202.38 . 8670.48 2493.67 8306.77 3.11 -1.44 3.00 25-JUN-00 MWD 11681.00 65.72 74.02 95.00 6241.32 8757.07 2517.41 8390.11 0.23 -0.17 -0.17 25-JUN-00 MWD 11776.00 65.67 - 73.00 95;00 6280.43 8843.61 2541.99 8473.12 0.98 -0.05 -1.07 25-JUN-00 MWD 11870.00 66.00 73.97 94.00 6318.91 8929.34 2566.37 8555.35 1.00 0.35 1.03 -26-JUN-00 ' MWD 11967.00 66.04 74.20 97.00 6358.33 9017.90 2590.67 - 8640.58 0.22 0.04 0.24 26-JUN-00 MWD 12061.00 66.23 73.24 94.00 6396.36 - 9103.82 2614.77 8723.09 0.96 0.20 -1.02 26-JUN-00 MWD 12156.00 66.84 73.59 95.00 6434.19 9190.94 2639.64 8806.61 0.73 0.64 0.37 26-JUN-00 MWD 12252.00 66.74 72.97 96.00 6472.02 9279.14. 2665.02 8891.11 0.60 -0.10 -0.65 26-JUN-00 MWD 12346.00 64.80 71.18 94.00 6510.60 9364.85 2691.39 8972.66 2.70 -2.06 -1.90 26-JUN-00 MWD 12440.00 64.82 71.38 94.00 6550.61 9449.90 2718.69 9053.22 0.19 0.02 0.21 26-JUN-00 MWD 12536.00 64,75 72.10 96.00 6591.51 9536.76 2745.91 9135.70 0.68 -0.07 0.75 26-JUN-00 MWD 12632.00 64.64 70.98 96.00 6632.54 9623.54 2773.39 9218.02 1.06 - -0.11 -1.17 , o ~.~ 26-JUN-00 MWD 12725.00 64.54 71.13 93.00 6672.45 9707.54 .2800.66' 9297.48 '0.18 -0.11 0.16 -- 26-JUN-00 MWD .12821.00 64.23 71.53 96.00 6713.95 9794.10 2828.37 9379.49 0.50 -0.32 0.42 26-JUN-00 MWD 12915.00 64.09 71.41 - 94.00 6754.92 98~8.69 2855.26 9459.70 0.19 -0.15 -0.13 26-JUN-00 MWD 13011.00 63.87 72.22 96.00 6797.04 9964.96 2882.18 9541.66 0.79' -0.23 0.84 26-JUN-00 MWD 13106.00 64.21 71.24 95.00 6838.62 10050.38 2908.96 9622.77 0.99 0.36 -1.03 26-JUN-00 MWD 13200.02 64.89- 72.37 94.02 6879.03 10135.27 2935.46 9703.42 1.30 0.72 1.20 26-JUN-00 MWD 13234.00 65.06 71.46 33.98 6893.40 10166.06 2945.02 9732.69 2.48 0.50 -2.68 26-JUN-00 MWD 13308.00 65.06 71.46 74.00 6924.60 10233.16 2966.36 9796.30 0.00 0.00 0.00 Projected Data - NO SURVEY SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00037 Sidetrack No. I Page 1 of 3 i Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & N0~ PAD CD#1/6 PHi / 6 Survey Section Name CD1-6 MWD BHI Rep. C MILCHAK / B HENDERSON .e~ ~ ~Ig~,,a~ WELL DATA ' Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -256.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W ' ' Slot Coord. E/W 2538.57 - Magn. Declination 25.780 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m0 10m0 Vert. Sec. Azim. 151.99 Magn. to Map Corr. 25.780 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(-) El+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (OD) '- (DD) (FT) (F'r) (FT) . (FT). Per 400 FT) Drop (-) Left (-) MWD 12536.00 64.75 72.10 6591.51 1866.25 '~ '2745.91 9135.70 TIE IN POINT 29-JUN-00 MWD 12550.00 64.87 71.53 14.00 6597.47 . 1868.25 2749.88 9147.74 3.78 0.86 -4.07 6 3/4' MIX 1.5 DEG AKO 29-JUN-O0 MWD 12576.95 65~31 73.54 26.95 6608.82 1872.73 2757.20 9171.05 6.96 1.63 7.46 29-JUN-00 MWD 12605.58 65.56 - 76.85- 28;63 6620.73 1878.68 2763.85 9196.22 10.55 0.87 11.56 29-JUN-00 MWD 12639.03 66.90 80.95 33.45. 6634.21 1887.58 2769174 9226.25 11.91 4.01 12.26 29-JUN-00 ' MWD 12671.10 68.01 84.52 32.07 6646.51 1898.07 2773.48 - 9255.63 10.85 3.46 11.13 29-JUN-00 MWD 12700.00 69.26 88.43 28.90 6657.04 1909.23 2775.13 9282.48 13.32 4.33 13.53 29-JUN-00 MWD 12732.36 70.65 91.96 32.36 6668.14 1923.60 2775.02 9312.88 11.11 4.30 10.91 29-JUN-00 MWD 12764.49 71.88 96.80 32.13 6678.46 1939.90 2772.69 9343.21 14.77 3.83 15.06 29-JUN-00 MWD 12795.62 73.68 100.11 31.1 3 6687.68 1957.57 2768.32 9372.61 11.69 5.78 10.63 29-JUN-00 MWD 12827.60 74.09 100.96 31.98 6696.56 1976.71 2762.70 9402.81 2.86 1.28 2.66 · . 29-JUN-00 MWD 12854.56 74:16 101.24 26.96 6703.93 1993.07 2757.71 9428.26 1.03 0.26 1.04 29-JUN-00 MWD 12892.02 73.94 101.82 37.46 6714.23 2016.00 2750.51 9463.55 1.60 -0.59 1.55 29-JUN-00 MWD 12923.63 74.03 101.61 31.61 6722.95 2035.42 .2744.34 9493.30 -0.70 0.28 -0.66 -- 29-JUN-00 MWD 12955.72 74.09 101.94 32.09 6731.76 2055.16 2738.04 9523.51 1.01 0.19 1.03 . 29-JUN~00 MWD 12986.53 74.80 103.45 '30.81 6740.02 2074.52 2731.52 9552.46 5.25 2.30 4.90 29-JUN~00 MWD 13019.94 75.10 106.75 33.41 6748.70 2096.57 2723.11 9583.61 9.58' 0.90 9.88 29-JUN-00 MWD 13050.20 75.64 109.57 30.26 ' 6756.35 2117.69 2713.99 9611.43 9.19 1.78 9.32 29-JUN-00 MWD 13081.10 76.53. -112.70 '30.90 6763.78 2140.37 2703.18 9639.40 10.25 2.88 10.13 ' ' 30-JUN-00 MWD 13114.04 76.91 116.39 32.94 6771.35 2165.82 2689.86 9668.55 10.96 1.15 11.20 '. 30-JUN-00 MWD 13145.45 76.88 120.20 31.41 6778.47 2i 91.27 2675.36 9695.49 11.81 -0.10 12.13 30-JUN-00 MWD 13177.04 77.09 123.54 31.59 6785.59 2217.89 2659.11 9721.62 10.32 0.66 10.57 30-JUN-00 MWD 13209.16. 76.92 - 126136 32.12 6792.81 2245.76 2641.19 9747.27 8.57 -0.53 8.78 30-JUN-00 MWD 13240.92 -76.80 129.95 31.76 6800.03 2274.04 2622.08 9771.59 11.01 -0.38 11.30 i ' aMf, F.,R. i SURVEY CALCULATIONAND FIELDWORKSHEETJob No. 0450-(XX)37 Sidetrack No. 1 Page 2 of 3 ii '-[l[e-] ;1=(~1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co~ - Rig: #1 I 9 Field ALPINE FIELD / Well Name & No.' PAD CD#1/6 PH1 / 6 Survey Section Name CD1-6 MWD BHI Rep. C MILCHAK / B HENDERSON I~"~1~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/$ -256.61 Grid Correction 0.000 Depths Measured From: RKB gl MSL0 SSI] Target Description Target Coord. E/W Slot Coord. ~ 2538.57 Magn. Deolinafion 25.780 Calculation Method MINIMUM CURVATURE Target Direction (DO) Buil~Walk\DL per: lOOft~ 30ml-J lOml-I Vert. Seo. Azim. 151.99 Magn. to Map Corr. 25.780 Map North to: OTHER S U RVEY. 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 (Fr) (OD) (D_D) (FT) (Fr) (Fr) (FT) - (Per 100 FT) Drop (-) Left (-) 30-JUN-O0 MWD 13272.37 77.24 133.38 31.45 6807.10 2302.78 '--- 2601.71 9794.48 10.72 1.40 10.91 .,-,~,,_ 30-JUN-O0 MWD 13304.23 78.55 135.72 31.88 6813.78 .2332.49 2579.86 9816.67 8.27 4.11 7.34 30-JUN-O0 MWD 13336.12 80.03 137.80 31.89 6819.71 2362.73- 2557.03 9838.14 7.91 4.64 6.52 30-JUN-O0 MWD 13368.67 81.44 140.03 32.55 6824.95 2394.02 2532.82 9859.25 8.03 4.33 6.85 30-JUN-OQ MWD 13399.84 83.34 142.56 31.17 - 6829.08 2424.37 2508.71 9878.56 10.09- 6.10 8.12 30-JUN-O0 MWD 13431.69 85.18 145.13 31.85 6832.26 2455.74 2483.13 9897.25 9.89 5.78 8.07 06-JUL-O0 MWD 13510.83 88.11 149.33 79.14 6836.90 2534.45 2416.72 9940.00 6.46 3.70 5.31 4 3/4' MlX 1.2 DEG AKO 06-JUL-O0 MWD 13606.42 89.73 150.40 95.59 6838.70 2629.95 2334.06 9987.98 2.03 1.69 1.12 06-JUL-O0 MWD 13702.63 88.18 151.16 96.21 6840.45 2726.12 2250.11 10034.93 1.79 -1.61 0.79 06-JUL-O0 MWD 13799.16 88.63 11~1.58 96.53 6843.14 2822.60 2165.42 10081.17 0.64 0.47 0.44 06-JUL-O0 MWD 13894.67 88.77 152.10 95.51 .6845.31 2918.09 2081.24 10126.23 0.56 0.15 0.54 06-JUL-O0 ' MWD 13991.17 89.25 152.30 96.50 6846.98 3014.57 1995.89 10171.23 0.54 0.50 0.21 06-JUL-O0 MWD' 1-4083.60 89.76 151.63 92.43 6847.77 3107[00 1914.31 10214.67 0.91 0.55 -0.72 .-~_-- 06-juL'o0 MWD 14176.69 90.31 153.20 93.09 6847.72 3200.08 -1831.80 10257.78 ~ .79 0.5g 1.69 06-JUL-O0 MWD 14269.74 90.89 154.52 93.05 6846.74 3293.07 1748.28 10298.77 1.55- 0.62 1.42 06-JUL-00 MWD- 14358.15 91.10 155.05 88.41 6845.21 3381.37 1668.30 10336.43 0.64 0.24 0.60 07-JUL-O0 ' MWD 14453.81' 89.93- 152.85 95.66 6844.35 3476'.96 1582.37 10378.43 2.60 -1.22 -2.30 07-JUL-00 MWD 14547.41 90.89 153.09 93.60 6843.68 3570.54 1499.00 10420.97 1.06 1.03 0.26 07-JUL-O0 MWD 14639.49 89.38 152.90 92.08 6843.46 3662.60 1416.96 10462.78 1.65 -1.64 -0.21 07-JUL-O0 MWD 14734.21 90.10 152.66 94.72 6843.89 3757.31 1332.73 10506.10 0.80 0.76 -0.25 07-JUL-O0 MWD 14825.54 90.72 152.39 91.33 6843.24 3848.64 1251.71 10548.24 0.74 0.68 -0.30 07-JUL-O0 MWD 14918.99 89.28 153.63 93.45 6843.24 3942.07 1168.44 10590.65 2.03 -1.54 1.33 07-JUL-O0 MWD 15011.12 · 90.21 '154.45 92.13 6843.65 4034.14 1085.61 10630.97 1.35 1.01 0.89 07-JUL-O0 MWD 15104.01 89.86 153.78 92.89 ' 6843.59 4126.96 1002.04 10671.53 0.81 -0.38 -0.72 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00037 Sidetrack No. I Page 3 of 3 i Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 Field ALPINE FIELD · Well Name & No.' PAD CD#1/6 PH1 / 6' Survey Section Name CD1-6 MWD BHI Rep. C MILCHAK / B HENDERSON Jlr~"Jl"~~ WELL DATA Target TVD (FT) Target Goord. N/$ Slot Coord. N/$ -~&.&l Grid Gorreotion 0.000 Depths Measured From: FIKB Target Desoription Target Coord. E/W Slot Coord. F_/W ~538.67 Magn. Deolination ~S.780 Galoulation Method MINIMUM GURVATURF: Target DireCtion (on) Buil~Walk\DL per: 100ft~ 30m~ 10m~ Vert. 8e¢. Azim. 1~1 .gg Magn. to Map Gorr. ~.780 Map North to: OTHEFI SURVEY DATA gurvey Survey - In~l. Hole Gourse Vertioal Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Dire~ion 'Length TVD Seotion N(+) /8(-) I:(+) /W(-) DL Bui!d (+) Flight (+) Gomment Type (Fr) (DO) · (DD) (Fr') (FT) (Fl') (FT) . iPer 100 FT)Drop (-) ' Left (-) -.. 07-JUL-O0 MWD 15196,72 89,55 151,80 92,71 6844,07 4219,66 919,59 10713,92 2,16 -0,33 -2,14 08-JUL-O0 MWD 15289,41 89,73 152,67 92.69 6844,65 - 4312,34 837.58 10757,09 0,96 0,19 0,94 08-JUL-O0 MWD 15381,37 90,21 153,56 91,96 6844,70 4404,28. 755,56 10798,68 1,10 0,52 0,97 08-JUL-00 MWD 15471.52 88.90 152.70 90.15 6845.40 4494.41 675.14 10839.42 1.74 -1.45 -0.95 08-JUL-00 MWD 15564.75 88.70 152.19 93.23. 6847.35 4587.62 592.51 10882.54 0.59 -0.21 -0.55 . 08-JU L-00 MWD 15656.85 89.01 152.99 92110 6849.19 4679.69 510.76 10924.93 0.93 0.34 0.87 . 08-JUL-~0 MWD 15748.66 89.90 153.82 91.81 6850.67 4771.47 428.67 10966.03 1.33 0.97 0.90 08-JUL-00 MWD 15839.94 90.10 152.91 91.28 6850.07 4862.72 347.08 11006.95 1.02 0.22 -1.00 08-JUL-00 MWD -15931.06 91.06 153.90 91.12 6849.14 4953.81 265.61 11047.74 1.51 1.05 1.09 08-JUL-00 MWD 15969.80 91.30 154.46 38.74 6848.35 4992.51 230.74 11064.61 1.57 0.62 1.45 08-JUL-00 MWD 16023.00 91.30 154.46 53.20 6847.14 5045.65 182.75 11087.54 0.00 0.00 0.00 Projected Data - NO SURVEY -- -. ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-06 API number ............... : 50-103-20341-00 Engineer ................. : Rathert Rig: ................... ..: Doyon 19 State: .................. : Alaska 9-Jul-2000 06:28:29 Page 1 of 8 0 R I GIN A'L Spud date ................ : 17 Jun 00 Last survey date ......... : 09-Jul-00 Total accepted surveys...: 190 MD of first survey ....... : 0.00 ft MD of last survey ........ : 16023.64 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 55.78 ft DF above permanent ....... : 55.78 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: 151.99 degrees Geomagnetic data Magnetic model ........... : Magnetic date ............ : Magnetic field strength..: Magnetic dec (+E/W-) ..... : Magnetic dip ............. : BGGM version 1999 27-May-2000 1144.65 HCNT 25.80 degrees 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.78 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.78 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadri~l IDEAL ID6_0C_07] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD 9 depth angle angle length depth - (ft) (deg) (dog) (ft) (ft) 1 0,00 0,00 0,00 2 115,00 0,00 0.00 3 203,51 0,66 312,42 4 292,70 1,01 313,19 5 382,00 1.00 319,42 6 469,00 0,18 66,66 7 561,00 1,36 122,71 8 650,00 2,50 125,38 9 738,00 3.63 121,82 10 828,00 5,34 117.19 11 917,00 7,22 119,18 12 1007,00 9,60 120,91 13 1102,00 11,24 120,75 14 1198,00 11.34 120.90 15 1293,00 11,69 116,67 16 1388,00 13.68 104.16 17 1483,00 14,13 100.97 18 1579,00 14,87 98,73 19 1674,00 16,56 94,25 20 1768,00 19,26 90,76 21 1864,00 21,81 87.13 22 1958,00 21,83 87,59 23 2054,00 24,34 85,40 24 2149,00 26,83 82,30 25 2244,00 28,84 80,03 26 2339,00 31.12 78.73 27 2434,00 32,83 77,82 28 2529,00 35,19 76,52 29 2624,00 37,48 75,03 30 2720,00 39,73 74,30 0,00 115.00 88.51 89,19 89,30 87,00 92,00 89,00 88.00 90,00 89,00 90,00 95,00 96.00 95.00 95,00 95,00 96,00 95,00 94,00 96.00 94,00 96,00 95,00 95,00 95,00 95,00 95,00 95,00 96,00 [(c)2000 Anadrill IDEAL ID6 0C 07] 0,00 115,00 203,51 292,69 381,97 468,97 560.96 649,91 737,78 827,50 915,97 1004.99 1098,42 1192.56 1285.65 1378,35 1470,56 1563.51 1654,96 1744.39 1834.29 1921.56 2009,86 2095,55 2179,55 2261,84 2342,42 2421,17 2497,69 2572.71 9-Jul-2000 06:28:29 Page 2 of 8 Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (dog/ tool (ft) (ft) (ft) (ft) (dog) 100f) type 0,00 0,00 -0,48 -1,71 -3,21 -3,94 -2,98 -0,32 3,80 9,70 17,81 28,99 43,69 59,77 75,62 91,02 105.86 120,60 135,12 149,73 0,00 0,00 0.34 1,23 2,36 0 0 -0 -1 -2 ,00 ,00 ,38 .33 ,41 2,99 2.46 0,76 -1.82 -5,23 -2 -1 0 4 10 ,78 .73 ,74 ,68 ,82 -9,85 -16,47 -25,27 -34,90 -44.02. 19,39 30,77 45,52 61,66 78,28 -51.09 -56.04 -60,14 -63.00 -64,19 97 120 143 169 198 ,78 ,05 ,73 ,29 .15 -63.51 -61.90 -59,56 -55,12 -48,28 231 266 304 345 388 ,80 ,70 ,26 ,03 .85 -39,52 -29,28 -17,47 -3,62 12,23 435 484 536 591 648 ,5O ,75 ,55 ,10 ,86 164,93 179,90 195,48 210,70 225,24 0,00 0,00 0,51 1,81 3,37 4,08 3,00 1.07 5,02 12,02 21,75 34.90 52,07 70,86 89,81 110,32 132,49 155.81 180,63 208,29 240,35 273.79 310,04 349,41 391,83 437,'29 485,63 536,83 591,11 648.98 0,00 0.00 TIP 0,00 0,00 MWD 312,42 0.75 MWD 312,75 0,39 MWD 314,39 0,12 MWD ' 317,10 324.91 44,34 111,24 115,81 116,94 118,15 119,04 119.51 119.35 117,59 115.02 112.71 110,41 107,95 105.32 103,07 101,08 99,08 97.08 95.18 93,46 91,86 90,35 88,92 239,41 253,50 267,40 280,79 293,92 Tool qual type 6-axis 6-axis 6-axis 1,23 MWD 6-axis 1,38 MWD 6-axis 1,28 MWD 6-axis 1,30 MWD 6-axis 1,94 MWD 6-axis 2,13 MWD 6-axis 2.66 MWD - 1,73 MWD 6-axis 0,11 MWD 6-axis 0.96 MWD 6-axis 3,56 MWD 6-axis 0,94 MWD 6-axis 0,97 MWD 6-axis 2,19 MWD 6-axis 3,09 MWD 6-axis 2,97 MWD 6-axis 0,18 MWD 6-axis 2,76 MWD 6-axis 2,98 MWD 6-axis 2.39 MWD 6-axis 2,50 MWD 6-axis 1,87 MWD 6-axis 2,60 MWD 6-axis 2,58 MWD 6-axis RECEI AUG 10 2000 Alaska Oil & Gas Co~s. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) Course length (ft) 94.00 96.00 95.00 95.00 96.00 31 2814.00 42.05 74.97 32 2910.00 44.79 73.10 33 3005.00 47.39 72.92 34 3100.00 50.84 73.58 35 3196.00 53.83 74.66 TVD depth (ft) 2643.76 2713.49 2779.37 2841.54 2900.19 36 3290.00 56.'92 74.18 94.00 2953.60 37 3385.00 60.16 74.32 95.00 3003.17 38 3481.00 63.75 74.38 96.00 3048.30 39 3528.00 64.31 75.00 47.00 3068.88 40 3685.00 66.62 75.53 157.00 3134.07 9-Jul-2000 06:28:29 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) ' (ft) 307.40 28.53 708.19 708.77 321,14 46.70 771.61 773.02 334.22 66.70 837.06 839.71 348.25 87.38 905,83 910.03 364.23 108.16 978.91 984.87 Page At Azim (deg) 87.69 86.54 85.44 84.49 83.70 380.87 128.94 1053.41 1061.27 83.02 398.08 150.93 1131.39 1141.42 82.40 416.22 173.78 1212.97 1225.35 81.85 425.51 184.94 1253.72 1267.29 81.61 458.31 221.26 1391.84 1409.32 80.97 41 3780.01 66.50 74.83 95.01 3171.87 478.20 243.55 1476.11 42 3875.00 66.00 72.51 94.99 3210.13 495.80 267.99 1559.54 43 3969.00 66.69 72.98 94.00 3247.84 511.87 293.53 1641.77 44 4065.00 67.13 72.72 96.00 3285.49 528.51 319.57 1726.15 45 4160.00 67.00 71.90 95.00 3322.51 544.18 346.16 1809.50 46 4254.00 66.54 72.05 94.00 3359.59 559.16 372.88 1891.64 47 4351.00 68.10 71.61 97.00 3396.99 574.45 400.80 1976.67 48 4447.00 67.99 71.48 96.00 3432.88 589.23 428.98 2061.13 49 4541.00 67.84 7'1.30 94.00 3468.22 603.46 456.78 2143.68 50 4636.00 68.08 71.10 95.00 3503.87 617.55 485.16 2227.04 51 4731.00 68.69 71.36 95.00 3538.87 631.73 52 4826.00 68.64 70.88 95.00 3573.43 645.77 53 4920.00 68.30 71.80 94.00 3607.93 659.98 54 5017.00 68.38 71.78 97.00 3643.73 675.32 55 5113.00 67.50 72.57 96.00 3679.79 691.05 1496.07 1582.40 1667.80 1755.48 1842.31 1928.04 2016.90 2105.30 2191.81 2279.27 80.63 80.25 79.86 79.51 79.17 78.85 78.54 78.24 77.97 77.71 513.57 2310.66 2367.05 77.47 542.21 2394.39 2455.02 77.24 570.18 2477.23 2542.01 77.04 598.36 2562.87 2631.79 76.86 625.59 2647.57 2720.48 76.71 2808,19 2896.18 2982.95 3070.17 3156.37 56 5208.00 67.99 72.74 95.00 3715.77 707.32 651.81 2731.49 57 5303.00 68.30 73.04 95.00 3751.13 724.00 677.75 2815.76 58 5397.00 66.87 73.64 94.00 3786.97 741.10 702.66 2899.01 59 5492.00 66.85 72.59 95.00 3824.31 757.95 728.03 2982.60 60 5586.00 66.69 72.60 94.00 3861.38 773.85 753.87 3065.02 [(c)2000 Anadrill IDEAL ID6 0C 07] __ -- 76.58 76.47 76.38 76.28 76.18 3 of 8 DLS Srvy Tool (deg/ tool qual 100f) type type 2.51 MWD 6-axis 3.15 MWD 6-axis 2.74 MWD 6-axis 3.67 MWD 6-axis 3.24 MWD 6-axis 3.31 MWD 6-axis 3.41 MWD 6-axis 3.74 MWD 6-axis 1.68 MWD 6-axis 1.50 MWD 6-axis 0.69 MWD 6-axis 2.30 MWD 6-axis 0.87 MWD 6-axis 0.52 MWD 6-axis 0.81 MWD 6-axis 0.51 MWD 6-axis 1.66 MWD 6-axis 0.17 MWD 6-axis 0.24 MWD 6-axis 0.32 MWD 6-axis 0.69 MWD 6-axis 0.47 MWD 6-axis 0.98 MWD 6-axis 0.08 MWD 6-axis 1.19 MWD 6-axis 0.54 MWD 6-axis 0.44 MWD 6-axis 1.63 MWD 6-axis 1.02 MWD 6-axis 0.17 MWD 6-axis RECEIVED AU( 10 2000 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) TVD depth (ft) 9-Jul-2000 06:28:29 Page 4 of 8 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 61 5682,00 66,41 72,40 96,00 3899,59 789,91 780,35 3149,02 3244,27 62 5777.00 66,55 72,44 95,00 3937,50 805,68 806,66 3232,06 3331,20 63 5872,00 66,10 72,45 95,00 3975,65 821,47 832,91 3315,01 3418,04 64 5967,00 66,33 72,23 95,00 4013.96 837,09 859,28 3397,85 3504,81 65 6064,02 66,56 71,98 97,02 4052,73 852,71 886.61 3482,-48 3593,57 66 6159.79 66,54 71,70 95,77 4090,84 867.74 913.99 3565,96. 3681,23 67 6254,00 66,56 71,55 94,21 4128,33 882,20 941,23 3647,98 3767,45 68 6349,00 66,17 71,53 95.00 4166.42 896.64 968.79 3730,54 3854,28 69 6445,00 65,44 71,33 96,00 4205.76 911,01 996.68 3813,54 3941,64 70 '6540,00 65,12 71,45 95,00 4245,49 925,10 1024,22 3895,33 4027,73 76,08 75,99 75,90 75,81 75,72 75,62 75,53 75,44 75,35 75,27 75,18 75,09 75,01 74,94 74,86 71 6636,00 65,13 70,62 96,00 4285,87 938,79 1052,52 3977,69 4114,59 72 6731,00 66,50 71,09 95,00 4324,79 952,15 1080.94 4059.56 4201,01 73 6826,00 67.57 71.68 95,00 4361,86 966,43 1108,86 4142,45 4288.30 74 6921,00 67.63 70,48 95,00 4398,06 980,30 1137,34 4225,54 4375,92 75 7016,00 67,60 71,52 95,00 4434,24 994,06 1165.94 4308,59 4463,56 76 7111.00 68.22 71,21 95,00 4469,97 1008.40 1194.06 4392,00 4551,43 74,79 77 7206,00 68,75 71,16 95,00 4504,81 1022,52 1222,57 4475,66 4639,63 74,72 78 7300,00 68,46 72,47 94,00 4539,10 1037,45 1249.88 4558.81 4727.04 74,67 79 7491,00 69.23 73,13 191,00 4608,03 1070,87 1302.55 4728.97 4905,08 74.60 80 7587.00 67,38 73,29 96.00 4643,52 1088,22 1328,32 4814,36 4994,25 74.58 74,56 74,55 74,54 74,52 74,50 81 7680.00 68,03 73.99 93,00 4678,80 1105,60 t352,56 4896,92 5080,28 82 7776,00 66,72 73,82 96,00 4715,73 1123,89 1377,12 4982,06 5168,89 83 7871,00 67.00 73.71 95,00 4753,06 1141,72 1401,54 5065',93 5256,24 84 7967,00 67,29 73,50 96,00 4790,35 1159,53 1426,51 5150,80 5344,69 85 8062,00 67,53 73,06 95,00 4826,84 1176,70 1451,75 5234,80 5432,38 86 8157,00 67,72 72,68 95,00 ' 4863,01 ,/1193,28 1477,62 5318,75 5520,19 74,47 87 8252.00 67,72 72.17 95,00 4899,02 1209,20 1504,17 5402,56 5608,04 74,44 88 8347,00 67,91 71,62 95.00 4934,90 1224,33 1531,50 5486,17 5695,92 74,40 89' 8445,00 68,30 71,68 98,00 4971,44 1239,59 1560.13 5572,48 5786,75 74,36 90 8539,00 67,17 71,46 94.00 5007.06 1254,07 1587,63 5655,00 5873,64 74,32 [(c)2000 Anadrill IDEAL ID6_0C_07] 0,35 MWD 6-axis 0,15 MWD 6-axis 0,47 MWD 6-axis 0,32 MWD 6-axis 0,33 MWD 6-axis 0,27 MWD 6-axis 0,15 MWD 6-axis 0,41 MWD 6-axis 0,78 MWD 6-axis 0,36 MWD 6-axis 0,78 MWD 6-axis 1,51 MWD 6-axis 1,26 MWD 6-axis 1,17 MWD 6-axis 1,01 MWD 6-axis 0,72 MWD 6-axis 0,56 MWD 6-axis 1.33 MWD 6-axis 0,52 MWD 6-axis 1,93 MWD 6-axis 0,99 MWD 6-axis 1,37 MWD 6-axis 0,31 MWD 6-axis 0,36 MWD 6-axis 0,50 MWD 6-axis 0,42 MWD 6-axis 0,50 MWD 6-axis 0,57 MWD 6-axis 0,40 MWD 6-axis 1,22 MWD 6-axis RECEIVED AUG 10 ?000 Alaska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 9-Jul-2000 06:28:29 Seq Measured Incl Azimuth Course· TVD Vertical ~ depth angle angle length depth section - (ft) (deg) (deg) (ft) (ft) (ft) Displ +N/S- (ft) 91 8633,00 67,30 70,78 94,00 5043,43 1267,82 1615,68 5737 92 8727,00 67,08 70,48 94,00 5079,87 1280,84 1644,42 5818 93 8823,00 67,09 70,31 96,00 5117,25 1293,77 1674,09 5902 94 8918,50 66,79 69,73 95,50 5154,66 1306,04 1704,11 5984 95 9012.00 65,61 70,62 93,50 5192,39 1318,22 173·3,13 6065 96 9109.00 65.36 71,92 97,00 5232,64 1332,45 1761,47 97 9204,92 66,30 71.65 95,92 5271,91 1347,33 1788.82 98 9300,00 66,45 71,92 95.08 5310,02 1362,16 1816,05 99 9395,00 66.83 71.37 95,00 5347.68 1376,78 1843.51 100 9491,00 67,40 72,05 96,00 5385,02 1391,71 1871,27 6148 6231 6314 6397 6481 101 9585,00' 67,66 71,74 94,00 5420,94 1406,66 1898,26 6563 102 9680,00 67,63 70,60 95,00 5457,08 1420,67 1926,62 6647 103 9775,00 68,15 70,35 95,00 5492,83 1433,66 1956,04 6729 104 9871,00 67,90 71.44 96,00 5528,76 1447,44 1985.17 6814 105 9967,00 68.27 70,84 96,00 5564,59 1461.60 2013,96 6898 96.00 96,00 94,00 96,00 94,00 95.00 92,00 98..00 95,00 94,00 98.00 93,00 97,00 95,00 95,00 106 10063,00 67,06 71,76 107 10159,00 67,39 70,72 108 10253,00 65,88 71,88 109 10349,00 66,26 71,71 110 10443,00 66,07 70,89 5601.07 5638,23 5675,51 5714.45 5752.44 5790,88 5828,05 5867,42 5905,36 5942,84 5981,44 6017,49 6054,44 6090,88 6127,63 111 10538,00 66,19 70,58 112 10630,00 66,16 71,06 113 10728,00 66,47 69,53 114 10823,00 66,44 69,29 115 10917,00 66,58 71,39 116 11015,00 67,02 71,37 117 11108,00 67,37 70,83 118 11205,00 67,85 70,98 119 11300.00 67.03 72.45 120 11395,00 67,46 71,96 Page Displ Total At +E/W- displ Azim (ft) (ft) (deg) [(c)2000 Anadrill IDEAL ID6_0C_07] ,02 5960,18 74,27 ,76 6046,66 74,22 .06 6134,89 74,16 .64 62'22,53 74,11 ,11 6307,88 74,05 ,69 6396,03 74,01 ,82 6483,47 73,98 ,56 6570,52 73.95 ,34 6657,66 73,92 ,31 6746,04 73,90 1475,96 1490,19 1504,14 1519,09 1533,00 2042.44 2070,90 2098.57 2125,99 2153,55 6982 7066 7148 7231 7312 ,88 6832,85 73,87 ,03 6920,61 73,84 ,98 7008,48 73,79 ,10 7097,39 73,76 ,38 7186,36 73.72 1546.20 1559,12 1572,09 1583,33 1595,85 2182.22 2209,87 2240,13 2270,75 2299,76 7394 7474 7558 · 7640 7721 ,49 7275,08 73,70 ,30 7363,51 73,67 ,03 7449,72 73.64 ,39 7537,43 73,62 ,83 7623,34 73,59 1610,55 1624,12 1638,02 1652,83 1668,37 2328,52 2356,28 2385,62 2413,15 2439,93 ,84 7710,11 73,56 ,33 7794,17 73,53 ,81 7883,77 73,49 ,34 7970,64 73.45 ,52 8056,72 73,41 7806,88 8146,74 73,39 7887,99 8232,40 73,37 7972,74 8322,01 73,34 8056,04 8409,70 73,32 8139,45 8497,29 ~3,31 5 of 8 DLS Srvy Tool (deg/ tool qual 100f) type type 0.68 MWD 6-axis 0,38 MWD 6-axis 0,16 MWD 6-axis 0,64 MWD 6-axis 1,53 MWD 6-axis 1,25 MWD 6-axis 1,01 MWD 6-axis 0,30 MWD 6-axis 0,67 MWD 6-axis 0,88 MWD 6-axis 0,41 MWD 6-axis 1,11 MWD 6-axis 0,60 MWD 6-axis 1,08 MWD 6-axis 0.70 MWD 6-axis 1,54 MWD 6-axis 1,06 MWD 6-axis 1,97 MWD 6-axis 0,43 MWD 6-axis 0,82 MWD 6-axis 0,32 MWD 6-axis 0,48 MWD 6-axis 1,46 MWD 6-axis 0,23 MWD 6-axis 2.05 MWD 6-axis 0,45 MWD 6-axis 0.65 MWD 6-axis 0,52 MWD 6-axis 1,67 MWD 6-axis 0,66 MWD 6-axis RECEIVED AUG 1 0 ?_000 Alaska Oil & Gas Cons. Commission 6 n~.hnrao8 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 121 11491.00 67.25 71,33 122 11586,00 65,88 74,18 123 11681,00 65,72 74,02 124 11776,00 65,67 73,00 125 11870.00 66,00 73,97 126 11967,00 66.04 74,20 127 12061,00 66,23 73,24 128 12156,00 66,84 73,59 129 12252,00 66,74 72,97 130 12346,00 64,80 71,18 131 12440,00 64,82 71.38 132 12536,00 64,75 72,10 133 12550.00 64,87 71,53 134 12576,95 65,31 73,54 135 12605.58 65,56 76.85 136 12639.03 66,90 80,95 137 12671,10 68,01 84,52 138 12700,00 69,26 88,43 139 12732,36 70,65 91,96 140 12764,49 71,88 96,80 141 12795,62 73,68 100,11 142 12827,60 74,09 100.96 143 12854,56 74,i6 101,24 144 12892,02 73,94 101,82 145 12923,63 74,03 101,61 146 12955,72 74,09 101,94 147 12986,53 74,80 103.45 148 13019,94 75,10 106,75 149 13050,20 75,64 109,57 150 13081,10 76,53 112,70 TVD depth (ft) 9-Jul-2000 06:28:29 Page 6 of 8 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 96,00 6164,59 1683,23 2467.82 8223,54 8585,85 73,30 95,00 6202,38 1699,50 2493,67 8306,77 8672,99 73,29 95,00 6241.32 1717,68 2517.41 8390,11 8759,64 73,30 95,00 6280,43 1734,97 2541,99 8473,12 8846,21 73,30 94,00 6318,91 1752,06 2566,36 8555.35 8931,.98 73,30 [(c)2000 Anadrill IDEAL ID6_0C_07] 97,00 6358,33 1770,63 2590,67 8640,58 9020,59 73,31 94,00 6396,36 1788.10 2614,76 8723,09 9106,55 73,31 95,00 6434.19 1805,37 2639,64 8806,61 9193,70 73,31 96,00 6472,02 1822,64 2665,02 8891,11 9281,93 73,31 94,00 6510,60 1837,66 2691,39 8972,66 9367,62 73,30 94,00 96,00 14,00 26,95 28.63 1851,39 2718,69 9053,22 9452,63 73,28 1866,10 2745,90 9135,70 9539.45 73.27 1868,26 2749,86 9147,74 9552,11 73.27 1872,73 2757,19 9171,05 9576,55 73,27 1878,68 2763,84 9196,22 9602,57 73.27 6550,61 6591,51 6597,47 6608,82 6620.72 33,45 6634,21 1887.59 2769,73 9226,25 9633.02 73.29 32,07 6646,51 1898,08 2773,47 9255,63 9662,24 73,32 28,90 6657,04 1909,24 2775.12 9282.49 9688.44 73,36 32,36 6668,13 1923.61 2775,01 9312,88 9717,53 73.41 32,13 6678,46 1939,90 2772,69 9343,21 9745,94 73,47 31.13 31,98 26,96 37,46 31.61 6687,68 1957,57 2768,31 9372,61 9772,89 6696,55 1976,72 2762,69 9402,82 9800,28 6703,93 1993,08 2757,70 9428,26 9823,29 6714,22 2016,01 2750,50 94'63,55 9855,16 6722,94 2035,42 2744,33 9493,30 9882,01 6731,76 6740.02 6748,70 6756.34 6763,77 2055,17 2074,53 2096,57 2117,69 2140,38 73,54 73,63 73,70 73,79 73,88 2738,04 9523,51 9909,29 2731,51 9552,47 9935,33 2723,11 9583,61 9962,98 2713,98 9611,43 9987,25 2703,17 9639,40 10011,25 73,96 74,04 74,14 74,23 74,33 32,09 30,81 33,41 30,26 30,90 0,64 MWD 6-axis 3,11 MWD 6-axis 0,23 MWD 6-axis 0,98 MWD 6-axis 1,00 MWD 6-axis 0,22 MWD 6-axis 0,96 MWD 6-axis 0,73 MWD 6-axis 0,60 MWD 6-axis 2,70 MWD 6-axis 0,19 MWD 6-axis 0.68 MWD °6-axis 3.78 MWD 6-axis 6,96 MWD 6-axis 10,55 MWD 6-axis 11,91 MWD 6-axis 10,85 MWD 6-axis 13.32 MWD 6-axis 11,11 MWD 6-axis 14,77 MWD 6-axis 11,69 MWD 6-axis 2,86 MWD 6-axis 1.03 MWD 6-axis 1,60 MWD 6-axis 0,70 MWD 6-axis 1,01 MWD 6-axis 5,25 MWD 6-axis 9,58 MWD 6-axis 9,~9 MWD 6-axis 10,25 MWD 6-axis RECEIVED Alaska 1 0 2000 Oil & Gas Cons. Commission ~ nnhr, rn~18 ANADRILL SCHLUMBERGER Survey Report Seq 151 152 153 154 155 Measured Incl Azimuth depth angle angle (ft) (deg) (deg) 13114.04 76.91 116.39- 13145.45 76.88 120.20. 13177.04 77.09 123.54 13209.16 76.92 126.36 13240.92 76.80 129..95 Course length (ft) 32,94 31.41 31.59 32.12 31.76 156 13272.37 77,24 133.38 157 13304.28 78.55 135.72 158 13336.12 80.03 137.80 159 13368.67 81.44 140.03 160 13399.80 83.34 142.56 31.45 31.91 31.84 32.55 31.13 161 13431.69 85,18 145.13 162 13510.83 88.11 149.33 163 13606.42 89.73 150.40 164 13702.63 88.18 151.16 165 13799.16 88.63 151.58 31.89 79.14 95.59 96.21 96.53 166 13894.67 88.77 152.10 167 13991.17 89.25 152.30 168 14083.60 89.76 151.63 169 14176.69 90.31 153.20 170 14269.74- 90.89 154.52 95.51 96.50 92.43 93.09 93.05 171 14358.15 91.10 155.05 172 14453.81 89.93 152.85 173 14547.41 90.89 153.09 174 14639.49 89.38 152.90 175 14734.21 90.10 152.66 88.41 95.66 93.60 92.08 94.72 176 14825.54 90.72 152.39 177 14918.99 89.28 153.63 178 15011.12 90.21 154.45 179 15104.01 89.86 153.78 180 15196.72 89.55 151.80 91.33 93,45 92.13 92.89 92.71 [(c)2000 Anadrill IDEAL ID6_0C_07] TVD depth (ft) 6771.34 6778.47 6785.58 6792.81 6800.03 6807.10 6813.79 6819.71 6824.95 6829.07 6832.26 6836.89 6838.69 6840.45 6843.14 6845.30 6846.97 6847.77 6847.71 6846.74 6845.20 6844.34 6843.67 6843.46 6843.89 6843.23 6843.23 6843.64 6843.59 6844.06 9-Jul-2000 06:28:29 Page Vertical section (ft) 2165.83 2191.27 2217.89 2245.76 2274.05 2302.78 2332.55 2362.73 2394.02 2424.34 2455.74 2534.45 2629.95 2726.12 2.822.61 2918.09 3014.58 3107.00 3200.09 3293.08 3381.37 3476.96 3570.55 3662.61 3757.32 3848.64 3942.07 4034.14 4126.97 4219.66 Displ Displ Total +N/S- +E/W- displ (ft) (ft) (ft) 2689.85 9668.55 10035.75 2675.35 9695.49 10057.83 2659.11 9721.62 10078.73 2641.18 9747.27 10098.77 2622.08 9771.59 10117.27 7 of 8 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 2601.71 2579.82 2557.03 2532.82 2508.74 9794.48 10134.13 9816.71 10150.04 9838.14 10165.01 9859.25 10179.39 9878.54 10192.12 74.45 74.57 74.70 74.84 74.98 2483.12 2416.71 2334.06 2250.11 2165.41 9897.25 10204.00 9940.00 10229.57 9987.98 10257.07 10034.93 10284.11 10081.17 10311.11 75.12 75.28 75,43 75.59 75.75 2081.23 1995.88 1914.30 1831.80 1748.27 10126.23 10337.90 10171.23 10365.21 10214.67 10392.50 10257.78 10420.05 10298.77 10446.10 75.92 76.33 76.85 77.36 77.88 1668.30 1582.37 14'98.99 1416.95 1332.73 10336.43 10470.19 10378.43 10498.37 10420,97 10528.23 10462.78 10558.29 10506.10 10590.29 78.39 78.90 79.39 79.88 80.37 1251.70 1168.43 1085.60 1002.03 919.59 10548.24 10622.24 10590.65 10654.91 10630.97 10686.26 10671,53 10718.47 10713.92 10753.31 80.83 81.33 81.81 82.29 82.77 83.23 83.70 84.17 84.64 85.09 10 11 10 8 11 .96 .81 .32 .57 .01 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 10.72 8.26 7,93 8.03 10.11 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis .88 .46 .03 .79 .64 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 0.56 0.54 0.91 1.79 1.55 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis .64 .60 .06 ,65 .80 MWD 6-axis MWD 6-axis MWD - MWD 6-axis MWD 6-axis 0.74 2.03 1.35 0.81 2.16 R MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis ECEIVED Alaska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 181 15289,41 89.73 152.67 182 15381.37 90.21 153.56 183 15471.52 88.90 152.70 184 15564.75 88.70 152.19 185 15656.85 89.01 152.99 92.69 91.96 90.15 93.23 92.10 186 15748.66 89.90 153.82 187 15839,94 90.10 152.91 188 15931.06 91.06 153.90 189 15969.80 91.30 154.46 91.81 91.28 91.12 38.74 Survey Projected to TD: 190 16023.64 91.30 154.46 53.84 TVD depth (ft) 6844.65 6844.69 6845.39 6847.35 6849.19 6850.06 6850.06 6849.14 6848.34 6847.12 9-Jul-2000 06:28:29 Page 8 of 8 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 4312.35 837.57 10757.09 10789.65 85.55 4404.29 755.55 10798.68 10825.08 86.00 4494.41 675.14 10839.42 10860.42 86.44 4587.62 592.50 10882.54 10898.66 86.88 4679.70 510.76 10924.93 10936.86 87.32 4771.47 428.67 10966.03 10974.40 87.76 4862.73 347.07 11006.95 11012.42 88.19 4953.81 265.60 11047.74 11050.93 88.62 4992.52 230.74 11064.61 11067.01 88.81 5046.29 182.17 11087.81 11089.31 89.06 0.96 MWD 6-axis 1.10 MWD 6-axis 1.74 MWD 6-axis 0.59 MWD 6-axis 0.93 MWD 6-axis 1.33 MWD 6-axis 1.02 MWD 6-axis 1.51 MWD 6-axis 1.57 MWD 6-axis 0.00 MWD [(c)2000 Anadrill IDEAL ID6 0C 07] R ££1VED AUG 10 2000 Alaska Oil & Gas Co3s. Commission t.nchorage Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-06PH API number ............... : 50-103-20341-70 Rig .................... : Doyon 19 State: ................. : Alaska ANADRILL SCHLUMBERGER Survey report 26-Jun-2000 15:18:23 Page ORIGINAL Spud date ................ : 17 Jun 00 Last survey date ......... : 26-Jun-00 Total accepted surveys...: 141 MD of first survey ....... : 0.00 ft MD of last survey ........ : 13308.00 ft 1 of 6 Survey calculation methods-- Method for positions ..... : Minimum curvature Method for DLS ........ ~..: Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.78 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: 71.91 degrees Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 27-May-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.80 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G... ......... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.78 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.78 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_0C_07] JUL ?_ 0 AJaska Oil & Gas Cons. commissior~ A~ChOrage ANADRILL SCHLUMBERGER Survey Report . 26-Jun-2000 15:18:23 Page 2 of 6 Seq. Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 115.00 0.00 0.00 115.00 3 203.51 0.66 312.42 88.51 4 292.70 1.01 313.19 89.19 5 382.00 1.00 319.42 89.30 6 469.00 0.18 66.66 7 561.00 1.36 122.71 8 650.00 2.50 125.38 9 738.00 3.63 121.82 10 828.00 5.34 117.19 11 917.00 7.22 119.18 12 1007.00 9.60 120.91 13 1102.00 11.24 120.75 14 1198.00 11.34 120.90 15 1293.00 11.69 116.67 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 0.00 0.00 0.00 0.00 115.00 0.00 0.00 0.00 203.51 -0.25 0.34 -0.38 292.69 -0.88 1.23 -1.33 381.97 -1.56 2.36 -2.41 87.00 468.97 -1.71 2.99 -2.78 92.00 560.96 -0.88 2.46 -1.73 89.00 649.91 0.94 0.76 0.74 88.00 737.78 3.88 .-1.82 4.68 90.00 827.50 8.66 -5.23 10.82 89.00 915.97 15.37 -9.85 19.39 90.00 1004.99 24.14 -16.47 30.77 95.00 1098.42 35.43 -25.27 45.52 96.00 1192.56 47.78 -34.90 61.66. 95.00 1285.65 60.74 -44.02 78.28 16 1388.00 13.68 104.16 95.00 1378.35 77.08 -51.09 97.78 17 1483.00 14.13 100.97 95.00 1470.56 96.72 -56.04 120.05 18 1579.00 14.87 98..73 96.00 1563.51 117.95 -60.14 143.73 19 1674.00 16.56 94.25 95.00 1654.96 141.36 -63.00 169.29 20 1768.00 19.26 90.76 94.00 1744.39 - 168.42 -64.19 198.15 21 1864.00 21.81 87.13 96.00 1834.29 200.62 -63.51 231.80 22 1958.00 21.83 87.59 94.00 1921.56 234.30 -61.90 266.70 23 2054.00 24.34 85.40 96.00 2009.86 270.73 -59.56 304.26 24 2149.00 26.83 82.30' 95.00 2095.55 310.86 -55.12 345.03 25 2244.00 28.84 80.03 95.00 2179.55 354.64 -48.28 388.85 26 2339.00 31.12 78.73 95.00 2261.84 27 2434.00 32.83 77.82 95.00 2342.42 28 2529.00 35.19 76.52 95.00 2421.17 29 2624.00 37.48 .75.03 95.00 2497.69 30 2720.00 39.73 74.30 96.00 2572.71 [(c)2000 Anadrill IDEAL ID6 0C 07] __ -- 401.70 -39.52 435.50 451.70 -29.28 484.75 504.60 -17.47 536.55 560.76 -3.62 591.10 620.58 12.23 648.86 Srvy tool type 0.00 0.00 0.00 TIP 0.00 0.00 0.00 MWD 0.51 312.42 0.75 MWD 1.81 312.75 0.39 MWD 3.37 314.39 0.12 MWD 4.08 317.10 1.23 MWD 3.00 324.91 1.38 MWD 1.07 44.34 1.28 MWD 5.02 111.24 1.30 MWD 12.02 115.81 1.94 MWD 21.75 116.94 2.13 MWD 34.90 118.15 2.66 MWD 52.07 119.04 1.73 MWD 70.86 119.51 0.11 MWD 89.81 119.35 0.96 MWD 110.32 117.59 3.56 MWD 132.49 115.02 0.94 MWD 155.81 112.71 0.97 MWD 180.63 110.41 2.19 MWD 208.29 107.95 3.09 MWD 240.35 105.32 2.97 MWD 273.79 103.07 0.18 MWD 310.04 101.08 2.76 MWD 349.41 99.08 2.98 MWD 391.83 97.08 2.39 MWD 437.29 95.18 2.50 MWD 485.63 93.46 1.87 MWD 536.83 91.86 2.60 MWD 591.11 90.35 2.58 MWD 648.98 88.92 2.39 MWD RECEIVED JUL 20 2000 Alaska Oil & Gas Cons. Commission 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 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 26-Jun-2000 15:18:23 Page 3 of 6 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 31 2814.00 42.05 74.97 94.00 2643.76 682.04 28.53 708.19 708.77 87.69 2.51 32 2910.00 44.79 73.10 96.00 2713.49 747.97 46.70 771.61 773.02 86.54 3.15 33 3005.00 47.39 72.92 95.00 2779.37 816.39 66.70 837.06 839.71 85.44 2.74 34 3100.00 50.84 73.58 95.00 2841.54 888.18 87.38 905.83 910.03 84.49 3.67 35 3196.00 53.83 74.66 96.00 2900.19 964.11 108.16 978.91 984.87 83.70 3.24 36 3290.00 56.92 74.18 94.00 2953.60 1041.38 128.94 1053.41 37 3385.00 60.16 74.32 95.00 3003.17 1122.33 150.93 1131.39 38 3481.00 63.75 74.38 96.00 3048.30 1206.97 173.78 1212.97 39 3528.00 64.31 75.00 47.00 3068.88 1249.18 184.94 1253.72 40 3685.00 66.62 75.53 157.00 3134.07 1391.74 221.26 .1391.84 41 3780.01 66.50 74.83 95.01 3171.87 1478.77 243.55 1476.11 42 3875.00 66.00 72.51 94.99 3210.13 1565.67 267.99 1559.54 43 3969.00 66.69 72.98 94.00 3247.84 1651.76 293.53 1641.77 44 4065.00 67.13 72.72 96.00 3285.49 1740.06 319.57 1726.15 45 4160.00 67.00 71.90 95.00 3322.51 1827.54 346.16 1809.50 46 4254.00 66.54 72.05 94.00 3359.59 1913.92 372.88 1891.64 47 4351.00 68.10 71.61 97.00 3396.99 2003.42 400.80 1976.67 48 4447.00 67.99 71.48 96.00 3432.88 2092.45 428.98 2061.13 49 4541.00 67.84 71.30 94.00 3468.22 2179.55 456.78 2143.68 50 4636.00 68.08 71.10 95.00 3503.87 2267.60 485.16 2227.04 51 4731.00 68.69 71.36 95.00 3538.87 2355.92 513.57 2310.66 52 4826.00 68.64 70.88 95.00 3573.43 2444.40 542.21 2394.39 53 4920.00 68.30 71.80 94.00 3607.93 2531.83 570.18 2477.23 54 5017.00 68.38 71.78 97.00 3643.73 2621.98 598.36 2562.87 55 5113.00 67.50 72.57 96.00 3679.79 2710.95 625.59 2647.57 56 5208.00 67.99 72.74 95.00 3715.77 2798.87 651.81 2731.49 57 5303.00 68.30 73.04 95.00 3751.13 2887.03 677.75 2815.76 58 5397.00 66.87 73.64 94.00 3786.97 2973.90 702.66 -2899.01 59 5492.00 66.85 72.59 95.00 3824.31 3061.23 728.03 2982.60 60 5586.00 66.69 72.60 94.00 3861.38 3147.61 753.87 3065.02 [(c)2000 Anadrill IDEAL ID6 0C 07] Srvy tool type MWD MWD MWD MWD MWD 1061.27 83.02 3.31 MWD 1141.42 82.40 3.41 MWD 1225.35 81.85 3.74 MWD 1267.29 81.61 1.68 MWD 1409.32 80.97 1.50 MWD 1496.07 80.63 0.69 MWD 1582.40 80.25 2.30 MWD 1667.80 79.86 0.87 MWD 1755.48 79.51 0.52 MWD 1842.31 79.17 0.81 MWD 1928.04 78.85 0.51 MWD 2016.90 78.54 1.66 MWD 2105.30 78.24 0.17 MWD 2191.81 77.97 0.24 MWD 2279.27 77.71 0.32 MWD 2367.05 77.47 0.69 MWD 2455.02 77.24 0.47 MWD 2542.01 77.04 0.98 MWD 2631.79 76.86 0.08 MWD 2720.48 76.71 1.19 MWD 2808.19 76.58 0.54 MWD 2896.18 76.47 0.44 MWD 2982.95 76.38 1.63 MWD 3070.17 76.28 1.02 MWD 3156.37 76.18 0.17 MWD RECEIVED JUL 2 0 2000 Alaska Oil & Gas Cons. Commissior, 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 Seq Measured Incl Azimuth Course $ depth angle angle length - (ft) (deg) (deg) (ft) 26-Jun-2000 15:18:23 Page 4 of 6 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 61 5682.00 66.41 72.40 96.00 3899.59 3235.67 780.35 3149.02 62 5777.00 66.55 72.44 95.00 3937.50 3322.78 806.66 3232.06 63 5872.00 66.10 72.45 95.00 3975.65 3409.78 832.91 3315.01 64 5967.00 66.33 72.23 95.00 4013.96 3496.70 859.28 3397.85 65 6064.02 66.56 71.98 97.02 4052.73 3585.64 886.61 3482.48 66 6159.79 66.54 71.70 95.77 4090.84 3673.50 913.99 3565.96 67 '6254.00 66.56 71.55 94.21 4128.33 3759.93 941.23 3647.98 68 6349.00 66.17 71.53 95.00 4166.42 3846.96 968.79 3730.54 69 6445.00 65.44 71.33 96.00 4205.76 3934.52 996.68 3813.54 70 6540.00 65.12 71.45 95.00 4245.49 4020.81 1024.22 3895.33 71 6636.00 65.13 70.62 96.00 72 6731.00 66.50 71.09 95.00 73 6826.00 67.57 71.68 95.00 74 6921.00 67.63' 70.48 95.00 75 7016.00 67.60 71.52 95.00 4285.87 4324.79 4361.86 4398.06 4434.24 76 7111.00 68.22 71.21 95.00 4469.97 77 7206.00 68.75 71.16 95.00 4504.81 78 7300.00 68.46 72.47 94.00 4539.10 79 7491.00 69.23 73.13 191.00 4608.03 80 7587.00 67.38 73.29 96.00 4643.52 4107.89 1052.52 3977.69 4194.54 1080.94 4059.56 4282.00 1108.86 4142.45 4369.'82 1137.34 4225.54 4457.65 1165.94 4308.59 4545.67 1194.06 4392.00 4634.05 1222.57 4475.66 4721.57 1249.88 4558.81 4899.67 1302.55 4728.97 4988.84 1328.32 4814.36 81 7680.00 68.03 73.99 93.00 4678.80 5074.85 1352.56 4896.92 82 7776.00 66.72 73.82 96.00 4715.73 5163.41 1377.12 4982.06 83 7871.00 67.00 73.71 95.00 4753.06 5250.72 1401.54 5065.93 84 7967.00 67.29 73.50 96.00 4790.35' 5339.14 1426.51 5150.80 85 8062.00 67.53 73.06 95.00 4826.84 5426.83 1451.75 5234.80 Srvy tool type 3244.27 76.08 0.35 MWD 3331.20 75.99 '0.15 MWD 3418.04 75.90 0.47 MWD 3504.81 75.81 0.32 MWD 3593.57 75.72 0.33 MWD 86 8157.00 67.72' 72.68 95.00 4863.01 5514.66 1477.62 87 8252.00 67.72 72.17 95.00 4899.02 5602.57 1504.17 88 8347.00 67.91 71.62 95.00 4934.90 5690.53 1531.50 89 8445.00 68.30. 71.68 98.00 4971.44 5781.46. 1560.13 90 8539.00 67.17 71.46 94.00 5007.06 5868.45 1587.63 3681.23 75.62 0.27 MWD 3767.45 75.53 0.15 MWD 3854.28 75.44 0.41 MWD 3941.64 75.35 0.78 MWD 4027.73 75.27 0.36 MWD [(c)2000 Anadrill IDEAL ID6 0C 07] 4114.59 75.18 0.78 MWD 4201.01 75.09 1.51 MWD 4288.30 75.01 1.26 MWD 4375.92 74.94 1.17 MWD 4463.56 74.86 1.01 MWD 4551.43 74.79 0.72 MWD 4639.63 74.72 0.56 MWD 4727.04 74.67 1.33 MWD 4905.08 74.60 0.52 MWD 4994.25 74.58 1.93 MWD 5318.75 5402.56 5486.17 5572.48 5655.00 5080.28 74.56 0.99 MWD 5168.89 74.55 1.37 MWD 5256.24 74-.54 0.31 MWD 5344.69 74.52 0.36 MWD 5432.38 74.50 0.50 MWD 5520.19 74.47 0.42 MWD 5608.04 74.44 0.50 MWD 5695.92 74.40 0.57 MWD 5786.75 74.36 0.40 MWD 5873.64 74.32 1.22 MWD RECEIVED JUL 0 200 Alaska Oil & Gas Cons. Commission Anchorage 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 26-Jun-2000 15:18:23 Page 5 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 91 8633.00 67.30 70.78 94.00 5043.43 5955.12 1615.68 5737.02 92 8727.00 67.08 70.48 94.00 5079.87 6041.75 1644.42 5818.76 93 8823.00 67.09 70.31 96.00 5117.25 6130.14 1674.09 5902.06 94 8918.50 66.79 69.73 95.50 5154.66 6217.96 1704.11 5984.64 95 9012.00 65.61 70.62 93.50 5192.39 6303.47 1733.13 6065.11 96 9109.00 65.36 71.92 97.00 5232.64 6391.72 1761.47 6148.69 97 9204.92 66.30 71.65 9'5.92 5271.91 6479.23 1788.82 6231.82 98 9300.00 66.45 71.92 95.08 5310.02 6566.34 1816.05 6314.56 99 9395.00 66.83 71.37 95.00 5347.68 6653.55 1843.51 6397.34 100 9491.00 67.40 72.05 96.00 5385.02 6741.99 1871.-27 6481.31 101 9585;00 67.66 71.74 94.00 5420.94 102. 9680.00 67.63 70.60 95.00 5457.08 103 9775.00 68.15 70.35 95.00 5492.83 104 9871.00 67.90 71.44 96.00 5528.76 105 9967.00 68.27 70.84 96.00 5564.59 106 10063.00 67.06 71.76 107 10159.00 67.39 70.72 108 10253.00 65.88 71.88 109 10349.00 66.26 71.71 110 10443.00 66.07 70.89 111 10538.00 66.19 70.58 112 10630.00 66.16 71.06 113 10728.00 66.47 69.53 114 10823.00 66.44 69.29 115 10917.00 66.58 71.39 116 11015.00 67.02 71.37 117 11108.00 67.37 70.83 118 11205.00 67.85 70.98 119 11300.00 67.03 72.45 120 11395.00 67.46 71.96 6828.85 1898.26 6563.88 6916.70 1926.62 6647.03 7004.69 1956.04 6729.98 709_3.70 1985.17 6814.10 7182.75 2013.96 6898.38 96.00 5601.07 7271.54 2042.44 6982.49 96.00 5638.23 7360.05 2070.90 7066.30 94.00 5675.51 7446.33 2098.57 7148.03 96.00 5714.45 7534.08 2125.99 7231.39 94.00 5752.44 7620.06 2153.55 7312.83 95.00 5790.88 7706.91 2182.22 7394.84 92.00- 5828.05 7791.06 2209.87 7474.33 98.00 5867.42 7880.76 2240.13 7558.81' 95.00 5905.36 7967.77 2270.75 7640.34 94.00 5942.84 8053.94 2299.76 7721.52 [(C)2000 Anadrill IDEAL ID6 0C 07] 5981.44 6017.49 6054.44 6090.88 6127.63 98.00 93.00 97.00 95.00 95.00 8144.01 2328.52 7806.88 8229.74 2356.28 7887.99 8319.41 2385.62 7972.74 8407.13 2413.15 8056.04 8494.74 2439.93 8139.45 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) I00f) type type 5960.18 74.27 0.68 6046.66 74.22 0.38 6134.89 74.16 0.16 6222.53 74.11 0.64 6307.88 74.05 1.53 6396.03 74.01 1.25 6483.47 73.98 1.01 6570.52 73.95 0.30 6657.66 73.92 0.67 6746.04 73.90 0.88 6832.85 73.87 0.41 6920.61 73.84 1.11 7008.48 73.79 0.60 7097.39 73.76 1.08 7186.36 73.72 0.70 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 7275.08 73.70 1.54 MWD 7363.51 73.67 1.06 MWD 7449.72 73.64 1.97 MWD 7537.43 73.62 0.43 MWD 7623.34 73.59 0.82 MWD 7710.11 73.56 0.32 7794.17 73.53 0.48 7883.77 73.49 1.46 7970.64 73.45 0.23 8056.72 73.41 2.05 8146.74 73.39 0.45 8232.40 73.37 0.65 8322.01 73.34 0.52 8409.70 73.32 1.67 Rtc JUL Alaska 0ii & Gas Cons. commission hnChoTage MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 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 26-Jun-2000 15:18:23 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool % depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 121 11491.00 67.25 71.33 96.00 6164.59 8583.34 2467.82 8223.54 8585.85 73.30 0.64 MWD 6-axis 122 11586.00 65.88 74.18 95.00 6202.38 8670.48 2493.67 8306.77 8672.99 73.29 3.11 MWD 6-axis 123 11681.00 65.72 74.02 95.00 6241.32 8757.06 2517.41 8390.11' 8759.64 73.30 0.23 MWD 6-axis 124 11776.00 65.67 73.00 95.00 6280.43 8843.61 2541.99 8473.12 8846.21 73.30 0.98 MWD 6-axis 125 11870.00 66.00 73.97 94.00 '6318.91 8929.34 2566.36 8555.35 8931.98 73.30 1.00 MWD 6-axis 126 11967.00 66.04 74.20 97.00 6358.33 9017.90 2590.67 8640.58 9020.59 73.31 0.22 MWD 6-axis 127 12061.00 66.23 73.24 94.00 6396.36 9103.82 2614.76 8723.09 9106.55 73.31 0.96 MWD 6-axis 128 12156.00 66.84 73.59 95.00 6434.19 9190.93 2639.64 8806.61 9193.70 73.31 0.73 MWD 6-axis 129 12252.00 66.74 72.97 96.00 6472.02 9279.14 2665.02 8891.11 9281.93 73.31 0.60 MWD 6-axis 130 12346.00 64.80 71.18 94.00 6510.60 9364.85 2691.39 8972.66 9367.62 73.30 2.70 MWD 6-axis 131 12440.00 64.82 71.38 94.00 6550.61 9449.90 2718.69 9053.22 9452.63 73.28 0.19 MWD 6-axis 132 12536.00 64.75 72.10 96.00 6591.51 9536.75 2745.90 9135.70 9539.45 73.27 0.68 MWD 6-axis 133 12632.00 64.64 70.98 96.00 6632.54 9623.54 2773.38 9218.02 9626.19 73.26 1.06 MWD 6-axis 134 12725;00 64.54 71.13 93.00 6672.45 9707.53 2800.66 9297.48 9710.13 73.24 0.18 MWD 6-axis 135 12821.00 64.23 71.53 96.00 6713.95 9794.09 2828.37 9379.49 9796.65 73.22 0.50 MWD 6-axis 136 12915.00 64.09 71.41 94.00 6754.92 9878.69 2855.25 9459.70 9881.22 73.20 0.19 MWD 6-axis 137 13011.00 63.87 72.22 96.00 6797.04 9964.96 2882.18 9541.66 9967.46 73.19 0.79 MWD 6-axis 138 13106.00 64.21 71.24 95.00 6838.62 10050.37' 2908.95 9622.77 10052.84 73.18 0.99 MWD 6-axis 139 13200.02 64.89 72.37 94.02 6879.03 10135.27 2935.46 9703.42 10137.71 73.17 1.30 MWD 6-axis 140 13234.00 65.06 71.46 33.98 6893.40 10166.06 2945.02 9732.69 10168.50 73.16 2.48 MWD 6-axis Projected to TD 141 13308.00 65.06 71.46 74.00 6924.60 10233.16 2966.35 9796.30 10235.57 73.15 0.00 Projected [(c)2000 Anadrill IDEAL ID6 0C 07] JUL A/aska Oil & Gas Cons. Commission Anchorage Scklumberg.er Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 442 Company: Alaska Oil & Gas Cons Corem Attn: I. ori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-06 20345 GR/CDR/ADN/IMP ~ C~ ~{~ 000709 1 CD1-06 20345 MD CDR 000709 1 1 CD1-06 20345 TVD CDR 000709 1 1 . . ,,, RE'. A]ask. Oil & G~s Cons. t;ommission ThaAnchorage nsmlttal to Sherrle at the above address or fax tO (907) 561-8317, nK yOU, 8/23/00 8~7~OO Scklumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 'Anchorage, AK 99503-5711 ATTN: Sherrie NO. 398 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 ~ CDI-~ 20267 CDR/IMP/ADN/GR "~_,_, - ~(o ~'~ r-~. 000520 1 CD1-44' 20267 MD CD~MP/ADN/GR 000520 I 1 CD1-44 20267 TVD CD~MP/ADWGR 000520 I 1 CDI-~ ~1 ~ 20311 'USIT 000704 1 : ~r'~l~l,~ sIGNE DATE: AUG 1 8 2000 Alaska 0ii & Gas Cons. uommissJ0rl Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~Cuh.°rage. 8/10/00 Scklumbe Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK. 99503-5711 ATTN: Sherrie NO. 411 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job it Log Description Date BL Sepia Prints CD CD1-06 PB1 20316 CDPJADNIGR -~-.. ¢.~) 000623 1 cm-o~,m =o=~ .=co. ooo~== ~ CD1-06 PB1 20316 TVD CDR 000623 I 1 CD1-06 PB1 20316 MD ADN 000623 I 1 CD1-06 PB1 20316 TVD ADN 000623 I 1 . L AUG 1 8 2000 SIGNE DATE: e) ~aska 0ii & Gas Cons. builimissi0n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax tO (907) 561-8317, Thank you, ( MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-06 ~, O'O · ~'~ Date Dispatche 28-Jul-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECEIVE[ AL G 10 Alaska 0il ~ Gas Cons. (;om! Ancb0r~o ... Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 roseJJanchorage.anadrill.sib.com Fax: 907-561-8417 LWD Log Delivery Vl. 1, Dec '97 MWDILWD Log Product Delivery Customer Arco Alaska, Inc. ~.~' O~;1~ Dispatched To: AOGCC Well No CD1-06PH/CD1-06 Date Dispatche 16-Jul-00 Installation/Rig Doyen 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Pdnts No of Floppies No of Tapes Surveys (Paper) 2 ECEI ED ,JUL 2 0 ~1 O0 Naska )il & Gas Cons. ~ommission Anchorage ..... Received By: - ~' - I Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rose@anchorage.anadrill.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 (' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor DATE: July 10, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. CD1 CD1-06 FROM: Jeff Jones ~~.?J--~ Colville River Unit/Alpine Field Petroleum ~ns'p~for NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. CD1-06 I Typelnj. I G I T.V.D. I 6622' ITubingl ~S00I2~soI=1~oI=~o I lnterva,l I 200-083 mypetestI P I mestpsil 3500 ICasingI 150 I 3600 I 3550-I 3550 I P/F I E Type INJ. Fluid Codes F = FRESH WATER INJ. G '- GAS INJ. S = SALT WATER INJ. N = NOT INJECTING' '. Type Test M-- Annulus Monitoring P= Standard Pressure Test R= Intemal Radioactive Tracer Survey A= Temperature Anomaly Survey D=' Differential Temperature Test Interval '1= Initial Test 4= .Four Year Cycle V= Required by Variance W-- Test during Workover O= Other (describe in notes) Test's Details Monday July 10, 2000: I traveled to Phillips Alaska Iuc.'s Alpine field to witness an initial mechanical integrity test on well CD1-06. Scott Reynolds,' the operator representative, and I disCUSsed testing procedures while Doyon Drilling Inc. personnel rigged up to perform the test. The pretest casing and tubing pressures were allowed to stabilize for 30 minutes with no significant changes recorded. The standard annulus pressure test was then performed without failure. The test data recorded above indicates well CD1-06 is suitable for the proposed.gas injection. Summary.: I witnessed a successful MIT on Phillips Alaska Inc.'s Alpine gas injection well CD1'06. M.I.T.'s performed: Attatchments: Number of Failures: Total Time during.tests: 2hrs. Cc: MIT report form 5/12100 L.G. MIT CRU CD1-06 7-10-00 JJ1 .xls 8/7/00 APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _X Pull tubing _ Variance .~ Perforate _ 2. Name of Operator )hillips Alaska, Inc. 3. Address P. O. Box 100360 ~Anchorage, AK 99510-0360 4. Location of well at surface 258' FNL, 2538' FWL, Sec.5, T11 N, R5E, UM At target (Top Alpine)) 2184' FSL, 1903' FWL, Sec.34, T12N, R5E, UM =At effective depth At total depth 675' FNL, 1869' FEL, Sec.3, Tll N, R5E, UM 12. Present well condition summary Total depth: Effective depth: Casing Conductor 5. Type of Well: Development __ Exploratory _ Stratigraphic m Service _X_ Surface Production Other _ Annular Injection per APD per APD measured 13510 feet true vertical 6838 feet measured 13510 feet true vertical 6838 feet Length Size Cemented 77' 16" 10 ou.yds, Portland Type 3 3541' 9.625" 425 sx ASL3, 496 sx Class G 13466' 7" 263 sx Class G 6. Datum elevation (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-06 9. Permit number / approval number 200-083 10. APl number 50-103-20341-00 11. Field / Pool Colville River Field/Alpine Oil Pool ORIGINAL Measured Depth Trueverflcal Depth 114 114 3577' 3090' 13500' 6838' Per the attached letter, it is requested that the packer be set at 12600' (+/- 1 tubing joint). This is 668' MD above the top of the Alpine sand. This will allow the completion to wireline accessible. The CQL indicates good cement quality / bond above and below the proposed packer depth. The top of cement fi'om the CQL has been picked at 12420' MD. RECEIVED. The 7" casing has just been drilled out. Approximately 3200' of horizontal section will be drilled prior to running the completion. 13, Attachments Description summary of proposal_ Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation J15. Status of well classification as: I J Oil _ Gas ~ Suspended_ JService X July 8, 2000 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify th · foregoing is true and correct to the best of my knowledge. Signed /~~ ~/(C~ Title: Dril!ing Team Leader ' ~ FOR COMMISSION USE ONLY Conditions of appr~:Notify Commission so representative may witness Plug integrity m BOP Test _ Mechanical Integrity Test~J~ ,..)RIGINAL SIGNED BY Approved by order of the Commission D Taylor Seamount Form 10-403 Rev 06/15/88 · Location clearance _ Subsequent form required 10- Commissioner ~op~o~eCt ~o~ . Date JAppr°.,~ - I ?~7 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 05, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Change the Well Program: CD1-06~ Permit No. 200-0837 APl No. 50-103-20341 Dear Sirs: Phillips Alaska, Inc. hereby requests approval to place the production packer at 12600' MD (+/- 1 tubing joint) on the subject well. This is 668' above the top Alpine at 13268' MD). Setting the packer at this depth will allow the completion to be accessed by wireline. The inclination at the packer will be 65°. The previously submitted CQL indicates that there is good cement isolation both above and below this packer setting depth. The top of cement from the CQL has been picked at 12420' MD. It is estimated that completion operations will commence during the coming weekend (8 - 9 July 2000). If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Rob~rt~~n '~~ Senior Drilling Engineer CC. CD1-06 Well File Sharon AIIsup-Drake Doug Chester Mike Erwin Gracie Stefanescu ATO- 1054 ANO-382 ANO-383 Anadarko RECEIVED JUL 0 6 ~.000 Alaska 0il & Gas Coas. C0mm'~,i0n ALASKA OIL AND GAS CONSERVATION COPLSIISSION TONY KNOWLE$, GOVERNOR 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 1-06 ARCO Alaska, Inc. Permit No: 200-083 Sur Loc: 258'FNL, 2538'FWL, Sec. 5, T1 IN, R5E, UM Btmhole Loc. 675'FNL, 1869'FEL, Sec. 3, T11N, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. 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 Drill Site 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. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD 1-06PH) and APl number (50-103-20341-70) from records, data and logs acquired for well CD 1-06. Your request for a variance from the requirements of 20 AAC 25.412(b) to set the packer at a different depth will not be considered until a~er the CQL has been provided to the Commission for review. If the Commission is satisfied that the CQL confirms isolation above the Alpine Sand, it may approve a different packer setting depth. Mr. Doug Chester t: 2 ( June 9, 2000 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. 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 prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this t~t~ day of June, 2000 dlf/Enclosures Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 200-083-CD106pkr.txt Subject: CD1-06 (Proposed PTD 200-083) Date: Wed, 07 Jun 2000 16:10:34 -0800 From: Tom Maunder <tom maunder@admin.state.ak.us> To: Brian Robertson <brobert4@ppco.com> CC: Blair Wondzell <blair wondzell@admin.state.ak.us> Brian, Thanks for getting back to us with your proposal. We do understand th e rationale regarding the request to set the packer and associated jewel ry shallower than the regulations proscribe. We also appreciate your addressing the necessity of isolation and your proposal to determine that isolation is present above the proposed packer setting depth prio r to running the completion. Based on your message and our discussions I understand your plan to be as follows: ...pump sufficient cement to place the top of cement some 900' to 1000 md above the top of the Alpine sand ...run a cement quality log (CQL) before running the completion to determine effective isolation ...after assessing the cement quality and TOC, propose a packer settin g depth consistent with the determined quality information Provided adequate isolation is evidenced by the CQL, you are free to propose setting the packer at a shallower depth than proscribed by the regulations. When the CQL is available, please contact us so we may view the log. Again, thanks for your efforts on this matter. or Blair with any questions. Please contact myself Tom Maunder Petroleum Engineer AOGCC Subject: CD1-06 Packer Setting Depth Date: Mon, 5 Jun 2000 15:25:11 -0900 From: "Brian Robertson" <BROBERT4@ppco. com> To: tom_maunder@admin, state, ak. us Page 1 200-083-CD106pkr.txt CC: "Douglas K Chester" <DCHESTER@ppco.com>, Blair wondzell@admin.state.ak.us Tom, Further to our conversation this morning, there follows some thoughts / proposals regarding the packer setting depth on the CD1-06 well. Doug and I would be happy to come over and discuss this with you and Blair - at your convenience. Please let me know a suitable time. Brian ....... Attached is the blown up schematic for the proposed CD1-06 gas injecti on well completion. This plan recommends setting the packer at +/- 12500' MD. This is some 716' above the top of Alpine. An exception from the standard 200' MD maximum distance between the packer setting depth and Top Alpine has been requested in the APD. To compensate for this 'high packer setting depth, it is intended the top of cement be raised to so me 916' MD above the Alpine (as opposed to the standard 500' MD). This will allow for cement isolation some 200' MD above the packer. This will also provide addition back up to t he increased amount of casing exposed to injection fluids underneath the packer. The rationale behind choosing this packer setting depth was as follows: 1. Wellbore geometry : to maintain the completion within 'wirelineable limits the XN nipple needs to be at a maximum inclination of around 67 deg. We have had some success at getting wireline and USIT logs to around 70+ deg. However this has been in lower step out wells. 2. The setting depth shown below, also allows for some 240' MD from th e end of tubing to 68 deg inclination at 12800' MD. This is the distance ove r which a SCMT (cement evaluation log) could realistically be run post-completio n. Note, if the cement evaluation log was run pre-completion this distanc e Page 2 200-083-CD106pkr.txt would not all be required and the packer could be set +/- 200' deeper. 3. Setting the packer within 200' of the top Alpine is undesirable fro m a future completion perspective. Future well work operations would have to be conducted using coiled tubing as opposed to slickline. (Embedded image moved to file: pic26527.pcx) Proposal: Running the USIT log on electric line, pre-completion should allow the cement quality to be determined to a depth very close to the top of th e Alpine (78 deg inclination). Based on this information (and on the rea 1 wellbore surveys) we could then choose the optimal packer setting dept h for the well. Some guidance from the AOGCC will be necessary to determine if it is still permissible to run a 'wirelineable' completio n or if it will be necessary to set the packer within 200' of the Alpine Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder Petroleum Engineer .us> Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage AK 99501 USA Additional Information: Last Name Maunder First Name Tom Version 2.1 <tom maunder@admin.state.ak Fax: 907 276-7542 Work: 907 793-1250 Conference Software Address Page 3 CD1-06 Packer Setting Depth Subject: CDI-06 Packer Setting Depth Date: Mon, 5 Jun 2000 15:25:11 -0900 From: "Brian Robertson" <BROBERT4@ppco.com> To: tom_maunder@admin.state.ak, us CC: "Douglas K Chester" <DCHESTER@ppco.com>, Blair_wondzell@admin.state.ak. us Tom, Further to our conversation this morning, there follows some thoughts / proposals regarding the packer setting depth on the CD1-06 well. Doug and I would be happy to come over and discuss this with you and Blair- at your convenience. Please let me know a suitable time. Brian ....... Attached is the blown up schematic for the proposed CD1-06 gas injection well completion. This plan recommends setting the packer at +/- 12500' IRE). This is some 716' above the top of Alpine. An exception from the standard 200' MD maximum distance between the packer setting depth and Top Alpine has been requested in the APD. To compensate for this 'high' packer setting depth, it is intended the top of cement be raised to some 916' MD above the Alpine (as opposed to the standard 500' MD). This will allow for cement isolation some 200' MD above the packer. This will also provide addition back up to the increased amount of casing exposed to injection fluids undereath the packer. The rationale behind choosing this packer setting depth was as follows: 1. Wellbore geometry: to maintain the completion within 'wirelineable' limits the XN nipple needs to be at a maximum indination of around 67 deg. We have had some success at getting wireline and USIT logs to around 70+ deg. However this has been in lower step out wells. 2. The setting depth shown below, also allows for some 240' MD from the end of tubing to 68 deg inclination at 12800' MD. This is the distance over which a SCMT (cement evaluation log) could realistically be run post-completion. Note, if the cement evaluation log was run pre-completion this distance would not all be required and the packer could be set +/- 200' deeper. 3. Setting the packer within 200' of the top Alpine is undesireable from a future completion perspective. Future well work operations would have to be conducted using coiled tubing as opposed to slickline. (Embedded image moved to fie: pic26527.pcx) Proposal Running the USIT log on electric line, pre-completion should allow the cement quality to be determined to a depth veryclose to the top of the Alpine (78 deg inclination). Based on this information (and on the real wellbore surveys) we could then choose the optimal packer setting depth for the well. Some guidance from the AOGCC will be necessary to determine if it is still permissable to run a 'wirelineable' completion or if it will be necessary to set the packer within 200' of the Alpine, ~pic26527.pcx Type: PCX Image Document (application/x-unknown-content-type-PCXImage. Document) .... Encoding: base64 1 of 1 6/7/00 10:01 AM Colville River Field -06 Completion Plan -Gas Injector TOC est. {~ +/-12300' MD 16506' TVD 167 deg = +1- 916' MD above top Alpine Baker Model S-3 Packer (3.875" ID) at 12500' MD 16585' TVD 167 deg HES XN Nipple (3.725") at 12545'MD Wireline Entry Guide at 12558' MD / 6608' TVD 167deg 178 deg 7" 26 ppf L-80 BTC Mod Production Casing ~ 13482' MD / 6861' TVD / 87 deg i' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry DeepenI Service X Development Gas Single Zone X Multiple Zone 2/f_.~~[ame of_,Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ,"l'"..~Alaska, Inc. ~ DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559, 25557_ E, 7'Z~5' ,~ 4. Location of well at surface 7. Unit or property Name] 11. Type Bond (see 2O AAC 25.025) 258' FNL, 2538' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 2184' FSL, 1903' FWL, Sec. 34, T12N, R5E, UM CD1-06 #U-630610 At total depth 9. Approximate spud date Amount 675' FNL, 1869' FEL, Sec. 3, T11 N, R5E, UM 06/14/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 05 16,717 MD Crosses T11N to feet 8.7' @ 300' Feet 2560 6,851' TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 450' feet Maximum hole angle 90° Maximum surface 241 8 psig At total depth (TVD) 321 5 at p$ig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~e data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 3504' 37' 37' 3541' 3040' 531 Sx Arcticset III L & 488 Sx Class G 8.5" 7" 26# L-80 BTC-M 13445' 37' 37' 13482' 6861' 196 sx Class G N/A 4.5" 12.6# L-80 I BT-M 12463' 37' 37' 12500' 6585' Tubing (packer depth) 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 ~l'~ ~ ~'% ,..~, ,t~[{''~ I~% Measured depth True Vertical depth Conductor .... Surface Intermediate i~.,^~! 2 0 2000 Production l; ~f-~, i Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission ORIGINAL true vertical Anchorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21.1 hereby certify t~f~ the foregoing is trust of my knowledge Signed Title Drilling Team Leader Date ~j~¢~ ¢;~'( Commission Use Only P e rm~.~e_r~>,..,~ APl 50. n/~e,~ ,~./~,,~[-' ~ I Appr°valdate/~ .... ~)~, ~0 ISeec°verletterf°r - Other requirements Conditions of approval Samples required Yes ~ Mud Icg reqbired Yes Hydrogen sulfide measures Yes ~~Directional survey required /~s-') No Required working pressure for DOPE 2M 3M 5M 10M 15M byorder of Approved by ORIGINAL SIGNED BY commissioner the commission Date ~ Form 10-401 Rev. 7-24-89 L~ Taylor Seamount t in triplicate Alpine: CD1-06PH (Pilot Hole) & CD1-06 Procedure . . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 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 DOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole, Perform leak off test. Drill 8 Y2" ho!e.to...a._!3._o.!...n.t....+.../z..!,.00,.,T.v .D..be..!..o...w the base of the Alpine Sand. Set 500 ft cement plug #1 from TD to +/- 12938'. Set 500 ft cement~lug #2 from +/- 12938' to +/- 12438'. RIH with drilling assembly, Dress off plug #2. Kick off at +/- 12596' and drill sidetrack to intermediate casing point in the Alpine Reservoir, Run and cement 7 inch casing as per program. Top of cement +/- 900 feet MD above Alpine reservoir, 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. DOPE test to 3500 psi. Run a clean out assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Displace the well to 9.2 ppg FID-Pro drill-in fluid. POH. Run the 6 1/8" drilling assembly and drill the horizontal section to well TD. Contingency- set open hole isolation equipment 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 Y2, 12.6 #, L-80 tubing with SSSV nipple and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi, Remove 2 way check. Circulate the tubing to diesel and install freeze protection in the annulus. Install the lubricator and drop the ball to set the packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Set BPV and secure well. Move rig off. 2 6 2000 Alaska 0i~ & Gas Cons. Commission ,.And'~or~e Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-05 will be the closest well to CD1-06 (8.7' at 300' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.1' at 300' MD. Drillin.q Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations on well CD1-06 will be injected into the annulus of another permitted well on the CD1 pad. The CD1-06 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-06 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3040') + 1,500 psi = 3,397 psi Pore Pressure = 1,375 psi Therefore Differential = 3397 - 1375 = 2022 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 CD1-06 & CD1-06 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 1/2" Section - 6 1/8" point- 12 1~,, Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10-25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <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. ,I,ntermediate 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 cimulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with +_ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. Colville River Field CDI-O6PH Pilot Hole- Prior to Sidetracking RKB - GL = 37' Wellhead 16" Conductor to 114' 9,8 ppg drilling mud in hole I Cement Plug 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3541 ' MD / 3040' TVD cemented to surface Top of cement plug dressed off to 12596' MD / 6623' TVD (+/- 67 deg inc,) Top Alpine Reservoir at 13110' MD / 6826' Pilot Hole TD at 13438' MD / 6956' TVD (+/- 67 deg inc,) Top of Cement Plug #1 at +/- 12938' 500 ft Updated 05/23/00 Colville River Field CD1-06 Completion Plan - Gas Injector 16" Conductor @ 114' MD RKB - GL = 37' 4-1/2" Camco BAL-O SSSV Nipple (3,812" ID) at 1700' TVD = 1722' MD Isolation Sleeve with DB-6 No-Go Lock (3,812" OD) run in profile Dual 1/4" x 0,049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3541' MD / 3040' TVD cemented to surface WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3,812" OD) - to be installed later 4-1/2" 12,6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Tubing Suspension Fluid: Diesel to End of Tubing Packer Fluid: 9,6 ppg KCL brine with diesel to 2000' TVD Tubing tail to include: 4-1/2" Tbg Joints (1) HES "XN" (3,725" ID) 4-1/2" 10' Tbg pup Joint and WLEG Note-Baker-lock all components CD1-06PH - cement kick off plug at 12596' MD TOC est. @ +/-12300' MD = +/- 9,___jl_6,'.,,.MD above top Alpine Baker Model S-3 Packer (3,875" ID) at 12500' MD HES XN Nipple (3.725") at 12545'MD Wireline Entry Guide at 12558' MD TD planned at 16717' MD / 6851' TVD Top Alpine at 13216'MD / 6826' TVD 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 13482' MD / 6861' TVD Colville River Field CD1-06 Completion with Isolation Contingency Options 16" Conductor @ 114' MD RKB - GL = 37' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD = 1722' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" sis control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3541' MD / 3040' TVD . cemented to surface Packer Fluid' 9.6 ppg KCL brine with diesel to 2000' TVD Diesel to end of tubing 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-Uod - 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 @ +/-12300' MD (916' MD above Al Tubing tail to include: 4-1/2" Tbg Joints (1) HES "XN" (3.725" ID) 4-1/2" pup jt and WLEG Note-Baker-lock all components Baker Model S-3 Packer (3.875' ID) at +/- 12500' MD (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe ® )i 7" 26 ppf L-80 BTC Mod Production Casing @ 13482' MD / 6861' TVD (90 deg) TD at 16717' MD I 6851' TVD Updated 05/23/00 CD1-06 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well ' Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs,/ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 3541 / 3040 14.5 1375 2020 7" 13482 / 6861 16.0 3104 2418 N/A 16717 / 6851 16.0 3099 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) = 1375 - (0.1 x 3040') = 1071 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1} D = [(14.7 x 0.052) - 0.1] x 3040 = 2020 psi OR ASP = FPP - (0.1 x'D) = 3104 - (0.1 x 6861') = 2418 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3104- (0.1 x 6861') = 2418 psi Alpine CD1-06 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 - 1500 -2500 -3500 P( Pr -4500 -5500 -6500 -7500 II II ii III I I ~.~'~. ~/' ~11 ~E I I ~ssL ~1 II M~E ~rEI~F{T IIII ~/ I I - II III III III II Ill ,*~, 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpine, CD1-06PH & CD1-06 Well Cementing Requirements 9 5/8" Surface Casing run to 3541 MD i 3040' TVD. Cement from 3541' MD to 2400' (1141' fill) with Class G + Adds @ 15.8 PPG, and from 2400' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2400'-1571 ') X 0.3132 ft3/ft X 1.5 (50% excess) = 389.5 ft3 below permafrost 1571' X 0.3132 ft3/ft X 4 (300% excess) = 1968.1 ft~ above permafrost Total volume = 389.5 + 1968.1 = 2357.6 ft~ => 531 Sx @ 4.44 fta/sk System: Tail slurry: 531 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% BWOW1 D044 freeze suppressant 1141' X 0.3132~ ft3/ft X 1.5 ,(50% excess) = 536.0 ft~ annular volume 80' X 0.4341 ft°/ft = 34.7 ft° shoe joint volume Total volume = 536.0 + 34.7 = 570.7 ft~ => 488 Sx @ 1.17 ft3/sk System: 488 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 13482' MD 16861' TVD Cement from 13482' MD to +/- 12300' MD (916' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (13482'- 1230~0') X 0.126~8 ft3/ft X 1.4 (40% excess) = 210.0 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft° shoe joint volume Total volume = 210.0 + 17.2 = 227.2 ft~ => 196 Sx @ 1.16 fta/sk System: 196 Sx Class G + 0.2% D046 antifoamer, 0.27% D065 dispersant, 0.20% D800 retarder, 0.20% D046 anti-foam and 0.25% D156 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk CD1-06PH Cement Plug #1: 13438' MD to 12938' MD = 500'. Cement 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 => 196 Sx @ 1.16 ft3/sk CD1-06PH Cement Plug #2: 12938' MD to 12438' MD = 500'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.0 ft3 => 160 sx @ 1.00 ft3/sk I By Weight Of mix Water, all other additives are BWOCement 500 1000 1.500 2OOO 65OO 7000 RKB Elevation: 55' KOP 1.50 4.50 Bose Permofrost 7.50 lO.50West Sok DLS: 1.50 dog per 100 ft 12.5,3 EOB #1 15.12 1B.22 DLS: 2.00 deg per 100 ft 21.61 25.17 EOB ~2 29.g2 C40 35.80 C50 BLS; 3,00 deg per 100 ft 41,71 47,63 C20 53.57 59.52 EOC - g 5/8 CsgPt PHILLIPS Alaska, Inc. Structure : CD#1 Field : Alpine Field Well: 6PH Location : North Slope, Alaska c~tes by jo,,. For: B Robertaon Oot. pJotted: PlM Ref~,er,~ lB CDt-6 PIll Vemion ~6. CoordTnet# om in feet reference dot ~8. Ting Vwflcpal Dapth. arb refm'efl~.o RKB K-3 K-2 71.91 AZIMUTH oaa ' (To AVERAGE ANGLE 66.69 DEG AJb[on-97 Albion-96 HRZ KOP - Sdrtk Pt Miluveoch A AIp~m K-1 LCU I I I I I I I I I I I I I I I I I I I I I I II I I I I ! I I I I I I I I I I I I I I I i O 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 BOOO 8500 gooo 9500 10000 10500 11000 VeHicol Section (feet) -> Azimuth 71.91 with reference 0.00 $, 0.00 E from slot #6 PHILLIPS Alaska, Inc. Structure: CD#1 Field: Alpine Field Well: 6PH Location: North Slope, Alaska Point KOP West Sok EOB Bose Permofrost EOB #2 C40 C30 C20 EOC - 9 5/8 CsgPt ' K-3 K-2 Albion -97 Albion-96 HRZ K-1 LCU Miluveoch A Alpine D JAIpine Base Alpine TD PROFILE COMMENT DATA MD Inc Dir TVD North East V. Sect 450.00 0.00 120.00 450.00 0.00 0.00 0.00 1048.45 8.98 120.00 1046,00 -25.39 40,52 51.25 1250.00 12.00 120.00 1244,16 -41.74 72.29 55.75 1571.59 16.19 99.65 1556.00 -65.97 145.46 117.78 2200.04 27.00 81.61 2140.28 -59.80 375.95 356.87 2246.02 28.34 80.91 2181.00 -56.55 395.04 357.94 2512.25 36.16 77.82 2406.00 -29.95 534.45 498.71 3010.09 50.90 74.31 2766,00 53.77 865.84 859.73 5540.88 66.69 71.91 3040.14 186.05 1298.60 1292.16 5426.04 66.69 71.91 3786.00 723,71 2944.54 3023.51 6007.37 66.69 71.91 4016.00 889.51 3451.83 3557.40 10569.55 66.69 71.91 5821.00 2190.71 7434.56 7747.30 11416.24 66.69 71.91 6156.00 2452.21 8173.74 8524.92 11921.75 66.69 71.91 6556.00 2576.59 8615.04 8989.18 12540.99 66.69 71.91 6601.00 2753.01 9155.65 9557.89 12781.1 0 66.69 71.91 6696.00 2821.49 9365.25 9778.41 13008.58 66.69 71.91 .6786.00 2886.37 9565.85 9987.33 15071.76 66.69 71.91 6811.00 2904.39 9618.99 10045.36 15109.68 66.69 71.91 6826.00 2915.21 9652.09 10080.18 15190.56 66.69 71.91 6858.00 2938.27 9722.70 10154.46 15438.25 66.69 71.91 6956.00 5008.92 9938.94 10381.94 Deg/'~q,O 0.00 1.50 1.50 2.00 2.00 3.00 3.00 3.00 3.00 0.00 P-~O 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PHILLIPS Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : 6 Location : North Slope, Alaska 5200- 540O ~-~ 5600 ~.~ 5800 q) 6000 6200 6400 I--- 6600 I V 6800 7000 7200 , ! ! ! ! ! ! ! ! 1200 1400 1600 1800 2000 TANGENT ANGLE 90.37 DEG 151.99 AZIMUTH s7 a' % 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 2200 2400 2600 2800 5000 3200' 3400 3600 ;~800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 Vertical Section (feet) -> Azimuth 151.99 with referenoe 0.00 N, 0.00 Ir from slot#6 For: B Robert. son Date plotted: 17-UOy-ZO00 ~d~t~ arb in f~t ref~ s~ ~L PHILLIPS Alaska, Inc. Structure: CD#1 Field: Alpine Fleld Well: 6 Location: North Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 KOP - Sdrtk Pt 12596.32 66.69 71.91 6622.94 2768.75 9205.95 1878.63 0.00 LCU 12785.02 68.10 90.25 6696.00 2795.47 9375.09 1935.43 9.00 Miluveoch A 13054.38 73.43 115,34 6786.00 2738.85 9620.39 2100.64 9.00 Alpine D Alpine 13149.15 13215.99 76.03 123.76 6811.00 2693.77 9699.82 2177.74 9.00 78.05 129.57 6826.00 2654.88 9752.05 2236.59 9.,~0 Tgt/CsgPt - EOC 13481.91 87.00 151.98 6861.00 2451.83 9917.07 2493.56 9.00 End Build/Turn 13814.05 90.32 151.99 6868.74 2158.73 10073.01 2825.57 1.00 Tgt/IntermdPt 15182.15 90.32 151.99 6861.00 950.94 10715.57 4193.44 0.00 End Build/Turn 15191.02 90.37 152.06 6860.95 943.11 10719.73 4202.31 1.00 TD 16717.21 90.57 152.06 6851,00 -405.15 11434.80 5728,46 0,00 INTEQ PHILLIPS Alaska, Inc. Struoture: CD#1 Field : Alpine Field Well : 6 Location : Norfh Slope, Alaska 48OO 42O0 56OO A 2400 I 1200 0 Z 600 600 1200 1800 6~ East (feet) -> 600 0 600 1200 1800 2400 $000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 I I ~ I I I I I Ii i t II I I II I I I I I I II II II II II II II II II II SURFACE LOCATION: 258' FNL, 2538' FWL SEC. 5, T11N, R5E ~ [ CD1-6PH1 TD LOCATION: 2559' FNL, 1927' FWL 4-0.0. ~. ~. SEC. 54, T12N, R5E ~,~v-~y~r ~ End Build/Turn CD1-6 TGT - CSC PT LOCATION: 2184' FSL, 1905' FWL SEC. 54, T12N, RSE End Bu~ld/'rurr torm¢lPt ! CD1-6 TD LOCATION: 675' FNL, 1869' FEL SEC. 5, 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 0 600 t200 1800 2400 $000 5600 4200 4800 5400 6000 $800 7200 7800 8400 0000 9600 10200 10800 11400 12000 12600 Eosf (feet) -> 4800 4200 3600 3000 2400 h I Z 1800 0 1200 ~_. 1200 1800 PHILLIPS Alaska, Inc. CD%i 6 slot %6 Alpine Field North Slope, Alaska SUMM'ARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-6 Version #6 Our ref : prop3952 License : Date printed : 16-May-2000 Date created : 14-Apr-2000 Last revised : 16-May-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.572,w150 55 31.879 Slot Grid coordinates are N 5975869.883, E 385964.835 Slot local coordinates are 256.61 S 2538.57 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath CD1-4 Version #10,,4,CD#1 CD1-9 Version 96,,9,CD#1 CD1-9 PH1 Version 96,,gPH,CD%1 PMSS <297 - 9882'>,,44PHl,CD%l PMSS <9081 - ???'>,,44,CD%1 PMSS <476 - 11190'>,,34,CD%1 PMSS <7182 - 11170'>,,41,CD91 PMSS <475 - 8166'>,,41PH1,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <654 - 10956'>,,38PBl,CD%1 PMSS <9876 - 12240'>,,38,CD91 PMSS <0-10504'>,,5PH1,CD%1 PMSS <9499 - 14515'>,,5,CD91 PMSS <0-10897'>,,3,CD91 PMSS <0-11608'>,,42,CD91 PMSS <472 - 1545'>,,36PH1,CD%1 PMSS <6600 - 10654'>,,36,CD~1 PMSS <0-11067'>,,32PH1,CD%1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-9357'>,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD%1 PMSS <0-8350'>,,26PH1,CD#1 PMSS <7755-11134'>,,26,CD%1 PMSS <0-10224'>,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-11300'>,,13,CD%1 PMSS <0-7331'>,,1PH1,CD%l PMSS <5946 - 10289'>,,1,CD%1 PMSS <0-12055'>,,40,CD91 PMSS <0-8168'>,,35,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <0-10548'>,,19,CD%1 PMSS <2827 - 11956'>,,19A,CD%1 PGMS <0-10255'>,,WD2,CD#1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance 10-May-2000 16-May-2000 2-May-2000 14-May-2000 15-May-2000 11-May-2000 3-Apr-2000 26-Mar-2000 15-Mar-2000 16-Mar-2000 13-Feb-2000 14-Feb-2000 23-Jan-2000 23-Jan-2000 4-Jan-2000 23-Dec-1999 4-Jan-2000 22-Dec-1999 4-Jan-2000 23-Dec-1999 4-Jan-2000 19 7 643 2 30 3 380 4 380 4 280 2 350 0 350 0 189 8 210 2 319 9 319 9 8 7 8 7 29 6 360 3 300 4 300 4 259 9 259 9 390 2 M.D. 200.0 11760.0 300.0 100.0 100.0 200.0 100.0 100 0 400 0 200 0 200 0 200 0 300 0 300 300 100 100 100 400 400 200 16-Nov-1999 390 2 200 4-Jan-2000 77 7 1425 25-0ct-1999 77 7 1425 6-Mar-2000 200 5 100 1-Nov-1999 200 5 100 4-Jan-2000 330 3 100 22-Sep-1999 330 3 100 26-Aug-1999 310 3 0 3-May-2000 127.9 1221 15-Ju1-1999 69.8 400 29-Feb-2000 49.3 200 27-Jun-1999 49.3 200 28-Jun-1999 340.3 100 28-Jun-1999 290.2 100 10-May-2000 117.0 1437 6-Apr-2000 130.1 100 30-Apr-2000 130.1 100 28-Jun-1999 868.9 2822 Diverging from M.D. 14620 0 13515 3 4040 0 100 0 100 0 200 0 100 0 100.0 16717.2 16700.0 200.0 200.0 3455.6, ~, 10360.0 14500.0 12766.7 100.0 100.0 400.0 400.0 200.0 200.0 15000.0 16160.0 15000.0 16717.2 15220.0 15220.0 0.0 16717.2 14220.0 200.0 16560.0 14780.0 100.0 15580.0 100.0 100.0 2822.2 Pi' ILLIPS Alaska, I(_c. Sfrucfure: CD#1 Field : Alpine Field Well: 6 Location : Norfh Slope, Alaska 320 330 10o TRUE NORTH, ~00 ~ 0 10 / / \~4500 / / \ x 3~5°° 4~00 ~ 5100 2900 2700 41 O0 310 x 50 59oo~ 60 290 280 80 27O 9O 260 100 250 110 240 120 230 ~oot ~~oo /2~o 700 900 (900 170 160 I~00 140 130 Normol Plone Trovelling Cylinder - Feet All depths shown ore Meosured depths on Reference Well PHILLIPS Alaska, Inc. CD#1 6 slot #6 Alpine Field North Slope, Alaska ELLIPSE CLEARANCES 3-D MINIMUM DISTANCE CLEARANCE INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ REPORT Your ref : CD1-6 Version #6 Our ref : prop3952 License : Date printed : 16-May-2000 Date created : 14-Apr-2000 Last revised : 16-May-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.572,w150 55 31.879 Slot Grid coordinates are N 5975869.883, E 385964.835 Slot local coordinates are 256.61 S 2538.57 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* ELLIPSE CLEARANCES Object wellpath PMSS <384 - 14477'>,,23,CD#1 PMSS <0-10224'>,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD#1 CD1-43 Version #9,,43,CD#1 PMSS <0-11067'>,,32PHI,CD#1 PMSS <10016 - 11136'>,,32,CD#1 CD1-28 Version #5,,28,CD#1 CD1-33 Version #4,,33,CD#1 CD1-30 Version #4,,30,CD#1 CD1-31 Version #2,,31,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD#l PMSS <832 - 12147'>,,25,CD#1 PMSS <0-11608'>,,42,CD#1 CD1-17 Version #8,,17 CD#1 CD1-29 Version #2,,29 CD#i PMSS <0-8350'>,,26PH1 CD#1 PMSS <7755-11134'>,,26 CD#1 CD1-21 Version #3,,21 CD#i CD1-20 Version #3,,20 CD#I CDi-18 Version #2,,18 CD#i PMSS <0-9357'>,,16P~1 CD#i PMSS <8393 - 12600'>,,16,CD#1 CDl-10 Version #3,,10,CD#1 PMSS <0-10897'>,,3,CD#1 PGMS <0-10255'>,,WD2,CD#1 CD1-15 Version #2,,15,CD#1 PMSS <0-7331'>,,1PHi,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <0-9236'>,,22,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <472 - 1545'>,,36PH1,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-10548'>,,19,CD#1 PMSS <2827 = l1956'>,,19A,CD#1 CD1-2 Version #6,,2,CD#1 PMSS <0-10796'>,,24,CD#1 CD1-4 Version #10,,4,CD#1 44 Version#6,,44,CD#1 PMSS <297 - 9882'>,,44PH1,CD#l PMSS <9081 - ?77'>,,44,CD#1 PMSS <476 - 11190'>,,34,CD#1 PMSS <0-10504'>,,SPH1,CD#1 ~MSS <9499 - 14515'>,,5,CD#1 CD1-9 PM1 Version #6,,~PH,CD#i Closest apDroach with 3-D Minimum Distance method Last revised Distance 3-May-2000 4-Jan-2000 22-Sep-1999 12-Apr-2000 4-Jan-2000 23-Dec-1999 13-Jan-2000 il-Aug-1999 il-Aug-1999 11-Aug-1999 28-Jun-1999 28-Jun-1999 13-Feb-2000 14-Feb-2000 16-Mar-2000 3-Apr-2000 26-Mar-2000 15~Mar-2000 23-Dec-1999 19-ADr-2000 13-Jan-2000 6-Mar-2000 1-Nov-1999 10-Aug-1999 10-Aug-1999 10-Aug-1999 4-Jan-2000 25-0ct-1999 10-Aug-1999 4-Jan-2000 28-Jun-1999 5-Apr-2000 29-Feb-2000 27-Jun-1999 15-Ju1-1999 28-Jun-1999 26-Aug-1999 4-Jan-2000 16-Nov-1999 4-Jan-2000 4-Jan-2000 22-Dec-1999 6-ADr-2000 30-ADr-2000 8-Aug-1999 10-May-2000 10-May-2000 14-May-2000 14-May-2000 15-May-2000 11-May-2000 23-Jan-2000 23-Jan-2000 2-May-2000 122.3 328.5 328.5 369.4 257.8 257.8 215.3 267.9 238.8 247.8 289.2 339.5 318.3 318.3 209.2 348.5( 348.5( 186.8( 359.3( 108.0( 228.5( 199.6( 199.6( 148.7( 138.7( 115.0( )62.7( )62.7( )33.5( )28.0( )814.7( )87.7( )48.3( )48.3( )67.5( 158.5( 308.5( 389.2( 389.2( 299.7( 299.7( 299.7( 128.7( 128.7( )38.1( )103.5( )18.1( 7939.3 )379 7( )379 7( )278 2( )7 1( )7 1( )28 4( M.D. 1235.7 450.0 450.0 300.0 400.0 400.0 707.1 507.1 300.0 535.7 200.0 200.0 200.0 200.0 200.0 200.0 200.0 450.0 200.0 400.0 300.0 200.0 200.0 300.0 400.0 535.7 1525.0 1525.0 578.6 300.0 2911.1 535.7 300 0 300 0 464 3 507 1 300 0 200 0 200 0 100 0 100.0 100 0 492 9 492 9 300 0 1462 5 300 0 2433 3 200 0 200 0 300 0 300 0 300 0 400 0 Diverging from 16717 2 14980 0 14980 0 300 0 15940 0 15940 0 14380 0 15400 0 16180 0 16040 0 200 0 14780 0 16480 0 16480 0 16717 2 16640.0 16640.0 16717.2 16260.0 16717.2 15800.0 14620.0 16717.2 15480.0 15140.0 535.7 14260.0 16717.2 14360.0 14660.0 2911.1 535.7 300.0 13427.3 14640.0 13800.0 15380.0 200.0 200.0 16480.0 14440.0 14440.0 15182.2 3760.0 13820.0 15840.0 14620.0 2433.3 16700.0 16700.0 16540.0 10040.0 14800.0 5140.0 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 24, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-06 (& CD1-06 PH) Dear Sirs: · [-,,,,,m ~' ".' ~' ',;, 2 6 2000 Aiaska 0{i & Gas Cons. C0mmi~ion Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore gas injection well from the Alpine CD1 drilling pad. The intended spud date for this well is June 14, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-06 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 67°. This will allow evaluation of the reservoir interval. It 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 gas injector. At the end of the work program, the well will be closed in awaiting field start up~. ~(,,5~,,5' '~',)~ ~.-~(~"t~ t As per the AOGCC regulations)1999, 25.412 (b) we request that permission be given to plade the packer at +/- 12500' MD. This is approximately 700' from the top of the Alpine. This request is being made so that the hole inclination will be Iow enough to enable the running of wireline conveyed cement evaluation logs below the base of the completion. 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~'~'l~obertson Senior Drilling Engineer Attachments CC: CD1-06 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 Look at Alpine 401 CD1-06 (200-084). Proposal is to drill a grass roots gas injection well. Made request to set packer 700' md, 141' tvd above Alpine to have Iow enough angle (-67 deg) to get a bond log down. Proposed packer ~1,5_0.~.' -67 deg, EOT 12558' -67 deg, 7" @ 13482' -87 deg, top of Alpine D @ 13149' -76 deg, top of Alpine @ 13216' -78 deg. Discuss with Blair...says we should review that. Check disposal well WD-02 (198-258). Pull WD-02 file. They set the packer high for some reason. Gave a lot a headaches with EPA. Relatively straight hole. Pull an injection well file...CDl-16 (199-094). Packer @ 8898' md -53 deg, 7" @ 9596' md -87 deg. Top of Alpine 9331' md -76 deg. Intended to set WLEG 100' above top of Alpine, but had problems getting ~ angle. By email requested permission to set packer -430' above Alpine. Blair approved. Look at CD1-26 (199-088). 7" @ 8554' -86 deg, packer @ 8085' - 53 deg, EOT @ 8193' -60 deg, top of Alpine D @ 8262' -68 deg. Another email discussion. Look at CD1-45 (199-101). 7" @ 9032' -85 deg, packer @ 8580' -58 deg, EOT @ 8690' -60 deg, top of Alpine @ 8786' -66 deg. T- EXPENDITURES BY MONTH/ 3~' TO SEPTEMBER COLLOCATION CODE EXPENDITb,.&S BY ACCOUNT 2140101-00 EPA.GRANT COA'2000 ENTITY NUMBER - DESCRIPTION S** 70000 TOTAL EXPENDITURES S** 70009 TOT EXPS-PRECLOSING S** 70008 OPERATING ACCT TOTAL S** 70100 GROUP CTRL-PER SER S** 71000 PERSONAL SERVICES RRN'008~ 2 RSN'04605 01/03/2000 3ULY AUGUST SEPTEMBER SPENT SPENT SPENT 5,601.20 5,601.20 5,601.20 5,601.20 5,601.20 13,728.87 13,728.87 13,728.87 13,728.87 13,728.87 17,345.34 17,345.34 17,345.34 17,345.34 17,345.34 EXPENDITURES BY MONTH / OCTOBER TO DECEMBER RRN:0082494 RSN:04605 01/03/2000 COLLOCATION CODE EXPENDITURES BY ACCOUNT 2140101-00 EPA GRANT COA: 2000 OCTOBER NOVEMBER DECEMBER ENTITY NUMBER - DESCRIPTION SPENT SPENT SPENT s** 70000 TOTAL EXPENDITURES S** 70009 TOT EXPS-PRECLOSING S** 70008 OPERATING ACCT TOTAL S** 70100 GROUP CTRL-PER SER S** 71000 PERSONAL SERVICES 18,245.67 18,245.67 18,245.67 18,245.67 18,245.67 15,892.11 15,892.11 15,892.11 15,892.11 15,892. ll 14,370.86 14,370.86 .14,370.86 14,370.86 14,370.8~ EXPENDITURES BY MONTH / 3ANUARY TO MARCH COLLOCATION CODE EXPENDITURES BY ACCOUNT 2140101-00 EPA GRANT COA: 2000 ENTITY NUMBER - DESCRIPTION S** 70000'TOTAL EXPENDITURES RRN'0082495 RSN'04667 03/31/2000 70009 TOT EXPS-PRECLOSING 70008 OPERATING ACCT TOTAL 70100 GROUP CTRL-PER SER 71000 PERSONAL SERVICES 79200 C-onmlo /'TO' -- r~'ruE,~' · ~l ~., · i~l-- ~,~ I I I 702~ ~' ~"~' 7~nn~ ~,,c. SRVCS & C:lAR55 3ANUARY FEBRUARY MARCH SPENT SPENT SPENT 16,~. 59 18,268.70 16; 603.'.42 16,~77 59 18,268.70 16,'603.., 42 30~00 .00 .0 3000 . O0 . O0 ~ . O0 . O0 200-083-CD106pkr.txt Subject: CD1-06 (Proposed PTD 200-083) Date: Wed, 07 Jun 2000 16:10:34 -0800 From: Tom Maunder <tom maunder@admin.state.ak.us> To: Brian Robertson <brobert4@ppco.com> CC: Blair Wondzell <blair wondzell@admin.state.ak.us> Brian, Thanks for getting back to us with your proposal. We do understand th e rationale regarding the request to set the packer and associated jewel shallower than the regulations proscribe. We also appreciate your addressing the necessity of isolation and your proposal to determine that isolation is present above the proposed packer setting depth prio r to running the completion. Based on your message and our discussions I understand your plan to be as follows: ...pump sufficient cement to place the top of cement some 900' to 1000 md above the top of the Alpine sand ...run a cement quality log (CQL) before running the completion to determine effective isolation ...after assessing the cement quality and TOC, propose a packer settin g depth consistent with the determined quality information Provided adequate isolation is evidenced by the CQL, you are free to propose setting the packer at a shallower depth than proscribed by the regulations. When the CQL is available, please contact us so we may view the log. Again, thanks for your efforts on this matter. or Blair with any questions. Please contact myself Page 1 200-083-CD106pkr.txt Tom Maunder Petroleum Engineer AOGCC Subject: CD1-06 Packer Setting Depth Date: Mon, 5 Jun 2000 15:25:11 -0900 From: "Brian Robertson" <BROBERT4~ppco.com> To: tom maunder@admin.state.ak.us CC: "Douglas K Chester" <DCHESTER@ppco.com>, Blair wondzell@admin.state.ak.us Tom, Further to our conversation this morning, there follows some thoughts / proposals regarding the packer setting depth on the CD1-06 well. Doug and I would be happy to come over and discuss this with you and Blair - at your convenience. Please let me know a suitable time. Brian ....... Attached is the blown up schematic for the proposed CD1-06 gas injecti on well completion. This plan recommends setting the packer at +/- 12500' MD. This is some 716' above the top of Alpine. An exception from the standard 200' MD maximum distance between the packer setting depth and Top Alpine has been requested in the APD. To compensate for this 'high packer setting depth, it is intended the top of cement be raised to so me 916' MD above the Alpine (as opposed to the standard 500' MD). This will allow for cement isolation some 200' MD above the packer. This will also provide addition back up to t he increased amount of casing exposed to injection fluids underneath the packer. The rationale behind choosing this packer setting depth was as follows: 1. Wellbore geometry : to maintain the completion within 'wirelineable Page 2 200-083-CD106pkr.txt limits the XN nipple needs to be at a maximum inclination of around 67 deg. We have had some success at getting wireline and USIT logs to around 70+ deg. However this has been in lower step out wells. 2. The setting depth shown below, also allows for some 240' MD from th e end of tubing to 68 deg inclination at 12800' MD. This is the distance ove r which a SCMT (cement evaluation log) could realistically be run post-completio n. Note, if the cement evaluation log was run pre-completion this distanc e would not all be required and the packer could be set +/- 200' deeper. 3. Setting the packer within 200' of the top Alpine is undesirable fro m a future completion perspective. Future well work operations would have to be conducted using coiled tubing as opposed to slickline. (Embedded image moved to file: pic26527.pcx) Proposal: Running the USIT log on electric line, pre-completion should allow the cement quality to be determined to a depth very close to the top of th e Alpine (78 deg inclination). Based on this information (and on the rea 1 wellbore surveys) we could then choose the optimal packer setting dept h for the well. Some guidance from the AOGCC will be necessary to determine if it is still permissible to run a 'wirelineable' completio n or if it will be necessary to set the packer within 200' of the Alpine Page 3 H 1 68496 DATE 050400 HANDL] INVOICE / CREDIT MEMO CKOSO4OOA NST' S/H DESCRIPTION rilE ATrACHED CHECK IS IN PAYMENT FOR ri'EMS DESCRIBED ABOVE. TERRIE X 462E GROSS 100.00 I00.00 VENDOR ALASKASTAT 10 DISCOUNT NET 100.00 100.00 PAY IWELL PERMIT CHECKLIST COMPANY ~/~--~-~ WELL NAME d~:~//- ~)~ PROGRAM: exp FIELD & POOL J ,2.,~..~ ?~.,~ INIT CLASS '~ ~"~/' ~'~__~/,d.~ GEOL AREA ADMINISTRATION Permit fee attached ......................... ~" Y) N Lease number appropriat .e~.. Unique well name and number .............. : . . . ~__~,~N Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... ~ N Well located proper distance from other wells .......... d__Y.J N Sufficient acreage available in drilling unit ............ ~ N If deviated, is wellbore plat included ............... d.~ N Operator only affected party ................... ~ N Operator has appropriate bond in force ............. ~ N N . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... A,~ DATE .- ~-. ~O-ClD 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. DATE 26. G,~r_ ~ 27. 28. 29. . dev ///redrll serv /,/ wellbore seg ann. disposal para req c:~ ~'O UNIT# ~>'~-') _~;"'t'~ _"~,~/'~ ON/OFF SHORE (~ N 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 ..... ~ .) N BOPEs, do they meet regulation ................ ~t N BOPE press rating appropriate; test to ~~ psig. t,~ N Choke manifold complies w/APl RP-53 (May 84) ........ r,~ N Work will occur without operation shutdown ........... ~ N Is presence of H2S gas probable ................. Y (~ Permit can be issued w/o hydrogen sulfide measures ..... (~N Data presented on potential overpressure zones ....... ~___~N Seismic analysis of shallow gas zones ............. /L,/~ -Y N Seabed condition survey (if off-shore) ............. /~/'/Y Y N I G~-OLOGY 30. 31. 32. DATE 33. ~ ~",5~:DD 34. Contact name/phone for weekly progress reports [exploratory o. rlly,] Y N 'ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will'not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLO. G~': ~N ENGINEERING: UlCIAnnular coMMISSION: Comments/Instructions: O z O -I I'll Z c:~msoffice\wordian~diana~checklist (rev. 02/17100)
