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Home My WebLink About202-249CAUTION: 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 Supervisor To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Integrity Subject:10-426 form for CD2-51 SI non-witnessed MIT-IA 6-9-24 Date:Monday, June 10, 2024 1:41:18 PM Attachments:image001.png MIT CRU CD2-51 SI TEST 06-09-24.xlsx Afternoon, Please see the attached 10-426 form from the S/I non-witnessed MIT-IA on CD2-51 that were performed on 6-09-24. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022490 Type Inj N Tubing 10 10 10 10 Type Test P Packer TVD 6948 BBL Pump 3.7 IA 150 3300 3240 3240 Interval V Test psi 3000 BBL Return 3.7 OA 750 760 760 760 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 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec han ical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum injection pressure per AIO 18C.010 Notes: CD2-51 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Caudle 06/09/24 Form 10-426 (Revised 01/2017)2024-0609_MIT_CRU_CD2-51 9 9 9 9 9 9 9 9 9 9 9 99 9 -5HJJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-51 COLVILLE RIV UNIT CD2-51 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 CD2-51 50-103-20441-00-00 202-249-0 W SPT 6948 2022490 1737 2145 2147 2145 2143 780 800 800 800 REQVAR P Guy Cook 7/29/2022 MITIA to maximum anticipated injection pressure per AIO 18C.010. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-51 Inspection Date: Tubing OA Packer Depth 1020 3310 3300 3295IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220728140033 BBL Pumped:2.7 BBL Returned:2.7 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 MITIA to maximum anticipated injection pressure per AIO 18C.010. James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 14:27:39 -08'00' 5HJJ-DPHV%2*& )URP6PLWK7UDYLV77UDYLV76PLWK#FRQRFRSKLOOLSVFRP! 6HQW7XHVGD\-XQH30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW&58)RUPV $WWDFKPHQWV0,7&58&' 6,7(676[OV[0,7&58&'3$'6,7(676SDJH[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ ƚƚĂĐŚĞĚ͕ƉůĞĂƐĞĨŝŶĚϭϬͲϰϮϲĨŽƌŵƐĨŽƌD/dƐĐŽŵƉůĞƚĞĚĂƚZh͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌŶĞĞĚ ŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ dƌĂǀŝƐ^ŵŝƚŚ tE^/ŶƚĞƌǀĞŶƚŝŽŶΘ/ŶƚĞŐƌŝƚǇŶŐŝŶĞĞƌ ϵϬϳͲϲϳϬͲϰϬϭϰ dƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020290 Type Inj N Tubing 2425 2425 2425 2425 Type Test P Packer TVD 7088 BBL Pump 1.7 IA 60 1900 1850 1850 Interval 4 Test psi 1772 BBL Return 1.5 OA 480 630 630 630 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022440 Type Inj N Tubing 1940 1940 1940 1940 Type Test P Packer TVD 7064 BBL Pump 2.5 IA 50 2800 2740 2740 Interval 4 Test psi 1766 BBL Return 2.6 OA 740 740 740 740 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2012490 Type Inj N Tubing 3050 3050 3050 3050 Type Test P Packer TVD 7094 BBL Pump 1.9 IA 80 2000 1960 1960 Interval 4 Test psi 1774 BBL Return 1.7 OA 645 705 705 705 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2022490 Type Inj N Tubing 1740 1740 1740 1740 Type Test P Packer TVD 6948 BBL Pump 4.2 IA 60 3300 3280 3280 Interval V Test psi 3000 BBL Return 3.4 OA 780 800 800 800 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/13/22 Notes: Notes: CD2-32 CD2-35A CD2-51 Notes: CD2-49 Notes: Notes:MITIA to MAIP per AIO 18C.010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0613_MIT_CRU_CD2-pad_4wells 9 9 9 9 9 9 9 9 - 5HJJ CD2-51 Regg, James B (CED) From: Well Integrity Compliance Specialist S &CPF3 <n2549@conocophillips.com> Sent: Friday, July 17, 2020 3:11 PM erg To: Regg, James B (CED) IIII`"` Cc: Brooks, Phoebe L (CED) Subject: RE: [EXTERNAL]RE: CPAI 10-426 Forms From MIT's on 3M & CD2 Pads 2- — 5 Hi Jim, ? i fJ ?t�7z q0 Thank you for your time this afternoon. I wanted to summarize our phone conversation regarding not having an approved extension for these wells. These wells were shut in for facility maintenance during the month of June when the compliance testing was due. Knowing that the repair would soon be completed, rather than testing the well twice within two weeks, first offline then online, the decision was made to wait and test with AOGCC witness when online. The wells were brought online June 29`n which did not allow time for stabilization before testing by the end of the month, in turn, delaying testing into July. I apologize for the lack of communication regarding the planning for testing these wells and will share this event as a lesson learned to our team. Sincerely, SarctLCcwUs& (Ue4k,(*L) / StephaWel pack. Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490con com Cell: 907.331-7514 1 sara.e.carlisle@cop.com From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Friday, July 17, 2020 1:31 PM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL]RE: CPAI 10-426 Forms From MIT's on 3M & CD2 Pads MITs for CD2 -51 and -55 were due NLT 6/30/2020. Please forward a copy of the AOGCC approved extension. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or lim.regg2alaska.eov. From: Well Integrity Compliance Specialist WNS & CPF3 <n2549(0)conocophillips.com> Sent: Wednesday, July 15, 2020 5:05 PM To: Regg, James B (CED) <lim.regg@alaska.aov>; DOA AOGCC Prudhoe Bay <doa.aoecc,prudhoe. bav alaska.aov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.aov>; Wallace, Chris D (CED) <chris.wallace@alaska,gov> Subject: CPAI 10-426 Forms From MIT's on 3M & CD2 Pads All, Please see the attached 10-426 forms for MIT's recently completed on 3M and Cd2 pads. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop coni Cell: 907-331-7514 1 sara.e.carlisle@con com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reggictalaskaCov: AOGCC.InsoectorsrElalaskaoov: phoebe. brooks(Malaska.aov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Alpine / CRU / CD2 PAD DATE: 07/14/20 OPERATOR REP: Duffy AOGCC REP: Waived by Lou Laubenstein chris wallaceCcDalaska nov 2e�j -7/17(Zhelzo Well CD2 -51 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4 = Four Year Cycle F = Fail PTD 2022490,1Type Inj W - Tubing 1 2045 „ 2045' 1 2045 2045 N = Not Injecting Type Test P Packer TVD 6948 BBLPump 3.0 IA 1010. 3300 3275 3270' Interval V Test psi 3000 BBL Return 3.7 OA 800 - 810 - 810- 10-Notes: Notes: MITIA to maximum anticipated injection pressure per AIO 186010 Witness waived by Lou Laubenstein Well CD2 -56 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2031180 Type Inj W Tubing 1830 1830 1830 1830 Type Test P 7325 BBLPump 2.8 IA 1090 3300 3280 3280 Interval V 3000 BBL Return 2.9 OA 790 807 811 813 Result P Jots: MITIA to maximum anticipated injection pressure per AD 1BD.002 Witness waived by Lou Laubenstein Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: 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 Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD T] BBLPump IA Interval .atPsi BBL Return OA Result No es: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test 1= Initial Test P = Pass G = Gas O = Other (describe In Notes) 4 = Four Year Cycle F = Fail S=Slurry V= Required by Variance 1=Inconclusive 1= Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT CRU CD2 -51 55 07-14-20 SMEMORANDUM State of Al• ska II a Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: P.I.Jgg mRSupervisor /((.31/,;(4 SUBJECT: Mechanical Integrity Tests P.I.Su ervisor �/G 1� CONOCOPHILLIPS ALASKA,INC. // CD2-51 FROM: Brian Bixby COLVILLE RIV UNIT CD2-51 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-51API Well Number 50-103-20441-00-00 Inspector Name: Brian Bixby Permit Number: 202-249-0 Inspection Date: 6/6/2018 V Insp Num: mitBDB180611052629 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6948 Tubin 2530 • 1 2540- 2540 ' 2540 Well - cDz-51Type Inj w Test psi - -- ----- ---- -- TVD g PTD 2022490 Type Testi SPT 3000 IA 980 3300 - 3290 3290 - BBL Pumped: 1 2.8 •JBBL Returned: 2.7 OA 760 - 780 - 780 - 780 Interval ; REQVAR P/F P Notes: Tested to MAIP as per AIO 18C010 ✓ JUN 2 i Luz Page 1 of 1 Monday,June 11,2018 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,July 11,2016 P.I.Supervisor 9 1,q/to SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-51 FROM: Brian Bixby COLVILLE RIV UNIT CD2-51 Petroleum Inspector Src: Inspector Reviewed By:T P.I.Supry �/ . NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-51 API Well Number 50-103-20441-00-00 Inspector Name: Brian Bixby Permit Number: 202-249-0 Inspection Date: 6/22/2016 Insp Num: mitBDB160622150119 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-51 Type Inj W -TVD 6909 , Tubing, 2280 . 2250 - 2250 - 2250 , 2250 PTD 2022490 -. Type Test SPT Test psi 1727 IA 1480 3300 - 3080 - 3060 - 3060 - Interval REQVAR P/F P - OA 720 • 730 730 735 - 735 Notes: A10 18C.010 c: , '!. NOV 2 22016 Monday,July 11,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, March 13, 2016 1:28 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CRU CD2-51 (PTD 202-249) Report of IA pressurization Attachments: CD2-51.pdf; CD2-51 90 day TIO trend 3-13-16.JPG Chris, CRU CD2-51 (PTD 202-249) has exhibited slow IA pressurization while on miscible injection. DHD is being mobilized to perform the initial testing to include an MITIA, POTs, and IA DDT. A 30 day monitor period on miscible injection will follow the diagnostics to monitor the pressure build up rate and determine the number of bleeds required to maintain the well within WOG during the monitor period. Once the miscible injection monitor period has been completed the well will be WAG'd to water for a 30 day monitor period to confirm integrity while on water injection. Post diagnostics and monitor periods CPAI intends to submit an application for Administrative Approval to continue injection in the well. As always, if the MITIA fails the well will be shut in. Attached are a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 SCANNED APR 0 4 2016 WELLS TEAM ConocoPhillips 1 W ? I Ul Ul W N 2 Cr [Y cii 9,--' w Kt U — en W C t? c' O. r, r, W T o N N W re V d U Ll, Ci, 1r`J o Z N W C6 y W O C CD CD p, C) u, f u, I- Iy fV I- N WO 0 r pa ry r di w (vi iv in I u, u, J C) C) 1,1 L., C] Ci •l CJ U 0 0 0 0 0 0 CD 0 CD —Afi0ji r o r- tgr0 I I I I W r..r.. ~ i. to V.."' • 41) r W V C lir ta a) 11111111 Y! C m no O t 8 no to 011,111 It 8111 V -moi O C E 4 o J ULk (A as 1 N Q -b en ! O O1441 7 v O co nr c o Q _N M (J ,r- r, M _ 0 c c ll III U) EUcu 1 U U U U U O O 7. Mme., d CD CD 6 O O O CD CD C3 Z 1 JQ 11f{ }¢I� «. U+ V U, 0 Yl CJ tll C.0 Y, W i .,0 T !� a z' ` Q ( -1 -1 rl r'1 N N CI Od 40 vl XI 07 l6 !''B ISd V7 O W I Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 ,TM ECENED 4 2Ii1 Commissioner Dan Seamount Alaska Oil & Gas Commission 441614W APR 0 201} C +1iSSion 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 '' ®fa Commissioner Dan Seamount: / a.° v - 5 Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 ,.402 -51 50103204410000 2022490 5'10" 0.80 15" 3/21 /2007 3.9 3127/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 • MEMORANDUM To: Jim Regg ~~~~ ~(ZZ~ P.I. Supervisor 1\ la FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-51 COLVILLE R1V UNIT CD2-51 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J ~~~ Comm Well Name: COLVILLE RIV UNIT CD2-51 API Well Number: 50-103-20441-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100719114130 Permit Number: 202-249-0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-51 ',Type Inj. ~w ~ ~ TVD 6853 ' IA 700 2790 ~ 2750 2740 ' P.T.D 2 022490 Ty'peTCSt ~ SPT TCSt pSl 1713 ~ -QA- 620 850 840 840 -~- InterVal4YRTST p~F P Tubing 2010 2020 2010 2010 Notes: 3.6 BBLS diesel pumped. 1 well inspected; no exceptions noted. ~ .. 1 ,. t. Monday, July 26, 2010 Page 1 of 1 . . ~ ConocoPhillips Alaska :\/í ." ì~ ? P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 ;~~ ili!ili §eRl: ~GfftW;tllteN AweN9Il/ March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 dvt}d-- ~ 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 respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st_ 22° ,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \]7¢ ~ Arend- ConocoPhillips Well Integrity Field Supervisor ~ li~NED MAR ~ 6 2007 Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commissl TO: ~~~ s~::r~isor R el t <; {30! D(c DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CO2-51 COLVILLE RIV UNIT CO2-51 ~ ~~ ~O FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -Ji32-- Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-51 API Well Number 50-103-20441-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS06082815 1712 Permit Number: 202-249-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CO2-51 Type Inj. G TVD 6853 IA 1125 2470 2250 2250 2250 P.T. 2022490 TypeTest SPT Test psi 1713.25 OA 620 780 760 760 760 " Interval 4YRTST P/F P ,/ Tubing 3750 3750 3750 3750 3750 Notes Well had a waiver form hanging on wellhead limiting it to water injection only. Well curently on gas injection Conoco Phillips personell indicated the waiver had been canceled. / , I (-. "I ~ é 4-t{ ", A;,,~·,·'v, Q. A--~'to J C:I \ CÔÜ I ¡?r- Q , I~c/¡ G01 ¡ - I v'C.! ..",Le,¡, d ¡ - :::>1../ lJ_J ", -'''11'\ 'Yr-'" v '0 / -:-17 ' I -.J ,<,i'11' '[,(3" (,"-' sCANNED SE? 0 82006 Wednesday, August 30, 2006 Page I of I e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _ Inserts\Microfilm _ MaIker.doc e Conoc6Phillips e G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 December 15, 2005 RECEIVED DEC 1 9 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gaa "'''H1S. Commission Anchorage Subject: Corrected Report of Sundry Well Operations for C02-51 (APD202-249/ 305-314) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached corrected Report of Sundry Well Operations for the recent workover operations on the Alpine wells C02-51. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, A. L . 0« G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells 'U·'.I\."')"'¡·'" 'Q!'¡.....4'tß\:~~t.i r s;, " ?nríf; u () ,;..&, ~";' U7.J GCAlskad , ..... \".; I- I ~ "-.... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e DEC 1 9 2005 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission Anchorage 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing 0 Perforate New Pool 0 Waiver D Time Extension D Change Approved Program D Opera!. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 202-249/305-314 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20441-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' 152.7' AMSL CD2-51 8. Property Designation: 10. Field/Pool(s): ADL 380075 1 372097 1 25559 Colville River Field 1 Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 17320' feet true vertical 7108' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 3085' 9-5/8" 3121' 2410' PRODUCTION 13210' 7" 13246' 7167' OPEN HOLE 4074' 6-118" 17320' 7108' Perforation depth: Measured depth: open hole completion from 13246'-17320' true vertical depth: 7128'-7108' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 12625' MD. Packers & SSSV (type & measured depth) Baker Premier pkr, Baker S-3 pkr @ 12329',12532' Cameo 'DB' Landing Nipple @ 2406' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable ..iø.ts 8Ft DEC 2 (} 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubinq Pressure Prior to well operation -- -- 4800 bwpd -- -- Subsequent to operation -- -- 3000 bwpd 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Vern Johnson @ 265-6081 Printed Name Å.Alvord Title Alpine Drilling Team Leader Signature .( ~~ Phone 'U.,.-<Ç - , 11. ø Date I l..(c £. ( .ø <"" Prenared bv Sharon AI/sun-Drake 263-4612 Form 10-404 Revised 04/2004 0; . -,:' Submit Original Only . . G. C. Alvord Alpine Drilling Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 December 7, 2005 RECE/VFO DEC 0 8 2005 . A'"k, Oil & G,s .. A·.. Cons.Lomffllssu:m nChøtøø_ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for CD2-51~~"249/3Q6...a14) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Alpine wells CD2-51. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, A. t. ()(~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells 5CANNED DEC 1 92005 GCA/skad .--- ~,.. ,. 1. Operations Performed: . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . Kt:GEIVED DEC 0 8 2005 AI'$ka Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage o Time Extension 0 o Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Opera!. ShutdownD Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 36' 152.7' AMSL 8. Property Designation: ADL 380075 1 372097 1 25559 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION OPEN HOLE Perforation depth: measured 17320' 7108' Plug Perforations D Perforate New Pool 0 Stimulate 0 Waiver 0 Other true vertical measured true vertical Length Size Perforate 0 4. Current Well Status: Re-enter Suspended Well 5. per~it t08r!1I~~mber: o ~:j>'~:249 r305-314~ o 6. API Number: 50-103-20441-00 80' 3085' 13210' 4074' 16" 9-5/8" 7" 5-1/2" Development 0 Stratigraphic 0 Exploratory Service 9. Well Name and Number: CD2-51 10. Field/Pool(s): Colville River Field 1 Alpine Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 114' 3121' 13246' 17320' 114' 2410' 7167' 7108' true vertical depth: 7167'-7108' Measured depth: open hole completion from 13246'-17320' Intervals treated (measured) not applicable Oil-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Tubing (size, grade, and measured depth) 4-1/2" , L-80, 12625' MD. Packers & SSSV (type & measured depth) Baker Premier pkr, Baker S-3 pkr @ 12329', 12532' Cameo 'DB' Landing Nipple @ 2406' 12. Stimulation or cement squeeze summary: 13. Treatment descriptions including volumes used and final pressure: R8DMS 8Fl DEC 0 8 7005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 4800 bwpd 3000 bwpd 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJ 0 WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt: Contact Vern Johnson @ 265-6081 r-1( Printed Name C. Alvord Title A'I,{4- I\.Æ~AIPine Drilling Team Leader Signature A.c ttz. Phone U·r-G 12..D ~::rL12!,~s;;,su)-Drake263-4612 Form 10-404 Revised 04/2000 RIG I N A L CasinQ Pressure TubinQ Pressure WDSPL 0 Submit Original Only . . Page 1 of 2 ConocoPhillips Alaska Operations Summary Report Legal Well Name: cD2-51 Common Well Name: cD2-51 Event Name: WORKOVER/REcOMP Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 : Sub Date From - To . Hours. Code ! Code Phase 10/21/2005 10/22/2005 21 :00 - 21 :45 0.75 MOVE RURD MOVE 21 :45 - 23:30 1.75 MOVE OTHR MOVE 23:30 - 00:00 0.50 MOVE MOVE MOVE 00:00 - 02:00 2.00 MOVE MOVE MOVE 02:00 - 03:00 1.00 MOVE OTHR MOVE 03:00 - 10:00 7.00 MOVE MOVE MOVE 10:00 - 12:00 2.00 WELLSR OTHR DECOMP Spud Date: 3/12/2003 End: Group: Start: 10/21/2005 Rig Release: Rig Number: 19 Description of Operations PJSM - Prep rig for move - Pull high line Hydraulic leak on pipe shed - Clean up spill - repair hose - Raise pipe shed & move PJSM (moving rig) - Move pipe shed - Move pits & motors - Move sub offCD2-17A Finish cleaning up spill under pipe shed Move rig fl CD2-17A to CD2-51 - Move over well- Skid floor - Move in pipe shed - Move in pit & motor complexes Ru service lines & highline power - RU salt water line - loading tbg in pipe shed Accept rig @ 10:00 hrs. 12:00 -13:30 1.50 WELLSR NUND DECOMP Pull BPV - RU lines to kill well 13:30 - 16:00 2.50 WELLSR OBSV DECOMP Moved sea water source line to CD2-55 - Take on sea water for well kill (8.6 ppg) 16:00 -19:00 3.00 WELLSR KILL DECOMP PJSM - Displace well wI 474 bbls - 8.6 ppg sea water@ 5 bbls/min ICP 1100 psi FCP 1220 psi - Shut down & flow check well (static) Blow down lines & RD 19:00 - 21:30 2.50 WELLSR NUND DECOMP RU & set TWC - test to 5000 psi - ND tree - NU BOPE - riser & flow line 21 :30 - 22:00 0.50 WELCTL BOPE DECOMP Set test joint & RU to test BOPE 22:00 - 23:00 1.00 WELCTL BOPE DECOMP Conduct pre test - check for leaks - floor valve leaking - Replace & change test manifold 23:00 - 00:00 1.00 WELCTL BOPE DECOMP Begin testing BOPE as follows: Hydril to 250 & 3500 psi - Pipe rams, Choke manifold, choke & kill line vlaves to 250 & 5000 psi 10/23/2005 00:00 - 03:45 3.75 WELCTL BOPE DECOMP Finish testing BOPE - Pipe rams,blind rams, choke maniflod valves, floor safety & dart valves 250 & 5000 psi Performed accumulator closure test - Test witnessed & approved by John Crisp AOGCC RD test equipment & blow down lines 03:45 - 05:00 1.25 WELLSR PULD DECOMP PJSM - RU & unseat tbg hanger & pull up to rig floor - String wt. 198 k - LD hanger & Landing j!. - Change out elevators 05:00 - 15:45 10.75 WELLSR PULD DECOMP Pull & LD 41/2" tbg f/12,523' to 1086' (261 jts) - Observed diesel smell at surface 15:45 - 18:00 2.25 WELLSR CIRC DECOMP RU & reverse circulate 2X tbg & annulus volume to open top tank @ 3 bblslmin 350 psi - didn't observed any diesel to tank - Blow down lines - Flow check - well static - RD lines 18:00 - 18:15 0.25 WELLSR OTHR DECOMP Measure tbg in pipe shed 18:15 -19:30 1.25 WELLSR PULD DECOMP Finish pulling & laying down 4 1/2" tbg - GLM & cut off pup from chemical cut (3.38') 287 jts. total- Flow check -well static - Monitor well onTT Will have tbg checked for NORM 4.50 WELLSR OTHR DECOMP Work on tbg in pipe shed - strap, drift & install seal rings - Clean up rig floor & RU to run 4 1/2" completion 1.50 CMPL TN OTHR CMPL T2 Finish preparing tbg for completion 12.00 CMPL TN RUNT CMPL T2 PJSM - RU & Run 4 1/2" completion as follows: Baker Poor Boy over shot wI 4' perf pup, 2 jts. tbg - X nipple - 2 jts. tbg - Baker Premier Packer assembly - 2 jts tbg - Camco GLM assembly - 227 jts tbg - Camco DB nipple - 54 jts. tbg - to 12,460' (287 jts. total - All tbg 4 1/2" 12.6# L-80 IBTM 2.25 CMPL TN SOHO CMPL T2 PU 2 jts. tbg - RIH & tag up on tbg stub - Space out l' off of stop - LD space out jts. - LD 2 jts in string - MU tbg pup jts. 2 jts below hanger - PU 2 jts. tbg - MU tbg hanger & land tbg wI Poor Boy overshot 1 ft. from stop 19:30 - 00:00 10/24/2005 00:00 - 01 :30 01 :30 - 13:30 13:30 - 15:45 Printed: 11/1712005 1:45:49 PM . . Page 2 of 2 ConocoPhillips Alaska Operations Summary Report LD landing jt A - Set TWC - MU landing j!. - Attempt to test seals - leak on collar of test j!. - Change out collar Attempt to test hanger seals - Pressure not holding - trouble shot - seals leaking - Pull hanger & change - Re build back up hanger - MU hanger & land tbg - RU & test hanger seals to 5000 psi ND flow line & riser - ND BOPE - Install tree Rigged up and tested tree to 5000 psi. Rigged up manifold and pumped 188 Bbls. inhibited brine followed by 235 Bbls of diesel to freeze protect well. Tested lines to 5000 psi. Pressure up on tbg to 4600 psi to set packer- bled 600 psi off annulus - Pressure test tubing with 3500 psi, 30 minutes - bled down tubing to 1500 psi - pressure up annulus to 3500 psi, 30 minutes - Bleed off annulus to 0 psi - Bled tubing to 400 psi and shut in at wellhead. Rig released for PM @ 0830 Hrs. 9.00 DRILL PULD MOVE Laid down 4" Drill pipe from derrick in mouse hole. Legal Well Name: cD2-51 Common Well Name: cD2-51 Event Name: WORKOVER/REcOMP Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 . ;. Sub Date From - To . Hours. Code Code Phase 10/24/2005 10/25/2005 15:45 - 17:15 1.50 CMPL TN OTHR CMPL T2 17:15 - 18:00 0.75 CMPLTN OTHR CMPL T2 18:00 - 22:00 4.00 CMPL TN OTHR CMPL T2 22:00 - 00:00 2.00 CMPL TN NUND CMPL T2 00:00 - 01 :00 1.00 CMPL TN SEQT CMPL T2 01 :00 - 07:00 6.00 CMPL TN FRZP CMPL T2 07:00 - 08:30 1.50 CMPL TN PCKR CMPL T2 10/26/2005 15:00 - 00:00 Spud Date: 3/12/2003 End: Group: Start: 10/21/2005 Rig Release: Rig Number: 19 Description of Operations Printed: 11/1712005 1:45:49 PM CD~1 Workover Sc.matic II 16" Conductor to 114' Updated 11/10/05 4-1/2" Camco DB Nipple (3.812') at 2042' TVD = 2471' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @3121'MD/2411'TVD cemented to surface Upper Completion: TOP MD TIlQ Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 2406' 2004' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2- GLM (3.938" ID) 12216' 6800' 4-1/2" 12.6 ppf L-80 IBTM 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) tubing run with Jet Lube Run'n'Seal Baker Premier Packer 12329' 6853' pipe dope 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) HES "X" (3.81")-62° inc 12435' 6903' 4-1/2", 12.6#/ft, IBT-Mod tubing (2) "poor boy" over shot with perforated pup 12529' 6947' Bottom of "poor boy" over shot wlpup 12535' 6949' Lower Completion: TOP MD TVD 4-1/2", 12.6#/ft, IBT-Mod tubing stub 12524' 6944' Baker S3 Packer wI millout extension 12532' 6948' 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725") 12532' 6984' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 12626' 6989' Camco KBG-2 GLM (3.938" DRIFT ID) wI dummy 3.81" X nipple, with RHC plug, Perforated pup, and overshot assembly Baker S3 Packer WI millout extension --------------------------------------.wëïïTD-ä-¡---1 17320' MD I ! 7148' TVD i Top AI~in~·-~t·13083' MD I 7139' TVD"" ........,.,....................... ..... '"IIIf---------..-m---------------n---m--nmm---------------. noon -- __n .... 7" 26 ppf L-80 BTC Mod Production Casing @ 13246/7168' TVD @+I- 89.6° MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 30, 2005 TO: Jim Regg '0 . ~ _ .. _ _~p.Lsuper.visoL_\~~iZ.lI_-Z 'ù::>_-----ªy~-!F:~T: M~ºªl!!f~Jl11egILty Te~~.... . {{ CONOCOPHILLIPS ALASKA INC C02-5] COLVILLE RIV UNIT C02-5] / ~----~. aÙ:r FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: :JI2;¿ P.I. Suprv , Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CO2-51 API Well Number 50-103-20441-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG051 13011 1919 Permit Number: 202-249-0 Inspection Date: 11/29/2005 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I C02-5] ¡Type Inj. I w TVD I 6853 I IA I 600 i 2520 i 2510 ! 25]0 I , I I P. T. I 2022490 ¡TypeTest! SPT ' Test psi I ]7]3.25 lOA [ 750 I 800 i 790 I 790 i Interval INITAL P/F P Tubing 1245 i 1260 I ]245 I ]235 I Notes STP shut-in before pressure up ofIA. Tubing pressure declined due to cessatiion of injection. <2 bbl's required. g~;;C~M&\US:;;! ~w.ru~~tI~~ 2; 2; Wednesday, November 30,2005 Page I of I e e rID· n· :~. . fÆ·ß·-: !Æi ~. 'iV!'!Æ / ' ~ { ,. ! 11 ' 1 .U¡ bl\~lJ\\A / AI,ASIiA OIL AlWD GAS / CONSERVATION COMMISSION I FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 30,2005 Ms. M. J. Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SCANNED DEC 1. 9 2005 RE: Administrative Approval AI018B.001 Dear Ms. Loveland: In response to your recent inquiry, this is to clarify the applicability of Administrative Approval AIO 18B.00 1. That administrative approval addressed a situation in which intermittent pressure communication from the tubing to inner annulus had been discovered in well CD2-51~9). ·When the approval request was submitted, ConocoPhillips Alaska, Inc. ("CPAI") did not propose repairing the well to eliminate the pressure communication. The Commission determined that water injection would be allowed to continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Subsequent to obtaining the approval, CPAI has repaired the well, eliminating the pressure communication. The well has successfully passed the standard Mechanical Integrity Test ("MIT"). Consequently, Administrative Approval AIO 18B.00 1 no longer applies to operation of this well. Instead, the provisions of the under . g Area Injection Order No. 18 will again govern injection in well CD2- 1 ~ e e > >-------- Original Message -------- >Subject: CD2-51 AA cancellation (AIO 18B.001) >Date: Fri, 11 Nov 2005 11:31:52 -0900 >From: NSK Problem Well Supv <n1617@conocophillips.com> >To: tom_maunder@admin.state.ak.us, James Regg ><jim_regg@admin.state.ak.us> >CC: NSK Problem Well Supv <n1617@conocophillips.com> > > > >Tom & Jim, 'at > >CD2-51 had a RWO in the last month that repaired the TxIA >communication. CD2-51 had been injecting under AIO 18B.001 approval. > >This well will be removed from the Monthly Failed MITIA report, changed > >back to a 4 yr MITIA cycle, and MI injection will be allowable. > >Are the AA's just like sundry approvals in that they cancel >automatically when the drilling sundry report of repair is submitted, >or >is there extra paperwork needed to cancel the AIO for CD2-51? > >Thanks, >Marie McConnell >Problem Well Supervisor >659-7224 > > > > > > > > 1 of 1 11/30/2005 11:13 AM Re: CD2-51 Post Rig State Witnessed MIT Timing . . We will have an inspector at Alpine on or about 11/29 to witness meter prove; I'd suggest we do the MIT for CD2-51 at that time. We can do others in conjunction with a BOPE test or some other reason. Jim NSK Problem Well Jim/Tom, suP/te, CD2-51 (PTD 202-249) was recently worked over to repair TxIA communication. The well passed an informal pressure test to 3000 psi (Pre MIT) prior to being brought online (BOL) in water injection service. Historically we complete the initial State witnessed MIT after the well has thermally stabilized (online for 1-2 weeks). This well was BOL 11/13/05. ConocoPhillips anticipates approval to commence injection on CD2-59 (204-248) and CD2-60 (205-068) in the next couple weeks. For logistic purposes, we propose delaying the Initial State Witnessed MIT on CD2-51 for - 30 days to allow injection commencement and stabilization time on CD2-59 and CD2-60. After which the initial MIT's on all three wells could be schedule for the same day. Our intent is to have the initial MIT's completed before year end. Below is a 7 day injection plot with T/I/O data for CD2-51. Please let me know if this proposal is acceptable MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SC!~N.h¡I:;F.\ {'i - \"C~t;:~L-j,",j t¡ '':i ¿ i Picture (Device Independent Bitmap) 1 of 1 4/26/200612:57 PM CD2-5 I Post State Witnessed MIT Tirui Subject: CD2-51 Post Rig State Witnessed M1T Timing From: NSK Problem Well Date: Sat, 19 Nov 2005 09:29: 49 .0900 To: Thomas Maunder CC: NSK Problem Wen Supv Jimfrom, CD2-51 (PTD The well passed an pressure test to 3000 psi online (BOL) in water injection service. Historically we complete the initial State witnessed MIT after the well has thermally stabilized (online for 1-2 weeks) This well was BOL 11113105, ConocoPhillips anticipates approval to commence injection on C02-59 (204-248) and C02-60 (205-068) in the next couple weeks, For logistic purposes, we propose delaying the initial State Witne$sed MIT on C02-51 for - 30 days to allow injection commencement and After which the initial MIT's on all three wells could be scoedule for the same day, Our intent is to have the initial MIT'$ completed before year end, Below is a 7 day injection plot with TIIIO data for C02-51, Please let me know if this proposal is acceptable MJ Loveiand ConocoPhillips Problem Well Supervisor 659-7224 ) ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Urn .regg.@a.çjmín.state,ak.us .gogCG pruç!hoe þay@ad:]1!n.state.ak.us bob f;eckenste!n@admíO.state,.ak,us Rig No.: 19 DATE: 10/23/2005 Rig Phone: 670-4302 Rig Fax: 670-4303 Op. Phone: 670-4300 Op. Fax: 670-4301 11/09/04 Contractor: Doyon Rig Rep.: Welsh/Lupton Operator: Conoco Phillips Alaska Rep.: Mickey Field/Unit & Well No.: Colville Rv CD2-51 Operation: Test: Test Pressure: Drlg: Initial: x Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Well Sign Dr!. Rig Hazard Sec. Size 13-5/8 3-1/2x 6 3-1/2x 6 blinds 3-1/8 3-1/8 3-1/8 Alarm Test P P P P P PTD # 202-249 Workover: x Weekly: Annular: 250/3500 TEST DATA Explor. : Bi-Weekly Valves: 250/5000 Test Resu It P P P Test Result P P P P P P P NA FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1400 P 200 psi Attained 38 P Full Pressure Attained 3 min 19 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 ~2250 Test Results Number of Failures: Q Test Time: ~ Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: jim regg@admín.state.ak.us Remarks: Good test SCANNEU NO\í 0 2 2005 24 HOUR NOTICE GIVEN YES X NO Date Test sta rt BOP Test (for rigs) BFL 11/09/04 10/21/05 10:00: PM Time Finish Waived By 16:00 Witness Crisp/Mickey/Lupton 3:00AM Doyon191 0-23-05 CD2-51.xls ) ) !(?T"',i"'I.!,:¡:,~", 1,:¡;;~, \, :~? ~ \ <,\,i\c.!, IJ ql\ I ¡ II '\~\, I¡ J/\\ ri.:~ . ,'ì \~ f ," '\ I I ¡": nJ,) !! if' 1\ ! I i L ~ u ~ ,.j~ ~::n :,-["":1 I ' !b ~JI,,' , I I ' / / / ¡/ .I I ) J FRANK H. MURKOW5KI, GOVERNOR A.,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~ß 3P':}-- ~ Re: Colville River CD2-51 Sundry Number: 305-314 6CMNED OCT 3 1 2005 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by .4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~ day of October, 2005 Encl. 1. Type of Request: Abandon 0 o o Alter casing Change approved program ~tIÐ-I~-ð5 ý_ ) STATE OF ALASKA ¡J 10£ l"l RECEIV~l9\\ ALASKA OIL AND GAS CONSERVATION COMMISSION I~ acr 1 I lQQ5 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AII~kl 9il & Gas Cons. Commilsion Operational Shutdown 0 Perforate 0 waiverA"q~~Ø~ Other 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Perforate New Pool D Suspend 0 ® o Repair well Re-enter Suspended Well o Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 36' / 52.7' AMSL 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: 202-249 /' 6. API Number: .~ 50-103-20441-00 9. Well Name and Number: CD2-51 Exploratory D Service 0 8. Property Designation: ADL 380075 / 372097 / 25559 11. Total depth MD (ft): 17320' 10. Field/Pool(s): Colville River Field / Alpine Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7108' Length Perforation Depth MD (ft): open hole completion from 13246'-17320' Packers and SSSV Type: Baker S-3 pkr @ Camco 'DB' Landing Nipple @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 1P 4f Commencing Operations: October 18: 2005 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Casing CONDUCTOR SURFACE PRODUCTION OPEN HOLE 80' 3085' 1321 0' 4074' Signature ,Æ. Alvord /~.í.. Ck,{, / Size MD TVD Burst Collapse 16" 114' 114' 9-5/8" 3121' 2410' 7" 13246' 7167' 5-1/2" 17320' 7108' Perforation Depth TVD (ft): 7167'-7108' Tubing Size: 4-1/2" Tubing Grade: L-80 Tubing MD (ft): 12625' Packers and SSSV MD (ft) 12531' 2417' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil D Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL D Contact: Vern Johnson @ 265-6081 Title: Alpine Drilling Team Leader Phone '2.(..; ~ G· (1-" Date ( o( (, ( ð <" Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3¿J5- .~.:~ I ~ Plug Integrity D BOP Test ~ Other: ~QO~?\ ~\,,\ Mechanical Integrity Test ~ Location Clearance D , \s(J~ ~\- , ~~ò- \ \I:\~\ \,Q.c:..\æ~\ "" Cl, '-c::..«:Q~ "ù \ Q: ~r-- ifCJt:\~ ~~S"L\5G \.0-), RBDMS 8FL 0 CT J 3 2005 APPROVED BY COMMISSIONE. R ," A T,HE COMMISSION Ar~I("\~¡~' , 1 ¡·J1 l .... . \' \ l :, \ : \'" I , í \ . ._\ C"H Date: /O/o/~ Submit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ) ) ConocóP'hillips October 10, 2005 Re: Sundry Permit for Workover Operations, CD2-51 RECEIVED OCT 11 2005 Alaska Oil & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry permit for well workover operations. It is intended that Doyon 19 move to CD2-51 +/- October 20,2005. The purpose of the workover is to remediate a suspected slow leak in the tubing. The leak only becomes evident under water injection conditions. Reservoir pressure is estimated to be +/- 4000 psi. It is expected that we will be isolated from the reservoir during workover operations with the existing packer and a plug in the tailpipe below the packer, so the well will not need to be killed. It is requested that the packer placement requirement be relaxed to place the completion packer +/- 300 ft TVD above the Alpine formation. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-403 APPLICATION for Sundry Approval (20 ACC 25.280) 2. Proposed operational procedure. 3. Proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout 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 Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~in I;. ) ~ (Olftlo'7 rn J;nson Drilling Engineer ORIGINAL ) Attachments cc: C02-51 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson Chris Alonzo Steve Moothart Lanston Chin ) ATO 1530 ATO 1700 ATO 1702 ATO 1770 ATO-1756 Kuukpik Corporation ) ) Procedure 1. Pre-rig work will include removal of the injection valve @ 2417' MD. A plug will be set in an XN profile below the packer, and it will be positively and negatively tested to ensure isolation. Tubing above the packer will also be cut and a back pressure valve installed prior to moving the rig over the well. 2. Move on Doyon 19 3. NO tree. 4. NU and test BOP 5. MU landing jt. and pull 4-1/2" tubing. 6. If the tubing stub indicates the need for milling/dressing run, PU milling assembly, RIH and dress tubing stub. 7. Circulate the hole clean and pull out of hole, displacing the well to 9.2 ppg brine. 8. Run 4-~, 12.6#, L-80 tubing with DB nipple, gas lift mandrel, packer and tubing overshot. Swallow over tubing stub and space out. Land hanger. 9. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 10. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 11. Circulate tubing to diesel and install freeze protection in the annulus. 12. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 13. Set BPV and secure well. Move rig off. L-" \J\ \\ ~\'''''' S,,~\"0~Q< ~~~,. ~((( Completion Schematic: 16" Conductor to 114' Nipple. (3.812') 2417' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3121' MD 12410' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Cameo KBG"2GI..M (3.909" DRIFT ID) wi dummy Packer Upper Completion: Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo DB nipple 4-112", 12.6#/ft, IBT-Mod Tubing Cameo KBG2- GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 4-1/2", 12.6#1ft, 1ST-Mod Tubing (2) HES "X" (3.725"}-62° inc 4-1/2", 12.6#/ft, 1ST-Mod tubing (2) "poor boy" over shot Lower Completion: 2409' 12450' 4-1/2", 12.6#/ft, ISNvlodtµbing stub Baker $3 Packer wi milloutextension 4.1/2", 12.6#/ft, 1ST-Mod Tubing (1) HES"XN" (3.725") 12613' 4-1/2", 12.6#/ft, 1ST "Mod 10' pup jOint WEG Baker 53 Packer WI millout extension TOC @ +1- 12221' MD 16766' TVD Top Alpine at 13083' MD 17099' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 13246/7167' TVD @+I- 89.6° 7107' TVD Permit to Drill 2022490 MD 17320 /' REQUIRED INFORMATION ------- --- --"- ---- ---- S~~· DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Well Name/No. COLVILLE RIV UNIT CD2-51 TVD 7108 /' Completion Date 5/3/2003;" Completion Status Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset .T~~ _M_~d~rmt_~m~er Ar!i1-- ~t 4hv ~YAsc !~D ¡ Rpt 'P{ ~~\ ~ Log I : Log i : Log ! 'Erf" c.1ïJ '> --" -" ---~--------._- Name Directional Survey Directional Survey Directional Survey Directional Survey 11816 LIS Verification 1200ß 12riJ8 icv.a LIS Verification LIS Verification Induction/Resistivity Rate of Penetration Cement Evaluation Pressure Temperature 12594 Gamma Ray Well Cores/Samples Information: Name Operator CONOCOPHILLlPS ALASKA INC Samples No Log Log Scale Media ~\1'l......L ~ 1 ~ II g¡ ~ 125 Col 125 Col 125 Col Interval Start Stop Sent Run No 1 4 4 2,3,4 2,3,4 2,3,4 1 Received WAG IN Current Status WAGIN 5(1 t.t.l- I ~ r'lM ~ Oûj API No. 50-103-20441-00-00 cc.. UIC Y.) Directional Su~ y::-J (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received 349 17320 Open 5/13/2002 349 17320 Open 5/13/2002 0 349 Open 5/13/2002 0 17320 2/3/2005 3097 17255 Open 7/24/2003 3097 17255 Open 7/24/2003 3098 17319 Open 6/2/2003 3097 17255 Open 6/2/2003 3097 17255 Open 6/2/2003 34 12831 Case 6/27/2003 34 12831 Case 6/27/2003 34 12831 Case 6/27/2003 114 17320 Open 4/23/2004 Sample Set Number Comments '~ Comments MWD GYRO IIFR (Sag Corrected) GR, EWR4, ROP GR, EWR4, ROP Slim Cement Mapping Tool 9SCMT-BB) PSP: PressurefTemperature Slim Cement Mapping Tool 9SCMT-BB) PSP: PressurefTemperature Slim Cement Mapping Tool 9SCMT-BB) PSP: PressurefTemperature ROP, MWD, DGR, EWR ~. Permit to Drill 2022490 MD 17320 TVD 7108 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? "'r /1<1 Analysis -Y / N Received? Comments: --- - ._---------------~ - -- -- ~ -------- -- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Well Name/No. COLVILLE RIV UNIT CD2~51 Operator CONOCOPHILLlPS ALASKA INC Completion Date 5/3/2003 Completion Status WAGIN Daily History Received? Formation Tops /Jj API No. 50-103-20441-00-00 Current Status WAGIN ~/N ClN Date: UIC Y '-" ;¿ r J~ ~ ~dJ' ---- ) ) ~ " (~~!Æ~E : F !Æ~!Æ~~~!Æ AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. Ala 18B.00l Ms. M. J. Loveland Pro blem Well Supervisor ConocoPhillips Alaska, Inc. P.O, Box 100360 Anchorage, AK 99510-0360 RE: CRU C02-51 (PTO 202-249) Request for Administrative Approval AI018B.001 Dear Ms. Loveland: Per Rule 11 of Area Injection Order ("AIO") 018.B, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants ConocoPhillips Alaska, Inc, ("CPAI") 's request for administrative approval to continue water injection in the subject well. AOGCC finds that CPAI has performed diagnostic testing on C02-51 attempting to locate and quantify the reason for an intermittent pressure communication from the tubing to inner annulus. The diagnostic testing has not been able to definitively determine a cause for the communication. Based on the intermittent appearance of the pressure communication and the relationship to fluid temperatures, CPAI believes that a slight leak in the sealing elements at the packer may be the cause. At this time, CPAI does not propose to perform a repair to eliminate the pressure communication, The Commission further finds that, based upon reported results of CPAI's diagnostic procedures, C02-51 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in CRU C02-51 is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. CPAI shall monitor and record wellhead pressures (T /1/0) and injection rate daily; 3. CPAI shall submit to the AOGCC a monthly report of well pressures and injection rates; ) ) , ~ " Administrative Approval AlO 188.001 May 23, 2005 Page 2 of2 4. CPAI shall demonstrate continued tubular integrity by performing an MIT - T and MIT - IA every two years to 3000 psi; 5. CPAI shall determine the fluid level in the OA every 2 years; 6. CPAI shall immediately shut in the well and notify the AOGCC upon any measurable change in well outer annulus pressure; and 7, After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission cis ion to Superior Court unless rehearing has been requested, , 2005. f)aniel T. Seamount. Ir, Commissioner Çjf¡¿~ Commissioner ~,.:P:~ ':..' , ' . ~ort~~ ~~~ "J-~h ~ , ~~,::o-:'.,.;¡M R ...~~\~ ~,.,~ . ø.r--:,(;.¡;~~ J ~~J~)~:~,~;;r,~.n ~ . ~, ¿p ¿it)'!¡; ~(\',,:oy;,~,:\:~:\,.,l~~ ,.... O'/.I:~' ~5}:\!;:;.~'::?" \. ~ l nodI ,~."",':J' ...., '.,'7' lOA "1H t~ '~,:~:·~f~" ,i:.".r~Îr ' .n ~ ~ j';"!. "':~ \!" "~",::;.~",, Âj'~¡ ~ ~~~H!\~~;';)::(:ÇìÛ~'ßY~\¡,~" ~- . .,.).. .:.,::":,.,,,.,~, ~.1:'''·,· ,""1"'_ _J;~ ' :::'.~ ~~;.~. \~'~'{~I~::r·:··~~~~ '-1~~~~ ) -~'.' y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~"E:"" ... ;;;;:.-\ ,r"" { ~:....;c.c¡';'j ".~:-::;7 '1 g May 15,2005 Mr, John Norman, Chairman Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 S ubj ect: Alpine Well CD2-51 (PTD 202-249) Request for Administrative Relief to Continue Water Injection Operations Dear Mr, Norman: ConocoPhillips Alaska, Inc" requests approval to continue water injection operations into Alpine well CD2-51, This request is pursuant to Area Injection Order No, 18B, Rule 11 Administrative Actions, CD2-51 has tubing by inner annulus communication via a very slow linear leak in an undetermined location - possibly at the packer. A combination of mechanical integrity pressure tests of tubing and casing strings indicates the well has competent mechanical integrity and can be safely operated, Barriers have been defined (see attached) that will prevent an inadvertent release and confine fluids to the approved zones, The attached Technical Justification includes a proposed operating and monitoring plan, Daily monitoring of the wellhead and casing/tubing mechanical integrity tests are proposed to verify the well continues to be safe to operate. Should observations or tests indicate a compromise of well integrity, the well will be shut-in and the AGOCC notified, There is no source of underground drinking water in this area that could be endangered by this proposal. If you need additional information, please contact me or Marie McConnell at 659-7224, Sincerely, Aüf/ / ¡f / ///1/tvt:A ~ MJ Loveland Problem Well Supervisor Attachments On~r f¡\~ l\L t\ ~ lJ i\J l~\ ) ') ConocoPhillips Alaska, Inc. Alpine Well CD2-51 (PTD 202-249) Technical Justification for Administrative Relief Request Well History and Status Colville River Unit well CD2-51 (PTD 202-249) was originally completed in May 2003, as a MW AG Service well, In January 2004, inner annulus (IA) and tubing (T) pressures in this well started tracking, indicating TxIA communication, At that time, the 1" dummy valve in the tubing was pulled and replaced, after which, the tubing and IA stopped tracking and the well passed a mechanical integrity test of the IA (MITIA), March 23,2005, TxIA communication indications were again observed and reported to the AOGCC, The well failed a diagnostic MITIA on 3/25/05, with a very slow linear pressure leak and was SI. On 4/7/05 that failure could not be repeated - after conducting several passing MIT's of the tubing and inner annulus the well was brought back online. However, the well failed an additional MITIA on 4/15/05, with another slow linear leak, We concluded that the well would pass an MIT while it was SI; however, would fail an MIT while online injecting cold seawater, On 4/27/05, the dummy valve in the tubing was replaced; this time with an extended packing dummy for water service in hopes it would seal the leak. It passed an MITIA that day while it was SI; however, also failed another MITIA with a slow linear leak on 4/30/05 after it was brought on line, The pressure leak off in every failed MIT was slow enough that a liquid leak rate could not be achieved for a cQnventionalleak detection log, Currently the well will pass a mechanical integrity pressure test when the well is SI and wann, It will fail a MIT while it is online injecting cooler seawater. This phenomenon suggests some sort of seal leak, possibly the packer. Well events: 3/25/05: MITIA to 2500 psi - failed with well online, 4/07/05: MITT to 2400 psi with plug in TT - passed, MITIA to 2500 psi - passed, Combo TxIA MIT tubing to 1750 and IA to 3000 psi - passed, all tests were completed with the well SI. 4/15/05: MITIA -2500 psi - failed while well was online, tubing and inner casing packoff pressure tests passed, 4/27/05: Replaced DV with high seal ability packing, MITIA to 2500 psi - passed while well was SI 4/30/05: MITIA to 2500 psi - failed while well was online injecting cool SW. 5/10/05: MITOA failed - well has an open shoe, can pump 1 BPM at 1600 psi, holds static column of fluid at 800 psi, NSK Problem Well Supervisor 5/15/2005 1 ) ) ~ \> Barrier and Hazard Evaluation Tubing: The tubing has integrity to the casing and sand interval below the packer based on a passing MITT @ 3000 psi. Production casing: The production casing has integrity down to the packer based on a passing MITIA to 3000 psi while the well is SI. However, may still have a very slow linear leak possibility at the packer when injecting cold seawater. The 7" L-80 production casing has an internal yield pressure rating of 7240 psi, Surface casing: The surface casing has no cement shoe; however, will hold a static column of fluid at 800 psi, The 9-5/8" 36# J-55 surface casing has an internal yield pressure rating of 3520 pSI, Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing, The tubing appears to have solid integrity based on the MITT. Secondary barrier: The production casing is the second barrier. It holds a solid MIT when SI and only has a slow linear leak to pressure when online, The surface casing also provides a partial secondary barrier up to ,...., 800 psi. Monitoring: Each well is monitored daily for wellhead pressure changes, Should leaks develop in the production casing above the surface casing shoe, it will be noted during the daily monitoring process. Any deviations from approved Maximum allowable operating pressures (MAOP) annular pressures require investigation and corrective action, up to and including a shut-in of the well. T/I/O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1, Approve for water-only injection (no gas or MI allowed); 2, Perfonn 2-year MIT -T or MITIA to verify the tubing has not developed a leak and the MITIA failure has not worsened, 3, Perfonn 2-year OA fluid levels to ensure no injection out the bottom of the surface casing shoe; 4, Monitor T, lA, and OA pressures daily, particularly noting any sudden change from one day to the next. 5. Submit monthly reports of daily wellhead pressures and injection volumes; 6, Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC, Future Options The Engineering staff is proposing further options to identify the source of the leak using leak detection technology that is currently not available on the slope, There is a significant volume of reserves at risk if the well can not be returned to MI service. Therefore, every effort will be made to restore the casing integrity by locating and patching the leak or working over the well in the next couple of years, NSK Problem Well Supervisor 5/15/2005 2 MEMORANDUM TO: ') T?e114/77{ÙÇ Jim Regg P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector Well Name: COLVILLE RIV UNIT CD2-51 Insp Num: mitLG050417124339 Rei Insp Num: Packer Well I CD2-51 ¡Type Inj. S TVD P.T. 12022490 !TypeTest SPT Test psi Interval OTHER PIF F Notes: Diagnostic ìv1IT. Monday, April 18, 2005 State of Alaska Alaska Oil and Gas Conservation Commi~ ) DATE: Monday, April 18, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA fNC CD2-51 COL VILLE RIV UNIT CD2-51 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-103-20441-00-00 Permit Number: 202-249-0 Reviewed By: P.I.Suprv _.~ Comm Inspector Name: Lou Grimaldi Inspection Date: 4/15/2005 1320 Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. Depth 6947 I IA 1736.75 I OA Tubing 720 2500 720 1620 1620 2310 720 1620 2180 720 1620 Page 1 of 1 RE: PWIs lA-13 and CD2-51 ) sUþject:.. RE::PW~S)A-13 ~~ankS dOd-~~ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, April 18, 2005 2:35 PM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: PWIs 1A-13 and CD2-51 MJ, So long as there is no indication of any communication outside the casing, you request to keep these 2 wells in WATER ONLY service is acceptable. Please add the wells to the monitoring list and submit the Administrative Relief paperwork as you indicate. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: ~NED OCT 3 1 2005 Tom, Any decision on allowing this two wells (1A-13 and C02-51) to remain on line for a while? Just bringing it up in case the questions got buried in the dozens of emails I sent you this weekend. I can forward the original emails a questions if needed. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 1 of 1 ,,+-~ ~ " ~L~,J 10/27/2005 3:01 PM CD2-51 (PTD 202-249) and CD2-54 (PTD 204-178) ) ) S~~ject:....CD2-5~...(P1D.202-249) . and·ÇD2-.54.(PTIl204-17&).. Fr(JIt1:~~~r~9~lY111'Nell.~.upv <n~817@con9cpp~il1ip~'Q0tl1> . Da(¢}~at; 16Ap1:2PQ5.08:p9:11~0800 Tom, We completed additional diagnostics on injections wells C02-51 and on C02-54 yesterday. CD2-51 failed the MITIA with the well online injecting cold seawater. Earlier this month it passed a MITIA while it was SI. The leak appears to be slow with no attainable LLR. Since the leak is to slow to leak detect it is our intention to pursue an AR given that the combo MITIA and the MITT passed earlier this month. The tubing and IC packoffs were tested and passed yesterday as well. This well will be carried on the monthly failed MITIA report. ConocoPhillips requests verbal approval to keep the well (C02-51) online until a formal AR can be applied for and obtained. Our intent is to submit the AR application within the next -30 days. CD2-54 passed the diagnostic MITIA as well as Tubing and IC packott tests. However it did show signs of very slight TxlA communication when the IA pressure was bled back to 1000 psi (FTP 1600 psi) and it re pressured to 1200 psi after 2 hours. It is our intention to monitor this well and internally waiver it which would include an annual MITIA. If the well changes status, or the MITIA fails the AOGCC will be notified. State Inspector Lou Grimaldi was onsite and checked in during the tests, however did not formally witness them. Please let me know if you have any questions or require more information for the verbal approval on CD2-51. MITIA results are attached. «MIT CRU C02 04-15-05.xls» Thank you MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 Content-Description: MIT CRU CD2 04-15-05.xls MIT CRU CD2 04-15-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 ,Ç\~ .:~U ..¿:-...~ 'X \'L(Ç>~ - 1 of 1 10/27/2005 3 :02 PM RE: CD2-51 MIT Results ) ) Subject: RE: CD2-51 MIT Results From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Fri, 08 Apr 2005 11 :05 :32 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Kralick, Jack T" <Jack. T .Kralick@conocophillips.com> Thanks for the quick response Tom! Jerry Oethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, April 08, 2005 10:53 AM To: NSK Problem Well Supv Cc: jim_regg@admin.state.ak.us; bob_fleckenstein@admin.state.ak.us Subject: Re: CD2-51 MIT Results Jerry, Your testing appears to demonstrate that there is no communication. Returning the well to operation is acceptable and keeping it under increased survelience is appropriate. Keep us advised of the well's performance and we will look for the T/I/O plot in the April report. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom & Jim: Yesterday a series of MITs were performed on CPAI Alpine well C02-51. The well is an injector that was reported to you on 3/23/05 as having T x IA communication. As you can see from the MIT test results, we have not yet found a problem and the MITs pass. There may be some kind of intermittent mechanism that is causing the suspected communication problem, but for now the well looks tight. A tubing plug was set so that an MIT-tubing, MIT-IA, and Combination T x IA tests could be performed. The casing, tubing and packer all show integrity based on the passing tests. Please review the attached MIT form and Well Service Report. The well is being readied to return to water injection today. We would like to return this well to water injection as part of the plan forward, and go into a monitoring phase to see if the communication is going to return. We can put this well on the monthly report and see if there is some indication of the problem returning. Please drop me a line at your earliest convenience. «C02-51 MIT 04-07-05. RTF» «MIT CRU C02-51 04-07-05.xls» Jerry Oethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 "",,-W:J ~ --c.o~ ~\~ 1 of 1 10/27/20053:01 PM ) CRU_CD2-51_TXIA_2005-0324.txt ) subject: Alplne Injection well CD2-51 (PTD 202-249) From: NSK Problem well Supv <n1617@çonocophillips.com> Date: Thu, 24 Mar 2005 14:57:52 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, jim_regg@admin.state.ak.us Tom, Jim Below is a plot showing the T/I/O pressures for the past 6 months for well CD2-51. Around mid November the injection rate was increased and therefore the increase in tubing and IA pressure. However, the IA pressure required bleeding after the increase in injection/tubing pressure. The IA was bled 3 times in late December and early Jan. 05, then again on March 22. It appears the Tubing and IA pressures first started to equalize around Jan. 7. The OA pressure of 750 psi is a normal operating pressure at Alpine. I will provide you the results of the MIT-IA once that has been completed. please let me know if you have any questions. Brad Gathman conocophillips Alaska Inc. problem well supervisor 907-659-7224 picture (Device Independent Bitmap) Brad Gathman conocophillips Alaska Inc. Problem well supervisor 907-659-7224 page 1 CD2-51 MIT Results ) ') , Subject: CD2-51 MIT Results From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Fri, 08 Apr 2005 10:40:44 -0800 To: tom _ maunder@admin.state.ak.us CC: j im _regg@admin.state.ak.us, bob _ fleckenstein@admin.state.ak.us 20~- d-~\ Tom & Jim: Yesterday a series of MITs were performed on CPAI Alpine well C02-51. The well is an injector that was reported to you on 3/23/05 as having T x IA communication. As you can see from the MIT test results, we have not yet found a problem and the MITs pass. There may be some kind of intermittent mechanism that is causing the suspected communication problem, but for now the well looks tight. A tubing plug was set so that an MIT-tubing, MIT-IA, and Combination T x IA tests could be performed. The casing, tubing and packer all show integrity based on the passing tests, Please review the attached MIT form and Well Service Report. The well is being readied to return to water injection today. We would like to return this well to water injection as part of the plan forward, and go into a monitoring phase to see if the communication is going to return. We can put this well on the monthly report and see if there is some indication of the problem returning. Please drop me a line at your earliest convenience. «CD2-51 MIT 04-07-05.RTF» «MIT CRU C02-51 04-07-05.xls» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 I 'iiCorttent-Description: CD2-51 MIT 04-07-05.RTF II i¡CD2-51 MIT 04-07-05.RTFiiContent-Type: applicationlrtf ' Content-Encoding: base64 I I Ii Content-Description: MIT CRU CD2-51 04-07-05.xls MIT CRU CD2-51 04-07-05.xls! Content-Type: applicationlvnd.ms-excel i Content-Encoding: base64 1 of 1 4/8/2005 10:53 AM ) ) PHilliPS Alaska, Inc. WELL C02-51 DATE 04/07/05 DAY 1 FIELD ESTIMATE JOB SCOPE ANN-COMM DAILY WORK ANN COM DIAGNOSTIC OPERATION COMPLETE NO KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (CD2-51 (W4-6)) JOB NUMBER 0330051037.3 UNIT NUMBER SL 3437-ALP SUPERVISOR KRALlCK SUCCESSFUL NO DAILY COST KEY PERSON HES-MARSHALL ACCUM COST AFC# 10074314 Initial Tbg Press 1450 PSI CC# Signed Final Tbg Press 1800 PSI Initial Inner Ann 1500 PSI Final Inner Ann Initial Outer Ann Final Outer Ann 1450 PSI 700 PSI 730 PSI DAILY SUMMARY I PERFORMED MIT TBG : PASSED. MIT IA: PASSED. COMBO MIT: PASSED. TIME 06:00 07:00 07:30 15:30 16:20 16:35 16:50 17:00 17:15 17:30 18:05 18:20 18:35 18:50 19:05 19:20 19:45 20:00 20:15 20:30 21:15 22:00 LOG ENTRY PICK UP COMPUTER PAPERWORK, TRAVEL TO LOCATION RIG UP HES, 2118 ROLLER STEM; RS QC 13' QC OJ QC KJ LSS. STANDBY FOR PUMP TRUCK. RIG UP LRS. STAB ON WELL. PT LUB. PUMP 7/10 BBL DOWN TBG. PRESSURED UP TBG TO 2400 PSI. IA 1575 PSI. OA 710 PSI. TBG 2390 PSI. IA 1585 PSI. OA 710 PSI. TBG 2375 PSI. IA 1580 PSI. OA 710 PSI. PUMP TBG UP TO 2975 PSI. IA 1625 PSI. OA 710 PSI. TBG 2963 PSI. IA 1625 PSI. OA 710 PSI. TBG 2960 PSI. IA 1625 PSI. OA 710 PSI. TBG DROPPED 15 PSI. IAAND OA REMAINED THE SAME. MIT TEST PASSED. BLEED TBG DOWN TO 1650 PSI. PUMP IA UP TO 2500 PSI. OA 770 PSI. TBG 1665 PSI, IA 2480 PSI, OA750 PSI TBG 1670 PSI. IA 2475 PSI. OA 750 PSI. MIT ON THE IA PASSED. TESTED AGAIN WITH 3000 PSI ON IA TBG 1750 PSI. OA 780 PSI. TBG 1750 PSI. IA 2975 PSI. OA 770 PSI. NO CHANGE TBG, lA, OA. MIT IA PASSED AGAIN. BLED IA BACK TO 2560 PSI. PUMP TBG UP TO 2500 PSI FOR COMBO MIT. OA 730 PSI. TBG 2475 PSI. IA 2560 PSI. OA 730 PSI. NO CHANG IN TBG, IA OA. COMBO MIT PASSED. BLEED TBG BACK TO 1800 PSI. BLEED IA BACK TO 1450 PSI. LAY DOWN FOR NIGHT. PJSM. NOTIFY DSO OF WELL STATUS. TRAVEL TO CAMP. DOWNLOAD COMPUTER. END TICKET. ~ (', . FLUID SUMMARY 15 BBLS DIESEL DOWN TBG. SERVICE COMPANY - SERVICE HALLIBURTON LITTLE RED PHILLIPS TOTAL FIELD ESTIMATE DAILY COST ACCUM TOTAL ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: Alpine CRU CO2-51 DATE: 04/07/05 OPERATOR REP: Marshall / HES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CO2-51 Type Inj. N TVO 6947 Tubing 1 ,450 2,400 2,390 2,375 Interval 0 P.T.D. 2022490 Type test P Test psi 1737 Casing 1,500 1,575 1,585 1,580 P/F P Notes: MITT conducted with a plug in the tubing. The tubing was pressured with diesel. Well CO2-51 Type Inj. N TVD 6947 Tubing 2,375 2,975 2,963 2,960 Interval 0 P. T. D. 2022490 Type test P Test psi 1737 Casing 1,580 1,625 1,625 1,625 P/F P Notes: MITT conducted with a plug in the tubing. The tubing was pressured with diesel. Well CO2-51 Type Inj. N TVO 6947 Tubing 2,960 1,650 1,665 1,670 Interval 0 P.T.O. 2022490 Type test P Test psi 1737 Casing 1,625 2,500 2,480 2,475 P/F P Notes: Bled down tubing, pressured IA with diesel. Well CO2-51 Type Inj. N TVO 6947 Tubing 1,670 1,750 1 ,750 1,750 Interval 0 P.T.D. 2022490 Type test P Test psi 1737 Casing 2,475 3,000 2,975 2,975 P/F P Notes: Repeat MITIA (re-pressured IA) Well CD2-51 Type Inj. N TVO 6947 Tubing 1,750 2,500 2,475 2,475 Interval 0 P. T. D. 2022490 Type test P Test psi 1737 Casing 2,975 2,560 2,560 2,560 P/F P Notes: CMIT T x IA against TTP--bled back lA, pressure up tubing Test Details: MIT tests conducted due to suspected T x IA communication reported 3/23/05. A tubing plug was set in the XN nipple @ 12613' md and the MITs were performed against this plug. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUNey A = Temperature Anomaly SUNey 0= Differential Temperature Test MIT Report Form Revised: 06/19/02 MIT CRU C02-51 04-07-05-1.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) ") ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Alpine/CRU/CD2 03/25105 Shorty Davis ~..,.'. '~' ""~!:~:,,.,c.,' &0' .",-", ::;, ",' I:', 'I", :.';'. .'!I'~: I,' . .. Packer Depth Well CD2-51 Type Inj. S TVD 6,947' P.T.D. 2022490 Type test P Test psi 2500 Notes: MIT-IA conducted due to suspected T x IA communication Well CD2-51 Type Inj. S TVD 6,947' P.T.D. 2022490 Type test P Test psi 2500 Notes: MIT-IA conducted due to suspected T x IA communication Pretest Initial 15 Min. 30 Min. Tubing 1,940 1,940 1,940 Interval 0 Casing 1,950 2,500 2,350 P/F F Tubing 1,940 1,940 1,940 1,940 Interval 0 Casing 2,350 2,570 2,340 2,225 P/F F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0325_MIT _CRU_CD2-51.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 426* 426 0 31343 34 11/18/2003 12/24/2003 C02-07 C02-10 0 0 0 0 0 0 0 0 0 ~' Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the ~ :.' . '} f2f1rfé quarter. SCANNt:.W J A¡~ ~ V';tþ\:> 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 303-312 (h)(3) Other Commission approved substances (include descriptions in block 12) 1 0/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 4th 31243 100 2004 / 1 st o o 2004 / 2nd o o 2004/3rd o o Total Ending Volume (bbls): 31243 100 426 31769 Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D 11. Attach: * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. \ è ~- -'1 \. ~ Signature: Date: Kuparuk Drilling Team Leäae~' Printed Name: Randy Thomas Title: Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-249 C02-51 50-103-20441-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 34 \ (,/oS Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 426* 426 0 31343 34 11/18/2003 12/24/2003 C02-0?, C02-10 0 0 0 0 0 0 0 0 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D ~ -, 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 303-312 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 14th 31243 2004 I 1st 0 2004 I 2nd 0 /--. 104 / 3rd 0 Total Ending Volume 31243 (bbls): 100 o o o 100 426 31769 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s ): Pressure vs. Time D Step Rate Test D * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. < \ ~ \~'>- Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-249 C02-51 50-1 03~20441-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 34 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \. ~(l~ (0 cr Phone Number: (907) 265-6830 {).1Z lOt. a,,.p do~-;<C¡·7 /259~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 20, 2004 RE: MWD FOffilation Evaluation Logs: C02-51, A,K-MW-2323383 CD2-51 : Digital Log In1ages: 50-103-20441-00 1 CD RaIn PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING "THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:Or7 Or Signed: RECE'VED þ,PR 2 3 2004 Alaska Oil & Gas Cons, Commission Anchor8ge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 4th 31243 100 0 0 0 0 2004/1st 2004 / 2nd 2004 / 3rd Total Ending Volume (bbls): 31243 100 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas D WAG0 GINJ D WINJ D WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 303-312 (h)(3) Other Commission approved substances (include descriptions in block 12) 1 0/28/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-249 C02-51 50-103-20441-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .~ 426* 426 0 31343 34 11/18/2003 12/24/2003 C02-07, C02-10 0 0 0 0 0 0 426 31769 34 * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~1~ Step Rate Test D Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE ""--'1 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ì/<6foy Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 426* 426 0 31343 34 11/18/2003 12/24/2003 C02-07, C02-10 0 0 0 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 303-312 (h)(3) Other Commission approved substances (include descriptions in block 12) 1 0/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 4th 31243 100 2004 I 1st o o 2004 I 2nd 2004 / 3rd Total Ending Volume (bbls): 31243 100 426 31769 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D * Freeze protect volumes I hereby certify that the forego~ue and corre~o ~he ,best of my knowledge. Signature: . \. ~~ \ \.,;~ Printed Name: ~C"" ~ ì ~ \""""\. c.S Date: \J c-.~~ \e.'"L_ Lz~ Title: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-249 C02-51 50-103-20441-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ .~. 34 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter, Lf/r6/DY Phone Number: 2';';-6 Ö)O Submit in Duplicate MIT data for Alpine CDU CD2-51 ) ) Subject: MIT data for Alpine CDU CD2-51 From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 15 Feb 2004 15:53:34 -0900 To: "Tom Maunder AOGCC (E-mail)..<tom_maunder@admin.state.ak.us>. "Jim Regg AOGCC (E-mail)..<jim_regg@admin.state.ak.us>. "Bob Fleckenstein AOGCC (E-mail)..<bob_fleckenstein@admin.state.ak.us> Q " \' o..lo 4 Bob, Torn, & Jim, f-J?tî~' \ v Attached is the results of an MIT on the IA of Alpine injector CD2-51 (PTD #202-249) completed on 2-14-04 for diagnostics. No problem was identified. Please let me know if you have any questions, Marie McConnell Problem Well Supervisor 659-7224 «MIT CRU CD2-51 02-14-04,xls» .. MIT CRU CD2-51 Content-DescrIptIon: 02-14-04.xls CRU CD2-51 02-14-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 2/18/2004 11 :45 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) ) Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Alpine I COU I C02-51 02/14/04 Hansen - HES N/A Well CD2-51 Type Inj. P.T.D. 2022490 Type test Notes: Diagnostic Test s P Packer Depth TVD 6,909' Tubing Test psi 1727.25 Casing Pretest 2,200 500 Initial 700 3,000 15 Min. 30 Min. 800 800 Interval 2,975 2,975 P/F ~ y' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-0214_MIT_Alpine_CD2-51.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: r \ ~ ~ ~ ~ Printed Name: \<-.....- ..J. i' ,~~ J 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 14th 31286 100 YYYY 10# YYYY /0# YYYY /0# Total Ending Volume (bbls): 31286 100 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service 0 Development 0 Exploratory D 4b. Well Status: Oil D Gas 0 WAG0 GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 303-312 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/28/2003 Volume (bbls): Number of days disposal occurred 383* 383 o 31386 383 31769 34 Step Rate Test D Date: Title: ~ to- S \' c--~ L.e~-t INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-249 CD2-51 50~ 1 03-20441-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: -~./' 34 11/18/2003 12/24/2003 CD2-07, CD2-10 ~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. t (t..' (0 y Phone Number: US--G"ßJo Submit in Duplicate ~E: CD2~51 & CD2-28 AD Requests ) ) Subject: RE: CD2-51 & CD2-28 AD Requests Date: Mon, 27 Oct 2003 15:34:18 -0900 From: "Johnson, Vern" <Vern.Johnson@conocophillips.com> To: "Tom Maunder \"" <tom_maunder@admin.state.ak.us> CC: "Alvord, Chip" <Chip.Alvord@conocophillips.com> Tom, \ ''tcoc.\-;A. \\'1 ~ ~ \Cè.Q,. "-c~ We re-tested the annulus on CD2-28, and saw a higher than expected leak off pressure. We suspect it may be a build up of ice in the annulus as CD2-28 has been shut in for a long time to allow pressure build up in that area. We tried flowing the well for a few days to melt any ice that may be there, but we did not see an improvement in the pumping pressure after re-testing. We plan to re-test again after we bring the well on continuous production later this year. We also re-tested CD2-51. See the attached file with the test results. Attached are the data from the second retest. The first re-test was done with the Dowell pumping unit and a long run of hardline. The curve from that test had an uncharacteristic change in slope, so the test was re-ran using a pump truck, and it showed a leak off point of 15.3 ppg. As you can see there is a change in slope at +/- 1040 psi, and sharp decline in pressure after 30 seconds to 920 psi, which with diesel gives 15.3 ppg as the leack off point. 0 \ <... Let me know if you have any questions or comments. JJ;:.. ~ «CD2-51A Annular LOT.xls» Vern Johnson ConocoPhillips 907 -265-6081 > -----Original Message----- > From: Tom Maunder" [mailto:tom maunder@admin.state.ak.usl > Sent: Monday, October 13,2003 12:21 PM > To: Vernon T Johnson/PPCO@Phillips; Chip Alvord/PPCO@Phillips > Subject: C02-51 & C02-28 AO Requests > > Vern and Chip, > I was looking at the packets for the subject wells and had a couple of > questions, Please also refer to the other wells that were included, > C02-58 and C02-12. > The integrity tests for all of the wells are acceptable. They > essentially show jug tight at 16 ppg EMW or better. > On C02-51and C02-28, the pump in pressure up is somewhat "choppy" with a > sharp break from the maximum pressure and then a decreasing pumping > pressure as injection continues. On each well, the pressure drop while > pumping is over 200 psi. The pumpin pressure may be stabilizing on > C02-28, but there is insufficient information to see if this is so. > This is in contrast to C02-58 and C02-12 where the pressure up is smooth > and then a relatively constant injection pressure is developed. > When pumping ceases, the pressure slowly declines and stabilizes on all > wells but CD2-28 which is still dropping at about 10 psi/minute. > I'd appreciate your interpretation of the information on C02-51 and > C02-28. The pressure information reminds of a well we looked at a while > back when we made a request to repeat the injectivity test. Look > forward to your thoughts. > Tom Maunder, PE > AOGCC « File: tom_maunder. vcf» Name: CD2-51A Annular LOT.xls ~:A~. CD2-51 A A I LOT I Type: Microsoft Excel Worksheet (application/vnd.ms-excel) ---."" nnu ar .x s E d' b 64 -- nco m9: ase Description: CD2-51 A Annular LOT.xls 1 of 1 10/27/2003 3:54 PM Well Name: Drilling Supervisor: C02-51 -- - -----~ - -- - --- I Rig: David Burley PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Doyon 19 I Date: 10/22/2003 pump used: I ~ther - See commentsj ... !... Pumping down I annulus. i ... I Hole Depth 12,221 Ft-MD 6,766 Ft-TVD /·1 Pressure IntearitvTest Mud Weight: 6.9 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 15.0 ppg 1009 psi 1.2 bbls 1·1 ;·I! EMW = Leak~off Pressure + Mud Weight = 1040 + 69 0.052 x TVD 0,052 x 2395 ' EMW at 3121 Ft-MD (2395 Ft-TVD) = 15.3 1 500 - UJ 0::: :::> V) V) UJ 0::: C. 500 o o 2 Barrels Comments: ~CASING TEST Used Hot Oil for pumping. PIT 15 Second Shut-in Pressure, psi 1070 ~ \ PIlI . PIlI ~ .-~ 3 4 5 o 2 4 6 8 10 Shut-In time, Minutes o PIT Point --- LEAK-OFF TEST I VOlum~ Input Barrels I 'Y I Casing Test Pumping Shut-in Bbls psi Min psi o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Volume Pumped Bled Back 0,0 Bbls _Bbls Pump Rate: I 'Y 0.5 Bbljmin ... Pressure Integrity Test Pumping Shut-in Bbls psi Min psi 0 100 0 1090 0.1 240 0.25 1070 0.2 400 0.5 1020 0.3 550 1 1000 0.4 680 1.5 980 0.5 790 2 9 0.6 880 2.5 9~ 0.7 930 3 950 0.8 990 3.5 950 0.9 1040 4 950 1 1060 4.5 940 1.1 1080 5 940 1.2 1100 5.5 940 1.3 1100 6 930 1.4 1110 6.5 930 1.5 1120 7 930 2 1110 7.5 930 2.5 1110 8 920 3 1120 8.5 920 3.5 1120 9 920 4 1120 9.5 920 4.5 1120 10 ÇI">r¡ 5 1120 --r Volume Pumped 5,0 Bbls Volume Bled Back Bbls Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: i 8-1/2" ! · Casing Shoe Depth RKB-CHF: 34.6 Ft 3,121 Ft-MD 2,395 Ft-TVD Casina Size and Description: 9-5/8" 36#/Ft J-55 BTC Changes for Annular Adeauacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. ) ) ConocóPhillips ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 8, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinJJ Waste on well CD2-51 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-51 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-51 approximately October 22,2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Information regarding wells within 'l4 mile not already on file at the AOGCC (CD2-58) Further details regarding wells on CD2 pad within 'l4 mile radius should be on file at the AOGCC. If you have any questions or require further information, please contact Vern Johnson at 265-6081, or Chip Alvord at 265-6120. ~IY, /., ~~/(./ ¿ ---- . Vern Johnson Drilling Engineer cc: CD2-51 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 RECEIVED OrT, 1 0 ';'Iorq \J 1_ u....... ¡Õ¡laska Oil & Gas Cons. Commission I~nchorage J:~IGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25,280 Operational shutdown D D Perforate New Pool D 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 36'/52.7' MSL ) D Repair well D D Suspend Pull Tubing 8. Property Designation: ADL 3800751 25559 1 372097 1 ALK N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 17320' 7108' 17320' Casing Length Size Structural Conductor 77' 1611 Surface 3085' 9.62511 Intermediate Production 1 321 0' 711 Liner Perforation Depth MD (ft): open hole completion from 13246' - 17320' Packers and SSSV Type: Baker S-3 pkr, Cameo DB Land Nipple 12. Attachments: Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name G. Alvord Title ß(, ()t( Signature Perforation Depth TVD (ft): 7128' - 7108' Packers and SSSV MD (ft): Land Nipple @ 2417', packer @ 12531' 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D WAG [] GINJ D 1 0/22/2003 Date: ) kOf ('/ .e>~ J~ /.ø- ~ ~ Plug Perforations Perforate D D Variance D Annular Dispos.[] Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: Stimulate 4. Current Well Class: Development D Stratigraphic D Exploratory D Service [] 202-249 6. API Number: 50-103-20441-00 9. Well Name and Number: CD2-51 10. Field/Pools(s): Colville River Field I Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 7108' MD TVD Burst Collapse 114' 114' 3121' 2396' 13246' 7128' Tubing Size: 4.511 Tubing Grade: L-80 Tubing MD (ft): 12626' Service [] Plugged D WINJ D Abandoned D WDSPL D Contact Vern Johnson (ã>. 265-6081 Alpine Drilling Team Leader Phone 265-6120 COMMISSION USE ONLY Date (0(1 (o!> Sundry Number: Conditions of approval: Notify Commission so that a representative may witness RECEIVED ~ \ OCT 1 0 2003 Subsequent Form Required: C \)~,~\\.. . T~{)O,\ e~",,,,~\(!),c:J\~~~~AI k O' & G C C' .: ,.;, '. 'r .. ~ as a I as ons, !1mn~i.s<'lI" Anchorage /~~ Date: /¡--V 03 Plug Integrity D BOP Test D Other: Approved by: .tJ ~_ /r <- ~ ) Mechanical Integrity Test D ß....~1 ~ ..30..3 -.3 / d-' Location Clearance D COMMISSIONER BY ORDER OF THE COMMISSION -"\ G\NAL ocr a u lOU3 ~Bft ) ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-51 b, The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c, A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No, 443, March 15, 1999) d, A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile, wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry, bbls, f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1910 psi. See operation and calculations showing how this attached calculation page, value was determined. g, Details that show the shoe of the outer casing is See attached cementing reports, LOT/FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. See attached casing summary sheet and calculation page. 1. Any additional data required by the Commission NA to confirm containment of drilling wastes. ) ') CD2-51 Pressure Calculations for Annular Disposal DETAILS: l- I- a> "C a> ro "C a> ro ..c::: a> ..c::: '00 '00 0. 0. 0 0 0 C) 0 0 c: N 0 '00 N ro + + Ü a:: a:: ëo "00 "00 Lõ 0. 0. I T"" T"" "L: c:i c:i ~ C/) C/) ro ro (!) (!) ... ....... .... .... .... ··tö"ë Z Z C) c: :.õ ::J I- = C) ~ T"" c: I "00 "::t ro Ü t-.. ~ L ~ {=9-5/8" 36 lb/ft, J-55 BTC casing @ 3121 ft MD (2395ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi Estimated Top of Cement @ 11941 ft MD (6636 ft TVD) (7" csg x 8-1/2" Open hole annulus) {=4-1/2" 12,6 lb/ft L-80 tubing to 12626 ft MD {=7" 26 lb/ft, L-80, BTC casing @ 13246 ft MD (7130 ft TVD) P collapse = 5410 psi, @ 85%: P collapse85% = 4598 psi ASSUMPTIONS: · Maximum injection pressure, P Applied = 1500 psi · Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft · Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied - PFormation Pmax = 12.0 (0,052) (2395)+1500 - 0.4525 (2395) Pmax = 1910 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MW max (0,052) (2395) + 1500 - 0.4525 (2395) MWmax = 20,7 ppg Maximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0,052) (6636) + 1500 - (0.1) (6636) - 2000 MWmax = 16,7 ppg ') I ) Possible Error Casing Detail 9 5/8" Surface Casing tDPHILLlPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jrs 3 to 74 Doyon 1 9 RKB to LDS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 72 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TD 12 1/4" Surface Hole RUN TOTAL 42 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - # 12 (On stop rings of Jt #1 & #2) 14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54,56,58,60,62,64,66,68,70,72 78 joints total in shed -74 joints total to run Last 4 joints stay out Use API Mod Best 0 Life Artie Grade Csg Compound. Remarks: Up Wt - _K Ibs Dn Wt- _K Ibs Block Wt 75K Ibs Well: CD2~51 Date: 3/13/2003 LENGTH 36.60 2.97 2992.58 1.52 85.66 1.77 DEPTH TOPS 36.60 39.57 3032.15 3033.67 3119.33 3121.10 3131.00 Supervisor: G.R. Whitlock/J. Jackson ') ConocoPhillips Alaska Cementing Report Legal Well Name: C02-51 Common Well Name: C02-51 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 3,121 (ft) Date Set: 3/15/2003 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: 45.00 Meas. From: 180 Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 336 (gpm) Mud Circ Press: (psi) Report #: Start: 1 3/12/2003 Cement Job Type: Primary Squeeze Casing Hole Size: TM D Set: Date Set: Csg Type: SQ TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Squeeze Open Hole Hole Size: SQ TMD: (ft) sa Date: sa Type: Cmtd. Csg: ) Page1öf 3 Spud Date: 3/12/2003 Report Date: 3/15/2003 End: 5/3/2003 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 160,000 (Ibs) Drag Down: 130,000 (Ibs) .__...._--_._---_._,_.,,-~._._.-.,_..__._-_.._---- Start Mix Cmt: 06:48 Start Slurry Displ: 06:40 Start Displ: 07:59 End Pumping: 08:37 End Pump Date: 3/15/2003 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 _....._."---_._,,-_.~--~.------_.._---------_.._..- Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.60 (bbl/min) 80.80 (bbl/min) Y 450 (psi) 1,200 (psi) 2 (min) Y Returns: 100 '7 ~:~~~~~~~ Ann Flow After: N Mixing Method: Density Meas By: Type: Spud Mud Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PVIYP: (cp)/ (lb/100ft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Mud Data Stage No: 1 Slurry No: 1 of 3 ---.-.-....-.---.-.-.---.---"'-..-..------.-.--...---.---.-....- ---,.----"._-,.__..._----..__..,,---~.._.._,,--,,--._--"------.-----,.--.-.,--.-- Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: 50.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Pressure (psi) (psi) Printed: 10/812003 5:19:08 PM ) ') Page2of3 ConocoPhillips Alaska Cementing Report Legal Well Name: C02-51 Common Well Name: C02-51 Event Name: ROT - DRILLING Spud Date: 3/12/2003 Report Date: 3/15/2003 End: 5/3/2003 Report #: Start: 1 3/12/2003 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Rig tank Desc~iPti r(~ite To: 2,621.00 (ft) Cmt V, 1:~90.0 bl) Slur : (sk) CI~S:~~~ Density: 10.70 (ppg) Yi d: 4.44 (~) Water Vol: 236.0 (bbl) Othe . r Purpose: FILLER CEME Mix Water: 200.13 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Temperature: CF) Temperature: (OF) Temperature: (OF) Stage No: 1 Slurry No: 2 of 3 - Additives _...,,__...,_,___.____.___.. ._.~._._.~.____..__.H_'..__._____._... ._____'h__.___'_H___"._~_.._'_..H....__._.____.._"_._M_.___. Trade Name Units Type FILLlTE GYPSUM ACCELERATOR DEFOAMER EXTENDER Concentration Units 50.00 %BWOC 30.00 %BWOC 1.50 %BWOC 0.60 %BWOC 1.50 %BWOC Liquid Cone. D-124 D-53 S1 D-46 D-79 -"--"._".",.,~,--_._.._-"._..- _.._'H_'_.__,_.____~'___".H""_' .,_,.,_....__.""'..,_,._.,___.._____.__._ Stage No: 1 Slurry No: 3 of 3 .__.._---_.__._..".._-.---_._-_.~--_._--.._- .._.._._...."..__u_,______n_n_._.____ Slurry Data Fluid Type: TAIL Slurry Interval: 2,621.00 (ft)To: Water Source: Rig tank Description~,Nófñíã1' ) Class: G 3,121.00 (ft) Cmt V9P.··"49.3 (bbl) Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) / ../ SIL~~~S~' Water Vol: 29.0 (bbl) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: TAIL Mix Water: 5.09 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temp (OF) (OF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Stage No: 1 Slurry No: 3 of 3 - Additives __.__________"_.__m_______.. -----..- ----.-- Liquid Cone. Trade Name Concentration Units 0.20 %BWOC 0.30 %BWOC 2.00 %BWOC Units Type DEFOAMER DISPERSANT ACCELERATOR D-46 D-65 S1 Printed: 10/812003 5:19:08 PM ) ConocoPhillips Alaska Cementing Report Legal Well Name: C02-51 Common Well Name: C02-51 Event Name: ROT - DRILLING Report #: Start: 1 3/12/2003 Casing Test Shoe Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Log/Survey Evaluation Interpretation Summary CBl Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: __.__.___~..___________,_,_ "._...__,,",. _,_.,., 0" " .____......" .,_._.__.._._. _,_ ..._'WO. "N _..._....___ __" __.....__.___........ "_'''''_''___''_ _, _._.____"".__." ...,."_..".. _ .._ on'.' ...___.__.... _._____._,.,_ __ ') Pa.ge 3 of 3 Spud Date: 3/12/2003 Report Date: 3/15/2003 End: 5/3/2003 Liner Top Test Tool: Tool: -- .- -.......-.-. --....--.-.-.--...--.... .-..-.-..-,.,----..--...---....-...-- -,._--- Printed: 10/812003 5:19:08 PM ) ) Page 1of2 ConocoPhillips, Alaska Daily Drilling Report 1 JOB NUMBER 1 EVENT CODE 124 HRS PROG TMD I TVD I DFS I REPT NO. 1 DATE C02-51 OOR 3,131.0 2,401.0 4.00 4 3/15/2003 S~~::~~~k I J. Jackso.!L 1 ~~yN:n~E~:~~~º____ºQïº_OJ_~____t~~~~~~:E ~~p~~:o. AU~;,~~1.0 I DAILY TAN~ 1 CUM. TANGO CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD """FORECAST - ~~QP.L . .-- .... ..~...... ·íìATEOFWi-SAFETYMEE11NG ¡;AI':YroTALº-·---CìJMCOsTwI~UD :~~;;::~;~:~fiæt:~E.:"~:~~~}ï~~i;;:I~~~:ft)I~~¿:::::~~~::::D::~~ST DENSITY(ppg) l-n-9~90------r pp-r---------- I ECD I---'MU D DATA I DAILY COST I 0 I CUMCÖST I 0 FV PVIYP GELS WL/HTHP FCIT.SOL OILIWA T %Sand/MBT Ph/pM Pf/MfCI Ca H2S LIME E$ 74 18/23 6125 8.61 21 I 0.3/25.0 8.61 0.05/0 40 OPERATIONS SUMMARY PHASE SURFAC Finished R/U to run casing. SURFAC PJSM - run 9-5/8" surface casing. SURFAC Ran 74 joiints 9-5/8" 36 ppf J-55 BTC casing with float shoe, float collar, and FMC Gen V hanger. Installed total of 44 centralizers on casing string. No hole ____________________ _______ ______ __ _____ ______ ___ _ __. ,_ ,,_ _ P!~_~!e._'!1~:£"~~~!~_~_~~_~~_~~_!'_ ~g.! float collar at 3032' MD. _~~!~__Q§.:_~_~___,.J..:_Q2_,_g,~~§!'J~_~____ CIRC SURFAC Circ_u.lated 1 x_,~~sing volume while n~ci.Prg~~~'~H_~~!~_!L___________.____. __05:_!~.. _ 05:~_ 0 .50 CEM ENT P RU RD ___ S~.!3f:~º_Btl2_E.~~.~.~~_~~~~~_~_~__!3!_~._~_e.,~,~_~~!,~~J1_ead and line~~________.______,_________________ 05:45 06:30 0.75 CEMENT P CIRC SURFAC Continued circulating and conditioning mud and hole. Held PJSM - cement __________________ ______ ___,~:_~!~,':.~~,~i!:1.~_____n__ __ ___ ______________.___________,_,.__________,_,______________ 06:30 08:45 2.25 CEMENT P PUMP SURFAC Pumped 40 bbl. viscosified fresh water. Tested cement lines to 2500 psi. Dropped bottom plug. Pumped 50 bbl. Mudpush spacer mixed at 10.5 ppg. Pumped 390 bbl. (493 sks) ASL31ead mixed at 10.7 ppg). Pumped 49.3 bbl. (237 sks) 'G' wladditives tail mixed at 15.8 ppg. Dropped top plug. Displaced cement with 234 bbl. Bumped plug and checked floats - OK. 180 bbl cement returned to surface RURD SURFAC RID cementing head and lines. Backed out and LID landing joint. UO extended bails. Cleared and cleaned rig floor. SURFAC Flushed riser. N/O riser and adaptor. SURFAC N/U FMC unihead. Tested to 1000 psi. SUSPEN N/U BOP. SUSPEN Installed BOP test plug. Body tested BOP and wellhead adaptor to 3500 psi. Removed BOP test plu~:_ ________.___.._ _________ ~1¿~1:)__§l¿~~_~_~ l~s!~~~~~~~_~Eushi~~_____ ________________ ______ PULD SUSPEN RIH then UD tubulars from derrick including 5 stands HWDP, 22 stands 5" OP, and 51 stands 4" DP. WELL NAME FROM TO 00:00 00:15 00:15 00:30 00:30 04:15 HOURS 0.25 0.25 3.75 CODE CASE P CASE P CASE P TROUBLE SUB RUNC SFTY RUNC 08:45 10:00 1.25 CEMENT P 10:00 12:00 2.00 CASE P 12:00 12:30 0.50 CASE P 12:30 14:00 1.50 ABANON X 14:00 14:45 0.75 ABANON X .--- --------- 14:45 15:00 0.25 ABANON X ----~,.._-- ,,-,---_.- ....- .---. --- ----,-.---.- 15:00 00:00 9.00 ABANDN X -------~-.__._-. . NUNO NUND NUNO NUNO ~'!~_~~l.J~_I\II_~_~v:: Finished runni~~ and ceme..nti~~~-~/~''.!ur!~~~ ~~~~9.-._B__ega!!.!.e.rn2..E~é1'Y.s_u.~..e~~i_~~~f._~~I~ _ _____ -.---..---------- --------------~ -c~~~~~~~:~:~'f~~panyr----- SERVIC..E - Doyon ! I MI I DSR DESCRIPTION -- ._- ..-. -,-_.,----_.,~--- ------- -- -_.._~_.._----'_._..-_._-----~_._----_._--_._._---_._--,-_._- '-'-.-'--- -,-' '------,-------...----.---. -- -- PERSONNEL DATA NO. 2 H~~~~-~D~~ell--~~~~~~Y 26 AC 3 IFMC 4 I SERVICE NO. HOURS -- .---.--.----- -------,-- 2 5 1 Printed: 10/812003 5:29:54 PM ') ) Page 2 of2 CD2-51 ConocoPhillips, Alaska Daily Drilling Report I JOB NUMBER I EVE~TDC~DE 124 HRS PROG 1 T~~131.0 IrvD I DFS 2,401.0 4.00 1 REPT NO. IDA TE 4 3/15/2003 WELL NAME MATERIALS I CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS Fuel gals 2,545 -9,891 Water, Potable bbls Wa~!.~, Drilling __________ ___,_,____.P.!?~___________.___1.!.Q.~Q_,_______,_~!_~~~___~,__________________",____________ _____ USAGE 120 ON HAND -480 _..-._-----_..~..._._.._-~-----_.......__.__._----_...._,-. RESERVOIR NAME CD2-22 RESERVOIR AND INTERVAL DATA ZONE TOP BASE CD2-51 2996 4 1490 COMMENTS _____w,,·_~__...__··,,·__,_,,___.__"·__,··__·___·_·_'_·_,._~_...____._.,_.,,_...'._.,. - "....---..-- - ._-,-", -".-".-...."...----....- -~-- . -, - - ~--_._,.,-~_...._-,--_._".._'"'-"._-_..'._._._" --.----------.-.-.. Printed: 10/812003 5:29:54 PM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Doyon 19 I Date: 4/16/2003 I Pump used: I #1 Mud Pump \.... Well Name: C02-51 I Rig: Drilling Supervisor: G.R. Whitlock Type ot Test: I Casing Shoe Test LOT/FIT Hole Size: 18-1/2" I... Casing Shoe Depth RKB-CHF: 32.8 Ft 3,121 Ft-MD 2,395 Ft-TVD Casina Size and Description: 19-5/8" 36#/Ft J-55 BTC Casina Test Pressure IntearityTest Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg Mud 10 min Gel 23.0 Lb/100 Ft2 Mud 10 min Gel: 23.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight: 125,000 Lbs Rotating Weight 125,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs Desired PIT E~ 16.0 ppg Estimates tor Test: 2,1 bbls ["'1 ~EstimateS7Test: . 797 psi 0.7 bb~ EMW = Leak~off Pressure + Mud Weight = 800 + 9 6 / PIT 15 Second 0,052 x TVD 0.052 2395' Shut~in Pressure, psi EMW at 3121 Ft-MD (2395 Ft-TVD):.. 16.0 ppg 800 ... Pumping down annulus and DP. Hole Depth 3,151 Ft-MD 2,410 Ft-TVD 1...1 3000 - "- 2500 - 2000 - w 0:: ~ en 1500 - en w / c::: a.. 1000 - ~CASING TEST Comments: - Lost 0 psi during test, held 100% - =cl~~pre~ure. - ~L,^"lbltJ 1 1 1 A ~~ 2 3 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Barrels ~LEAK-OFF TEST I Volume Input Volume/Stroke ... Casing Test Strokes ... 0.1000 Bbls/Strk ... Pressure Integrity Test Pumping Strks psi o 0 4 400 8 900 12 1200 16 1550 20 1900 24 2300 27 2600 Volume Pumped 2,7 Bbls Shut-in Min psi o 2600 1 2600 2 2600 3 2600 4 2600 5 2600 6 2600 7 2600 8 2600 9 2600 10 2600 15 2600 20 2600 25 2600 30 2600 Volume Bled Back 2.3 Bbls Pumping Strks psi o 0 2 '\.D 100 4 ~ c 300 6 .)'òè 500 8 \C\t {DO 10 -"'800 Volume Pum~ed 1.0 -abls Pump Rate: 0.2 Bbl/min . Shut-in Min psi o 800 0.25 800 0.5 800 1 800 1.5 80C 2 775~ 2.5 750 3 750 3.5 750 4 700 4.5 700 5 700 5.5 675 6 675 6.5 675 7 675 7.5 675 8 650 8.5 650 9 650 9.5 650 10 65'- ~ Volume Bled Back 1.0 Bbls ) ~ ConocoPhillips Casing Detail 7" Intermediate Casinq Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 314 Doyon 19 RKB to LOS FMC 11" X 7" Hanger 312 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Float Collar 2 Jts 7" 26# L-80 BTCM Csg 7" Weatherford Float Shoe Jts 1 to 2 ! Straight blade centralizer on first 26 jts. 3 straight blade centraliers 1/jt on jts 241,242,243 34 straight blade centalizers every other jt on jts 245-311 Total Centralizers: 63 ) 7" shoe @ 8-1/2" TO 340 joints on rack - 314 total jts. to run 1 last 26 joints stay out Use Best-a-Life 2000 pipe dape Remarks: Up Wt =300k On Wt =175k Block Wt= 75K Supervisor: Mickey / Jackson Well: C02-51 Date: 4/19/2003 LENGTH 34.60 1.61 13121.07 1.32 85.70 1.47 DEPTH TOPS 34.60 36.21 13157.28 13158.60 13244.30 13245.77 13256.00 ) ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-51 Common Well Name: CD2-51 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 13,246 (ft) Date Set: 4/26/2003 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Report #: Start: 2 3/12/2003 Cement Job Type: Primary Squeeze Open Hole Hole Size: SQ TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TM D Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Cmtd. Csg: ) Page1of3 Spud Date: 3/12/2003 Report Date: 4/26/2003 End: 5/3/2003 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: No movement RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) __.__.,____..,,__._._.__.__..__..~______~.._.___.__.,_~.____."40."..__._._.__._...____.,..·_......_._,_......._.. Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 273 (gpm) Mud Circ Press: 760 (psi) Start Mix Cmt: 06:41 Start Slurry Displ: 06:41 Start Displ: 06:51 End Pumping: 08:22 End Pump Date: 4/26/2003 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 _._._.__R"'_..___._'"____.~,.____ Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbllmin) 7.00 (bbl/min) N 810 (psi) (psi) (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 350 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PVNP: 11 (cp)/16 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 484.00 (bbl) _~,__,_·_·~___·_~_,_'."_·'_'_.._n_'_·_'__.__.__._"'_ Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry No: 1 of 3 ---_._-"'.~_..__.,_. ,.-----.-..--'----------- . . - -- ... -- .- - ---.- ..-----.----.--.-----------..----..--.---- To: (ft) Description: ARoc wash Cmt Vol: 20.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: CF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Flush Mix Water: (gal) Foam Job: N Temp CF) (OF) Pressure (psi) (psi) Printed: 101812003 5:15:09 PM ') ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Legal Well Name: C02-51 Common Well Name: C02-51 Event Name: ROT - DRILLING Report #: Start: 2 3/12/2003 Spud Date: 3/12/2003 Report Date: 4/26/2003 End: 5/3/2003 Stage No: 1 Slurry No: 2 of 3 ----"..._-------- Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No· 1 Slurry No: 3 of 3 -------~i7----------- Fluid Type: TAIL Descriptiqf1~\ ,ii ;/ Slurry Interval: 13,246.00 (fI)o: 12,221.00 (ftJ:;mt Vr' 36.0 (bbl,)/ Water Source: lake water Slurry 01:173 (,J<)' / _>/1 Test Data - Thickening Time: 2.57 Temperature: 160 (OF) Free Water: (%) Temperature: (OF) Fluid Loss: 23.0 (cc) Temperature: 130 (OF) Fluid Loss Pressure: 130 CF) Slurry Data Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 21.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No: 1 Slurry No: 3 of 3 - Additives Trade Name Type Concentration Units Liquid Cone. Units water D-46 D-65 0167 B155 fresh DEFOAMER DISPERSANT 5.10 G P S 0.20 %BWOC 0.25 %BWOC 0.40 %BWOC 0.02 %BWOC GAL Printed: 10/812003 5:15:09 PM ) ) ConocoPhillips Alaska Cementing Report Page 30f 3 Legal Well Name: C02-51 Common Well Name: C02-51 Event Name: ROT - DRILLING Report #: Start: 2 3/12/2003 Spud Date: 3/12/2003 Report Date: 4/26/2003 End: 5/3/2003 Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.50 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: --_._._.".._".__._-,_._,--,._._._----~..._._--_...__._--,--."-.-------.-"---- ---.-------".-.--.- Remarks ._,._,_._-_.._._..~,-------- Cement 7" casing - pump 5 bbls Arco wash @ 8.3 ppg - Test lines to 3500 psi - Pump 15 bbls Arco wash - Mix & pump 50 bbls Mud Push XL @ 12.5 ppg - 5.25 bbls/min @ 800 psi - drop bottom plug - mix & pump 36 bbls slurry (Class G wI 0.20% 046, 0.25% D65, 0.40% D167, 0.020% B155) 36 bbls (173 sks) @ 15.8 ppg - 5 bbls/min @ 850 psi - drop top plug wI 20 bbls water fl Dowell - switch to rig pumps & displace wI 484 bbls 9.6 ppg mud @ 6 bbls/min @ 490 psi for 383 bbls - increase rate to 7 bbls/min @ 730 psi for 71 bbls - slowed pumps to 3 bbls/min for last 30 bbls 470 psi to 810 psi - Shut down - didn't.Q~mp plug - Bleed off pressure - floats held - CIP @ 0822hrs. - full circulation throughout job ---...::::::, Tagged top of cement @ 13.068' - 89' above top of FC - 3.4 bbls vol. - total vol. cement in casing 6.5 bbls - cement vol. outside casing 29.5 bbls - calc top - 11,941' '\. * NOTE - Rig pumps had 5 1/2" liners used 97% as efficency - actual 95.8% Printed: 10/812003 5:15:09 PM ') ) Page tof 2 ConocoPhillips, Alaska Daily Drilling Report I JOB NUMBER I EVEONTDCRODE 124 HRS PROG TMD I TVD I DFS CD2-51 13,256.0 7,131.0 22.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG _po Mickey I J. Jackson doyon1@.P-J~co~~___ _Q-ºy-ºn 19 _ Alpine _,J7,071.0 _ 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD ____________'_____'____'____'___B!!::!~!JL1'_ª~_ª_~~~_'!1Q!Y_______ _, ________ _______ ,________________ ____ ________ 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Drill cement and FE. Conduct FIT. Drill 6-1/8" hole. 4/21/2003 418,318 LITHÒï.O-Gy----------------=__~~---"-------~_:_~E::FÙiRSOF-SERVïcë--¡-ŠHA- HRS-SÏÑ-c~·ïNSP--I-LEAKOF~~~~--------·'AFE ------1 00279~~------- AUTtt LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 4/24/2003 13.!.ºª-?&:L_______ 76.790 ____ 138.26Q..___ --'z:º_º_º__(Ll]t@,___,_J,ª_!£4§.:.9 (ft) 4.500 (in) @ 12,632.0 (ft) 4/26/2003 DENSITY(ppg) -1-0:ÓÜ---- -I-'pp-T 'I-Ëcõ-f1Ò:9ÜfMUC--CATATI)AÎLy-cosr-r '-------(j----- -------1 CUM COST 0 FV PVNP GELS WL/HTHP FC/T.SOL OIL/WAT %Sand/MBT Ph/pM Pf/Mf CI C~ H2S LIME 40 11/18 8110 6.81 21 I 0.1/17.5 8.71 0.05/0 60 WELL NAME 1 REPT NO. IDA TE 22 4/26/2003 I CUM. TANGo _______ CUM INTANG WI MUD o CUM COST WI MUD 3,736,376 ES BHA NO. I 4 I BHA WT. BELOW JARS STRING WT. UP BHA I HOLE CONDITIONS STRING WT. DN STRINGWT. ROT BIT NO, I 3 BHÀLENGTH 381.80 CONN SIZE CONN TYPE TORQUE I UNITS ft-Ibf ITEM DESCRIPTION NO JTS LENGTH O.D. I.D. Bit 1 0.75 6.125 1.500 Mud Motor 1 34.50 4.750 2.794 -_._-"',_._---_._--,--".~----~,-,.__.._---~-_._--~.._-----.--.------..-------------.-.-- ..--"..-..----- --.--....-. ._.,_._-----~-~"._...._.._,----~._----''''.._--------- ,..--.--.....---,...,--.-....- Adjustable Gu~~~_~~é3:~~!~_~~~,__,________________ ____ ____ ,.__, ,_,1_ .______________1-º_:.??______n___~.__~~9 __ ___ _ ______.?.}50 ___,_________________________ Sub - Float 1 2.00 4.750 2.250 ___,______.___...___..__...____..____ '__' ....,_."_.~ ,.._._.__.__~.._____.._...__.___.".~ ..._..~ "._..____.. _____...__u..~.__.....u__.u__._"_ _.____.._., ___..__._ _ ._, _._,_...._,_. .,___,.... ....... ,._,.__.._..__.__.___. ___. __.._._._.__.._______h_· ____._._____.._._ MWD 1 24.45 4.750 1.250 ____.__.___ _'_h___ _~_._.,_ __._"._ .__...,,_ .... ___ _ _ .. _. _._._..._._,,_.__..._._ .___. __ _ .__, .~_..._.__~.._. ..._._.. ~,_ ____._____ _...__.,,__. __.._ MWD 1 8.55 4.720 1.250 __.___.._...... .._~...__._..__._.__.....__.........__,_._._._ _..._.__"._....._....___...._.._..._..__ ____... _ ______ ..__u._.._..".. _ _ ._ __.__"...__,_._._.",__ _.._...____._,,__.._..__. ____.__._,.__~_____m___..__·,·__.___··_·_ MWD 1 10.81 4.720 1.250 _..._--._~._-,.._._.._-,..._.._"_..,._-',,.,-_.,. .-.---.. . -------...-...-- - --. -----.....---.---.-.----...--..-".. . .-. .....--....---....__.....~..-. - --..--..,...---------- -..-.----.-...--,-.-----.....---.----..--.-----.-.-.-- ~~~~_!::I~r~ILQ!f__,________ _, __________._____ n __ ________ _ _,_______~___ ,___., ,__~~__: !~_ __'n___n_~~ 73~___ ____n n_ __!:?§.Q____,__________________ _,___ Flex Joint 1 31.20 4.750 2.250 __......,__~._._____.__,_____."._..__.... _ U'_' .._ ._ __~. ._.._.__._._._.. .._.__.__.____.__ _._._.".__..._.._"'_.". _ ._. _'__...___ _______,.__ ..__. _______.__ __' ... ..__._._.~___.._____.__..____ Flex Joint 1 30.44 4.710 2.250 --.--.,-.--...-----..--- - ... - -.- . -.- . ----- -...- ..--...--.--.-.-., ,,---_. - ....- ,- -_.--,.._-...."_.-,, -----.-- .--.. .---------- Flex Joint 1 31.05 4.650 2.250 Crossover 1 1.13 4.750 2.310 Drill Pipe - Heavy Wgt 3 92.07 4.000 2.563 Jars 1 32.12 4.750 2.000 Drill Pipe - Heavy Wgt 2 61.36 4.000 2.563 ------- -------------- BIT I RUN 31 4 SIZE MANUF. 6.125 SMITH BITS TYPE SERIAL NO. JETS OR TFA M285YPX JT0332 12/12/12/12/13/13 DEPTH IN DATE IN I·O·D·L·B-G~O·R 13,256.0 4/26/2003 O-O-NO-A-D-I-NO- TD BIT I RUN BIT OPERATIONS n___~~!___,__L_~~_~____,J_~~~L,__~~_~~s.____L_.!...~!..J___~~!_____1.24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP FROM TO 00:00 01 :30 OPERATIONS SUMMARY HOURS CODE TROUBLE SUB PHASE ----.-- -,----,,-,_.- --_..._-,,-- . ------.. .--.-.".- .------- ..--..--- 1.50 CASE P RUNC INTRM1 DESCRIPTION .~ -~~---_._-.- --.-------...----..---- . Continue running 7" 26# L-80 BTCM casing to 13,209.51' - 314 jts total ran- PU hanger & landing jt. - land 7" casing in wellhead on FMC fluted mandrel I hanger wI shoe @ 13,245.72' & FC @ 13,157' '-INTRM 1 P::o fill-UP tOOI&csg to~gs -- R-lT œ~e~th~;d- ---- ----- ------- INTRM1 I Circulate and condition mud for cement job - Lower YP to 16 - Mud wt. rfl 10.0 ppg to 9.6 ppg - stage pumps slowly to 6.5 bbls/min @ 760 psi INTRM1 i Held PJSM for cmenting 7" casing INTRM1 I Cement 7" casing - pump 5 bbls Arco wash @ 8.3 ppg - Test lines to 3500 psi - I Pump 15 bbls Arco wash - Mix & pump 50 bbls Mud Push XL @ 12.5 ppg - 01:30 02:00 0.50 CASE P NUND 02:00 06:00 4.00 CEMENT P CIRC 06:00 06:151 0.25 CEMENT P SFTY I CEMENT P PUMP 06:15 I 08:30 I 2.25 I I I I I Printed: 10/812003 5:21:31 PM ') ') Page2of2 CD2-51 ConocoPhillips, Alaska Daily Drilling Report I JOB NUMBER 1 EVEONTDCRoDE 124 HRS PROG I TMD I TVD 13,256.0 7,131.0 IDFS 22.00 I REPT NO. IDA TE 22 4/26/2003 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 06:15 08:30 2.25 CEMENT P PUMP INTRM1 5.25 bbls/min @ 800 psi - drop bottom plug - mix & pump 36 bbls slurry (Class G wI 0.20% D46, 0.25% D65, 0.40% D167, 0.020% B155) 36 bbls (173 sks) @ 15.8 ppg - 5 bbls/min @ 850 psi - drop top plug wI 20 bbls water fl Dowell - switch to rig pumps & displace wI 484 bbls 9.6 ppg mud @ 6 bbls/min @ 490 psi for 383 bbls - increase rate to 7 bbls/min @ 730 psi for 71 bbls - slowed pumps to 3 bbls/min for last 30 bbls 470 psi to 810 psi - Shut down - didn't bump plug - Bleed off pressure - floats held - CIP @ 0822hrs. - full circulation _______________________________________________'_m____ through~~:~ -- 08:30 09:00 __º:~_º_..__º~~~~_IJ:>_____________.!3~~g_,_____l~!~_~_!_,_~_º-_~~.~_~~t head & landing jt. ,___________'___m____._'_____ 09:00 10:00 1.00 WELCTL P OTHR INTRM1 Pull thin wal wear bushing - set & test 9 5/8"x7" pask off & test to 5000 psi 10:00 12:00 2.00 WELCTL P OTHR INTRM1 Set test plug - change top pipe rams f/7" to 31/2" x 6" VBR 12:00 16:00 4.00 WELCTL P BOPE INTRM1 Test BOPE - Hydril to 250 & 3500 psi - pipe rams, blind rams, kill & choke line valves, choke manifold valves, IBOP's - floor valves to 250 & 5000 psi- Performed accumlator closure test - Test witnessed & approved by Chuck Scheve AOGCC Pull test plug & set wear bushing PULD INTRM1 PU drilling bales & DP elevators PULD INTRM1 M/U 6-1/8" BHA. P/U bit and motor and adjusted motor to 1.15 deg. P/U and oriented MWDLWD. P/U PWD and TM. Uploaded MWD. P/U 3 x flex collars, __ __,__________ ___m_____ _,____________ __ __ ____ ____n__n__ "__n_ !.'()~~,~_,~~_D P, ja r, a_~~__~_x._!::!yy~~:.. _____________________ .__,___________________._____.__,_..__ 20:00 00:00 4.00 DRILL P PULD INTRM1 P/U 4" drill and RIH. 16:00 16:30 16:30 20:00 0.50 3.50 DRILL P DRILL P ---'~-~" -----.."..--..-..--,----. ..'" ---. -, -----,..- ----,...--.....-.".-..--..,- ,----.,-------.-.- .--.--.-.---...-..-...--- .____ ...____,__~__~____..__.__,..,., ,_ .~_, ...,'.__.....,__, ,k,..__".._..,." ,_,_.'____ _._.. ..,..".__,~_. __".__ '__R'._~ -.....,.--..----------.--.------- _~.!_!i_~_ª__~_~~~~X~~J_~~Sh.r~~~i_r1~_T'.c::~9_::. qir_c, ~c::!:)r1~.:_~f.~!1]_~r1! !"___-_~~t__~ !~~! _p_~c::~.!:>!!~_F3~_~_t~~tª~_~_~..~_~...?.::'!i8~~_ª_~_ ----..---------..---..--.....-.-.-.-.,..-.----.------.---~-----_._.,--_._---_.._.,.,_.. ________ PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY __.__,..._._...____u..._________.____.__.._____.___..... _...._"._._,_...___ ,____.__.._ _______ _º-~~~_~~~~!I~ip.~º!:)'!1J?~r1~ 3 AC Doyon 25 Sperry Sun MI 7 Columbia Dowell 2 Epoch ____ - 0" __..n"'.'_'_ SERVICE NO. HOURS 5 ..-. ...----..,--,..--.-----..-.---------.----.-- 4 1 2 ITEM UNITS gals bbls USAGE 1,350 1,190 MATERIALS I CONSUMPTION ON HAND ITEM -37,758 Water, Potable -15,535 UNITS bbls USAGE 120 ON HAND -2,135 Fuel Water, Drilling RESERVOIR AND INTERVAL DATA RESERVOIR NAME ZONE TOP BASE COMMENTS ------,-,,--.- -,-,-----~._--_._--,---- ..._--,_.----_._----..,~-.._._-- "----..- _._---,.._._-,~_.._- "-.-...---...------- CD2-46 CD2-51 1235 3.5 1440 - -_._---~-'._.._-------- - ~-.._- - ... -..--"'. -- -'. --..---.,--.--,..--------'.- - .'. ,-.------- Printed: 10/812003 5:21:31 PM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Doyon 19 I Date: 4/26/2003 pump used: I Cement Unit I... Well Name: C02-51 I Rig: Drilling Supervisor: Don Mickey Type of Test: I Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" l... Casing Shoe Depth RKS-CHF: 34.6 Ft 3,121 Ft-MD 2,395 Ft- TVD CasinQ Size and Description: 19-5/8" 36#/Ft J-55 BTC Chanqes for Annular Adequacy Tes Enter outer casing shoe test result~ in comments Casing Description references outel casing string Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. I Volume Input Pump Rate: 0.5 Bbl/min ... ... 'Y Barrels Bbls/Strk Pumping down annulus. ... ... Casing Test Pumping Shut-in Bbls psi Min psi Pressure Integrity Tes1 Hole Depth 11,941 Ft-MD 6636 Ft- TVD 1...1 Pumping Bbls psi o 0 0.9 21 1.7 79 2.4 144 3.2 220 3.9 300 4.7 333 5.4 450 6.2 527 6.9 544 7.7 561 8.4 663 9.2 632 9.9 553 10.7 517 11 450 Shut-in Min psi o 450 0.25 452 0.5 452 1 450 1.5 449 2 449~ 2.5 451 3 450 3.5 449 4 447 4.5 445 5 443 5.5 442 6 440 6.5 440 7 440 7.5 440 8 438 8.5 435 9 436 9.5 433 10 43~ Pressure IntegritvTes1 Mud Weight: 9.6 ppg Inner casing 00 7.0 In. 13.8 ppg 523 psi Desired PIT EMW: Estimates for Test: 0.6 bbls [·1 EMW = Leak-off Pressure + Mud Weight = 663 + 9 6 0.052 x TVD 0.052 x 2395 ' EMW at 3121 Ft-MD (2395 Ft-TVD) = 14.9 ¡. PIT 15 Second Shut-in Pressure, psi 452 1000 . w 0:: :J UJ 500- UJ w 0:: a.. -.-~, .----- o. o 4 6 10 Barrels ~CASING TEST ~LEAK-oFF TEST 12 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Volume Volume Pumped Bled Back 0,0 Bbls _Bbls Volume Volume Pumped Bled Back 11,0 Bbls ___ tibls 16.3 ppg FIT Comments: 1/4 Mile Radius of CD2-51... 9-5/8" Csg Pt (@ 3119MD /2395' TVD) - I -- ToMD 250 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5500 6500 7500 8500 9500 1??oo 10500 11000 11500 12500 13500 From Colour o 250 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5500 6500 7500 8500 9500 1 ??oo 10500 11000 11500 12500 Reference Azimuth Angle [deg] vs Centre to Centre Separation [ft] 180 1320 90 -1320 -1238 -1031 -825 -619 -413 -206 CD2GBtœJ. -0 -206 -413 -619 -825 -1031 -1238 '~1320 .....- iJ.lU Rig: ~>M'SL9 52.00011 Ref. Datum: V.Section ~~~ ~~ ~~~ Angle 129.896· 0.000 0.000 0.000 Calcu1ation MeLhod: Minimum Curvature Šc~r ~~~ k~::ra1 Plane Error Suåace: Elliptical + Casing Warning Method: Rules Based o Interpolation MethodMD 1nterval: 1.000 Depth Range From: 3109.000 To: 3139.000 Maximum Range: 1320.000 Reference: Definitive Survey ConocoPhillips Alaska Inc. Engineeñng KuparoJc 5974283.88 371734,28 70'20'16,7131' 151'02"26,793W 1'/A longitude Slot lalilude E.J:sting WELLPATH DETAILS CO2-51 ANI1-COLUSION SETIlNGS COMPA."IY DETAILS WELL DETAILS 1'orthinS -FJ-W 44.160 CD2-5~357.106 Name ·~/-S ) ) SURFACE CASING SHOE SEPARATION FROM CO2-51 CO2-51 x y Surface Casing Shoe ASP 4 Coordinates: 373114.02 5973411.81 Ulstance Details from Surface csg. Surface csg. @ Ann. Object Shoe X Shoe Y Wells AOGCC Permit # Perm it Date Source well Vol. **** Start Date End Date we 11* Coord. Coord. CD2-35** ---- ---- --- --- ---- 1005 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 y 301-140 6/1/2001 CD2-15 33992 6/1/2001 10/10/2001 2098 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 y 301-186 7/13/2001 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 2808 370630.11 5974721.81 CD2-33 B*** ----- ---- ----- --- ---- 2996 370155.64 5973886.23 ./ CD2-39 y 301-281 10/9/2001 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 795 372350.61 5973633.17 CD2-14 y 301-288 10/9/2001 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 1797 372202.47 5974960.87 CD2-15 y 301-308 11/6/2001 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 2771 370832.00 5974984.02 CD2-47 y 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 1886 371231.72 5973294.19 r-/ CD2-45 y 301-345 12/13/2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 563 372765.13 5973853.74 CD2-34 y 302-069 3/4/2002 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 1666 371803.06 5974439.79 CD2-26 y 302-068 3/4/2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 1743 371798.52 5974554.55 CD2-49 y 302-070 3/4/2002 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 1973 371252.38 5974065.93 CD2-17 y 302-122 4/10/2002 CD-48, CD2-08 18181 5/29/2002 2/7/2003 1821 371774.00 5974645.00 CD2-32 y 302-119 4/30/2002 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 2025 371295.61 5974302.38 CD2-41, CD2-19, CD2-16, CD2-50 y 302-121 4/30/2002 CD2-38 32000 7/24/2002 9/7/2002 1663 371665.21 5974227.65 CD2-25 y NA 1857 371594.00 5974479.00 CD2-46 y 302-273 9/20/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 1680 371694.80 5974310.85 CD2-22 y 302-274 9/20/2002 CD2-08, CD2-36, CD2-51 31253 2/7/2003 3/16/2003 1840 371678.61 5974562.30 CD2-28, CD2-35a, CD2· CD2-48 y 302-275 9/20/2002 45, CD2-08 32000 12/10/2002 2/4/2003 1517 371631.74 5973736.14 CD2-19 y 303-083 4/28/2003 CD2-58, CD2-52 31337 5/19/2003 6/27/2003 1516 372284.88 5974681.33 CD2-41 y 303-081 4/28/2003 CD2-20, CD2-55 24037 6/27/2003 7/28/2003 1189 371990.58 5973802.52 CD2-23 y 303-080 4/28/2003 NA 0 2677 371013.17 5975070.46 CD2-16 y ---- --- ".--- --- ----- 1525 372460.34 5974790.01 v' CD2-38 y 303-082 4/28/2003 CD2-40, CD2-30 30011 7/28/2003 8/17/2003 1086 372033.86 5973527.13 CD2-44 y --- --- ".--- --- ---- 1416 372034.57 5974328.53 CD2-29 y 303-249 8/25/2003 NA 0 1554 372652.44 5974896.02 CD2-13 y ----- ---- ---- ---- --- 2417 372658.78 5975785.31 CD2-37 y --- --- ----- ----- ---- 1635 371569.79 5972874.47 CD2-28 y NA 0 1638 372139.80 5974728.95 CD2-08 y ----- --- ------ --- --- 2239 372655.88 5975603.76 CD2-36 y NA 0 1272 371848.22 5973535.38 CD2-51 NA 0 0 373114.02 5973411.81 CD2-12 y NA 0 2883 371071.29 5975445.60 V' CD2-58 NA 0 1262 372102.03 5972657.80 ../' CD2-52 y NA 0 538 372637.61 5973661.63 CD2-20 NA 0 2729 371366.14 5975507.11 CD2-55 NA 0 2008 371118.23 5973194.84 CD2-40 NA 0 2453 370691.67 5973801.44 CD2-30 NA 0 2656 370465.55 5973612.54 CD2-18 NA 0 2453 370691.40 5973797.38 CD2-06 3022 371613.86 5976035.44 * Lateral distance in feet, between surface casing shoes, in the X- Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 8/17/03 Weir Name: Drilling Supervisor: I Rig: Don Mickey PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 5/31/2003 I Pump used: I Cement Unit /.... CD2-58 Type of Test: Annulus Leak Off Test for Disposal Adequacy .. Pumping down annulus. Hole Size: 8-1/2" .. Casing Shoe Depth I I RKB-CHF: 34.9 Ft 3,055 Ft-MD 2,385 Ft-TVD CasinQ Size and Description: 19-5/8" 36#/Ft J-55 BTC Chan~es for Annular Adequacy Test Enter outer casing shoe te~ 9.6 in comments Casing Description re1eren< 23.0 casing string. Hole Size is that drilled bel· 2,550 casing. Use estimated TOe for Ho 125,000 Enter inner casing 00 at right. 75,000 Hole Depth 11 ,045 Ft-MD 6,767 Ft- TVD "I Pressure Inte~ritvTest Mud Weight: 9.8 ppg Inner casing 00: 8.9 In. 125,000 75,000 14.5 ppg 583 psi Desired PIT EMW: Estimates for Test: -0.1 bbls I.. ..I EMW = Leak-off Pressure :+ Mud Weight = 646 + 9 8 0.052 x TVD 0.052 x 2385 . EMWat 3055 Ft-MD (2385 Ft-TVD) = 15,0 PIT 15 Second Shut-in Pressure, psi 520 1000· w a= ::) CJ) CJ) w a= a. 5 10 15 20 25 Shut-In time, Minutes o PIT Point , . ....---1X"'-~I~ 4 6 Barrels 8 10 o 12 ---CASING TEST ---LEAK-OFF TEST Comments: I Volume Input Barrels 'Y 0.1000 Bbls/Strk .. Casina Test Pumping Shut-in Bbls psi Min si o 0 .. 30 Volume Pumped 0.0 Bbls Volume Bled Back 2.8 Bbls Pump Rate: 0.5 Bbljmin ... Pressure Integrity Test Pumping Shut-in Bbls psi Min psi 0 0 0 535 0.5 46 0.25 520 1 86 0.5 520 1.5 136 1 520 2 187 1.5 ~'10 2.5 237 2 '- ..JJ 3 288 2.5 525 3.5 343 3 525 4 389 3.5 525 4.5 434 4 525 5 480 4.5 525 5.5 525 5 520 6 560 5.5 520 6.5 596 6 520 7 631 6.5 520 7.5 646 7 515 8 636 7.5 515 8.5 626 8 510 9 626 8.5 510 9.5 626 9 510 10 626 9.5 1)05 10.5 626 10 )5 ~ Volume Pumped 10.5 Bbls Volume Bled Back 1.0 Bbls ) ) Note to File C02-51 (202-249,..303-312) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface, Approximately 180 bbls of cement was circulated to surface, The net cement remaining in the surface hole was still 490/0 XS of the calculated hole volume, --On the initial leak off test, it was not possible to pump into the well at 16 ppg EMW, --The casing test and leak off pressure plot of C02-51 do not overlay each other, however they are satisfactory, Ouring the 10-minute observation period, the applied leak off pressure declined from 800 psi to 650 psi. --No problems are reported drilling the intermediate hole or while running and cementing the 7" casing, The pipe was not reciprocated during the cementing operation. There was no indication of lost circulation during the cementing operation. --On the injectivity test down 9-5/8" x 7" annulus, the pressure increases raggedly to 660 psi where it broke, While pumping proceeded, the pressure continued to decline to 450 psi. Ouring the 10-minute observation period, the pressure only declined 17 psi. The EMW where the pressure broke was 14,9 ppg, The information from this pump in test was discussed with CPA and another test was performed. On the second injectivity test, the pressure climbed smoothly until breaking at about 1040 psi. Fluid was pumped into the formation steadily at about 1100 psi. The calculated EMW where the formation broke is 15,3 ppg, --CPA provided a listing of all surface casing shoes within ~ mile of C02-51, The records of wells within 1100' radius were examined and no problems were identified that would preclude granting CPA's request for C02-51, Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. ./t~ ~ \()6b-a:, Tom Maunder, PE Sr. Petroleum Engineer s MEMORAN~, 'JM State, lAlaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: July 25, 2003 Commissioner . . \ r\ 07 SUBJECT: Mechanical. I~tegrity Tests THRU: Jim Regg rJ ð)C\ "'1. 1,-'D\ Conoco/Phllllps P.I. Supervisor~' (\ Alpine C02-12 FROM: John Crisp C02-51 Petroleum Inspector Collville River Unit NON· CONFIDENTIAL Type Inj. Type test T.VD. T est psi Tubing Casi ng 15 Min. 30 Min. 125 125 Interval I 1990 1980 P/F e 1100 1100 Interval I 2300 2290 P/F e Interval P/F Interval P/F Interval P/F Packer Depth Pretest Initial Well CD2-12 Type Inj. S T.VD. 6961 Tubing 125 125 P.TD. 2030730 Type test P Test psi 2000 Casing 750 2030 Notes: OA pretest pressure 750. OA pressure during test 850. 1/2 bbl pumped. Well CD2-51 Type Inj. S TV.D. 6909 Tubing 1100 1100 P.T.D. 2022490 Type test P Test psi 2250 Casing 1600 2340 Notes: OA pretest pressure 400. OA pressure during test 450. 1.8 bbl pumped. Well Type Inj. TV.D. Tubing P.TD. Type test Test psi Casing Notes: Well P.TD. Notes: Well P.TD. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Type Inj. Type test TVD. Test psi Tubing Casing Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal 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 0= Other (describe in notes) Test's Details I travelled to C/pls Alpine Field - Collville River Unit to witness 2 post injectjon initial MITis. No failures witnessed. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. 2003-0725_MIT _Alpine_ C02-51~c.xls 7/28/2003 \ ¡ \ ) 2.0 '2- -:¡~ 'J2Jl('? WEL:L LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 03, 2003 RE: MWDFormation Evaluation Logs - CD2-51, AK-MW-2323383 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20441-00. Note: This Data Replaces Any Previous Data For Well CD2-5L tV 0 pfe,vìo\ÁS do1(). t"':) ~,= 'I"~ E" '1\þ7r"''' r'."", ~\' ¡'M!¡ ~ :;) . ¡ ,ß ~!'~ 1 .~~ \I"""",~ .........6,,,[,",,"" tí' I') .tJ ..."'.~.~ ( ;¥ L... .. ~','- L;~ J} ~; ~I ~ 'J.)O:.!,... i\: ':' ~.~. ','~ ". " .", ' . ¡:\i",,,..,S \¡;¡ .,;. . '':':'';;:. .~' ""'. t...~~l:¡ ',Ii<, ,"c", ç':, "".:;.,., .,., ........., .;" "'.; .. t,.". . ~ 'J' ".. I. ' . '...- j .... ) ) G. C. Alvord Alpine Drilling Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 July 14, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for C02-51 (APD 202-249/303-087) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on the Alpine well C02-51, If you have any questions regarding this matter, please contact me at 265-6120, Sincerely, A·i, CXZ, G, C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad 11:.11,., .' ....~,.n JUL Î E ìG0¡l OR\G\NAL , '\ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U WINJ 0 WDSPL D GINJ 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Plugged D Abandoned D 20AAC 25.105 No. of Completions _ P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2073' FNL, 1502' FEL, Sec. 2, T11 N, R4E, UM At Top Productive Horizon: 2234' FNL, 2075' FWL, Sec. 7, T11 N, R5E, UM Total Depth: 650'FNL,803'FEL,Sec.18,T11N,R5E,UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371734 y- TPI: x- 380501 y- Total Depth: x- 382495 y~ 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlRes 22. CASING SIZE GRADE H-40 J-55 L-80 16" 9.625" WT. PER FT. 62.5# 36# 26# 7" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 3121' Surface 13246' 5974284 5968698 5964971 Zone-4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): open hole completion from 13246' to 17320' 26. Date First Injection July 4, 2003 Date of Test Hours Tested N/A Flow Tubing Casing Pressure press. 27. psi 24-Hour Rate-> Suspended D WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: May 3,2003 6. Date Spudded: March 12, 2003 7. Date TD Reached: May 1, 2003 8. KB Elevation (ft): RKB 36' I 52.7' AMSL 9. Plug Back Depth (MD + TVD): 17320' MD 17108' TVD 10. Total Depth (MD + TVD): 17320' MD I 7108' TVD 11. Depth where SSSV set: Land Nipple @ 2417' 19. Water Depth, if Offshore: N/A feet MSL 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: / 202-249 I 303-087 13. API Number: 50-103-20441-00 14. Well Name and Number: CD2-51 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ADL 380075 I 372097 I 25559 17. Land Use Permit: N/A 20. Thickness of Permafrost: 1665' MD 42" CEMENTING RECORD AMOUNT PULLED RBDMS BFL ,. . (g r- CONTINUED ON REVERSE SIDE HOLE SIZE Portland Type III 493 sx AS III Lite & 237 sx Class G 12.25" 8.5" 173 sx Class G 24. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 12626' PACKER SET (MD) 12531' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NI A NI A OR'G1N¡~L CHOKE SIZE GAS-OIL RATIO PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL WATER-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) .., ~ I II"'" Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 1 0-407 Revised 2/2003 ~__~._ 3_: .P.? ./T" --.-Ál v. '" NONE CORE DATA JUL 1 FI '!!~nl JUl 2 1 2003 Submit in duplicate 28. ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-51 Seabee Form. Nanushuk Gamma Ray Shale Kalubik Kuparuk Form. Miluveach Top Alpine D Top Alpine C Alpine A Base Alpine TD 3130.5' 6108.5' 11868' 12409' 12492' 12594.5' 12976' 13080.5' 2401' 3821' 6599' 6853' 6891' 6938' 7072' 7098' N/A 17320' 7108' JUt ]1 [) ZOO] 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name C. Alvord Signature )-L. ðkl.. Title: Alpine Drilling Team Leader 2.-1Ó)' -" ( L." "'7 ( 15/0.7 DateL::> Phone Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: list all test information. If none, state "None". OR\G\NAL Form 10-407 Revised 2/2003 ) ) Legal Well Name: CO2-51 Common Well Name: CO2-51 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Däte Frorn..To' Hours Code' '·Sub.. CÒd~ 3/12/2003 08:30 - 14:30 6.00 MOVE MOVE MOVE 14:30 - 15:00 0.50 MOVE MOVE MOVE 15:00 - 15:30 0.50 MOVE RURD RIGUP 15:30 - 17:00 1.50 MOVE RURD RIGUP 17:00 - 19:00 2.00 MOVE RURD RIGUP 19:00 - 19:30 0.50 DRILL PULD SURFAC 19:30 - 20:00 0.50 DRILL OTHR SURFAC 20:00 - 21 :00 1.00 DRILL DRLG SURFAC 21 :00 - 21 :30 0.50 DRILL TRIP SURFAC 21 :30 - 00:00 2.50 DRILL PULD SURFAC 3/13/2003 00:00 - 01 :30 1.50 DRILL PULD SURFAC 01 :30 - 12:00 10.50 DRILL DRLG SURFAC Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: Rig released from CD2-36 to CD2-51 at 0830 hrs. on 3/12/2003. Moved rig module and positioned over well. Positioned mud and power module. Connected service lines bewteen modules. Prepared to take on spud mud. N/U surface drilling riser. Received spud mud. Continued connecting service lines. P/U mousehole. Made rig ready to spud. M/U bit, bit sub, XO, and two stands 5" HWDP. Tagged at 114' Tested mudlines to 3000 psi and checked flowline, etc. for leaks. Spudded CD2-51 at 2000 hrs. on 3/12/2003. Drilled 12-1/4" hole from 114' to 180'. Encountered little cement in conductor. POOH. P/U steerable BHA for kickoff. Finished P/U steerable BHA for kickoff. Ran gyro and oriented. Held rig floor pre-spud meeting. Directionally drilled 12-1/4" surface hole from 180' MD (180' TVD) to 480' MD (467' TVD). WOB 25-35; RPM 100-150; 1420 psi @ 600 gpm ADT: 6.2 hrs. = ART: 1.2 hrs. + AST: 5 hrs. P/U wt. 115k; SIO wt. 115k, Rot. wt. 115k. Torque on/off 7k16.5k ft. Ibs. 12.00 DRILL DRLG SURFAC Directionally drilled 12-1/4" surface hole from 480' MD (467' TVD) to 2311' MD (1945' TVD). WOB 25-35; RPM 100-170; 1960 psi @ 600 gpm ADT: 8 hrs. = ART: 4.8 hrs. + AST: 3.2 hrs. Total ADT: 14.2 hrs. = ART: 6 hrs. + AST: 8.2 hrs. P/U wt. 125k, SIO wt. 115k, Rot. wt. 125k Torque on/off 9k17.5k ft. Ibs. 9.50 DRILL DRLG SURFAC Drilled 12-1/4" surface hole from 2311' MD (1945' TVD) to 3131' MD (2401' TVD). Lost returns at 2981'. Worked pipe with 5 bpm and regained full returns. Lost 60 bbl. total mud. WOB 25-35; RPM 100-180; 2200 psi @ 600 gpm. ADT: 6.88 hrs. = ART: 5.06 hrs. + AST: 1.82 hrs. Total ADT: 21.08 hrs. = ART: 11.06 hrs. + AST: 10.02 hrs. P IU wt. 130k; SIO wt. 125k; Rot. wt. 130k Torque on/off 8.5k17.5k Circulated bottoms up and until hole cleaned up. Flow checked. Blew down TDS. POOH to 1010' where tight hole was encountered with resistance down. 12:00 - 00:00 3/14/2003 00:00 - 09:30 09:30 - 10:30 1.00 DRILL CIRC SURFAC 10:30 - 10:45 0.25 DRILL WIPR SURFAC 10:45 - 12:45 2.00 DRILL WIPR SURFAC 12:45 - 13:15 0.50 DRILL REAM SURFAC 13:15 - 13:30 0.25 DRILL REAM SURFAC 13:30 - 14:15 0.75 DRILL WIPR SURFAC 14:15 - 14:45 0.50 DRILL REAM SURFAC 14:45 -15:15 0.50 DRILL TRIP SURFAC 15:15 - 16:30 1.25 DRILL CIRC SURFAC 16:30 - 16:45 0.25 DRILL TRIP SURFAC 16:45 - 17:00 0.25 DRILL TRIP SURFAC 17:00 - 17:15 0.25 DRILL REAM SURFAC 17:15 - 19:30 2.25 DRILL TRIP SURFAC 19:30 - 22:00 2.50 DRILL TRIP SURFAC .. .... . ". .":' ....: ": ... . Descdption of ()þ$råtions Backreamed and reamed from 950' to 1 040'. Continued POOH to 770'. Flow checked. RIH to resistance and surging at 1900'. Washed and reamed from 1900' to 1990'. Continued RIH 3047'. Precautionary washed from 3047' to TD at 3131'. No fill. Circulated and conditioned hole and mud. Flow checked. Blew down TDS. POOH to tight hole at 3000'. Backreamed from 3040' to 2950'. Continued POOH. UD NMFDC's, MWD, motor, bit, and associated subs. Printed: 5/15/2003 8:49:32 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-51 C02-51 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date . . . . ... SOb F=rom .. TôHol.lrs · Code ,. C()~e. Phase 3/14/2003 22:00 - 22:30 22:30 - 00:00 3/15/2003 00:00 - 00:15 00: 15 - 00:30 00:30 - 04: 15 04:15 - 05:15 05:15 - 05:45 05:45 - 06:30 06:30 - 08:45 08:45 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 14:00 14:00 - 14:45 14:45 - 15:00 15:00 - 00:00 3/16/2003 00:00 - 01 :00 01 :00 - 04:15 04:15 - 04:30 04:30 - 05:15 05:15 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 09:00 09:00 - 09:15 09:15 - 09:30 09:30 - 10:15 10:15 -11:00 11 :00 - 13:00 13:00 - 13:30 13:30 - 17:00 17:00 - 19:00 4/10/2003 07:00 - 12:00 12:00 - 00:00 0.50 DRILL 1.50 CASE OTHR SURFAC RUNC SURFAC 0.25 CASE 0.25 CASE 3.75 CASE RUNC SURFAC SFTY SURFAC RUNC SURFAC 1.00 CEMENTCIRC SURFAC 0.50 CEMENT RURD SURFAC 0.75 CEMENTCIRC SURFAC 2.25 CEMENT PUMP SURFAC 1.25 CEMENT RURD SURFAC 2.00 CASE NUND SURFAC 0.50 CASE NUND SURFAC 1.50 ABANDI\ NUND SUSPEN 0.75 ABANDI\ NUND SUSPEN 0.25 ABANDI\ NUND SUSPEN 9.00 ABANDI\ PULD SUSPEN 1.00 ABANDI\ OTHR 3.25 ABANDI\ PULD 0.25 ABANDI\ OTHR 0.75 ABANDI\ TRIP 0.75 ABANDI\ NUND SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN 0.50 ABANDI\ DPST SUSPEN 2.00 ABANDI\ NUND SUSPEN 0.50 ABANDI\ NUND SUSPEN 0.25 ABANDI\ DPST SUSPEN 0.25 ABANDI\ OTHR SUSPEN 0.75 ABANDI\ RURD SUSPEN 0.75 ABANDI\ DPST SUSPEN 2.00 ABANDI\ CIRC SUSPEN 0.50 ABANDI\ RURD SUSPEN 3.50 MOVE DMOB DEMOB 2.00 MOVE DMOB DEMOB 5.00 MOVE DMOB MOVE 12.00 MOVE MOVE MOVE Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: Cleared drilling tools from rig floor. Removed drilling bails. Rigged up to run casing. P/U extended bails and fill up tool. Installed 350T spider and elevator. Mud losses to hole 2.5 BPH. Finished R/U to run casing. PJSM - run 9-5/8" surface casing. Ran 74 joiints 9-5/8" 36 ppf J-55 BTC casing with float shoe, float collar, and FMC Gen V hanger. Installed total of 44 centralizers on casing string. No hole problems. Float shoe at 3121' MD, float collar at 3032' MD. Circulated 1 x casing volume while reciprocating casing. R/D Frank's tool and R/U cementing head and lines. Continued circulating and conditioning mud and hole. Held PJSM - cement 9-5/8" casing. Pumped 40 bbl. viscosified fresh water. Tested cement lines to 2500 psi. Dropped bottom plug. Pumped 50 bbl. Mudpush spacer mixed at 10.5 ppg. Pumped 390 bbl. (493 sks) ASL31ead mixed at 10.7 ppg). Pumped 49.3 bbl. (237 sks) 'G' w/additives tail mixed at 15.8 ppg. Dropped top plug. Displaced cement with 234 bbl. Bumped plug and checked floats - OK. 180 bbl cement returned to surface R/D cementing head and lines. Backed out and UD landing joint. UD extended bails. Cleared and cleaned rig floor. Flushed riser. N/D riser and adaptor. N/U FMC unihead. Tested to 1000 psi. N/U BOP. Installed BOP test plug. Body tested BOP and wellhead adaptor to 3500 psi. Removed BOP test plug. Installed wear bushing. RIH then UD tubulars from derrick including 5 stands HWDP, 22 stands 5" DP, and 51 stands 4" DP. Cut and slipped drilling line. Fiinished UD tubulars from derrick. Retrieved wear bushing. RIH with 25 stands of 4" DP to 2390'. P/U tubing hanger and M/U to DP. M/U landing joint. Landed tubing hanger and engaged lockdown screws. Tested two way check valve, tubing hanger seals and wing valve to 5000 psi. PJSM. N/D BOP. N/U vertical tree valves. Tested swab valve and tree flamnges to 5000 psi. Removed two-way check valve from tubing hanger. R/U lines to displace and freeze protect well. Tested lines to 3000 psi. PJSM. Tested 9-5/8" casing to 2500 psi for 30 minutes OK. Dowell displaced well with diesel for freeze protection. Flushed and blew down lines. Installed BPV in tubing hanger. Prepared rig for moving. Meanwhile ball mill finished injecting waste fluid. Moved pipe module off of pad. Moved ball mill module clear of rig module. CD2-51 temporarily suspended and rig released for modifications at 1900 hrs., 3/16/2003. Prepare rig for move Move camp CD2. Skid rig floor onto transporter. Start moving Printed: 5/15/2003 8:49:32 AM ') '" . . ....... ,. " , ' .q(jnøêoPhillipsAI(i~ka , ,. · ()pe~~t¡:on$~U trll11äryRE!pqrt ,. Legal Well Name: CO2-51 Common Well Name: CO2-51 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 "'·Date"· Sljþ Phåse CÒdè 4/1 0/2003 12:00 - 00:00 12.00 MOVE MOVE MOVE 4/11/2003 00:00 - 00:00 24.00 MOVE MOVE MOVE 4/12/2003 00:00 - 00:00 24.00 MOVE MOVE MOVE 4/13/2003 00:00 - 00:00 24.00 MOVE MOVE MOVE 4/14/2003 00:00 - 11 :30 11.50 DRILL RIRD RIGUP 11 :30 - 12:00 0.50 DRILL SFTY RIG UP 12:00 - 15:30 3.50 DRILL RIRD RIGUP 15:30 - 16:00 0.50 DRILL RIRD RIGUP 16:00 - 00:00 8.00 DRILL CIRC DECOMP 4/15/2003 4/16/2003 4/17/2003 Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: . . ... ..... t>éscriptiqrt ofOperåtioÓ$ . transporter and sub base to C02-51. Move Rig Floor Transporter to CD2. Moving sub base, motor complex, pit complex and pipe shed to C02. Moving sub base, motor complex, pit complex and pipe shed to CD2. Moving rig to CD2-51 location and begin R/U. Mating sub structure to scissor jack. Spot sub to transport. Skid floor to sub. Disconnect from transport. Hook up to sub power. Prep for floor skid. Skid floor to moving position. Move rig to final position on C02-51 well. Pre-spud safety meeting before skidding rig over well. Move rig over C02-51. Spot pits & motor complex. Build 300 bbls. of 9.6 mud to displace diesel from hole and drill ahead. Pull BPV and R/U to displace diesel from well with returns to upright tank while building the required mud. Finish building mud for diesel displacement. Displace diesel from CD2-51with returns to slop tank. RID lines used for circulating through tree. Set two way check valve in hanger. N/D tree. N/U BOP equipment. Test BOP equipment as per AOGCC & Doyon regulations. John Crisp, AOGCC, waived witnessing BOP test. Retrieve two way check valve in hanger. P/U landing joint. Engage hanger. Retrieve hanger to surface wi 115k pull. UD landing joint, hanger and crossover. POOH and stand 4" DP kill string in derrick. R/U 5" handling tools including elevators. Install wear bushing. P/U and stand in derrick 75 joints of 5" DP. P/U and stand in derrick 21 joints of 5" DP & 26 joints of 5" HWDP wi jars. RIH wi 25 stands of 4" DP. POOH UD same. UD GeoSpan unit that controls GeoPilot tools. P/U 87 stands 4" drill pie and stood back in derrick. P/U BHA including Geo-Pilot and MWD. RIH and P/U drill pipe. Washed through ice plug from 800' - 865'. Drilled cement from 2986' to 3022'. Tested 9-5/8" surface casing to 2500 psi.. Drilled cement and float equipment from 3022' to 3131'. Drilled 8-1/2" hole from 3131' to 3151'. Circualted bottoms up and ensured even mud weight.. Conducted FIT to 16.0 ppg EMW (800 psi with 9.6 ppg MW and shoe depth of 2396' TVD). Displaced to Ultradrill mud. Drilled 8-1/2" intermediate hole from 3151' MD to 3237' MD (2448' TVD) with Geopilot rotary steerable assembly. ADT = 0.96 hrs. 100-150 RPM; 5-20 klbs. WOB; 1970 psi at 130 SPM/546 GPM Torque on/off: 7/7 kft-Ibs P/U 140 klbs; S/O 110 klbs; Rot. wt. 125 klbs. 9.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 3237' MD (2448' TVD) to 4089' MD (2858' TVD). ADT = 6.88 hrs. Total ADT = 7.84 hrs. 10 - 20 klbs. WOB. 00:00 - 00:30 0.50 DRILL CIRC DECOMP 00:30 - 01 :30 1.00 DRILL CIRC DECOMP 01 :30 - 02:00 0.50 DRILL RIRD DECOMP 02:00 - 03:00 1.00 WELCTL OTHR DECOMP 03:00 - 05:00 2.00 WELCTL NUND DECOMP 05:00 - 10:00 5.00 WELCTL BOPE DECOMP 10:00 - 10:30 0.50 WELCTL OTHR DECOMP 10:30 - 11 :30 1.00 DRILL PULD DECOMP 11 :30 - 13:00 1.50 DRILL TRIP DECOMP 13:00 - 13:30 0.50 DRILL RIRD SURFAC 13:30 - 17:00 3.50 DRILL PULD SURFAC 17:00 - 19:30 2.50 DRILL PULD SURFAC 19:30 - 23:30 4.00 DRILL PULD SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 00:00 - 10:00 10.00 DRILL TRIP SURFAC 10:00 - 14:00 4.00 DRILL TRIP SURFAC 14:00 - 17:00 3.00 DRILL TRIP SURFAC 17:00 - 17:30 0.50 CEMENT COUT SURFAC 17:30 - 18:30 1.00 CEMENTOTHR SURFAC 18:30 - 20:00 1.50 CEMENT DSHO SURFAC 20:00 - 20: 15 0.25 DRILL DRLG INTRM1 20:15 - 20:45 0.50 CEMENT FIT SURFAC 20:45 - 21 :30 0.75 CEMENT FIT SURFAC 21 :30 - 22:30 1.00 DRILL CIRC INTRM1 22:30 - 00:00 1.50 DRILL DRLG INTRM1 00:00 - 09:00 Printed: 5/15/2003 8:49:32 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-51 C02-51 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: Date From""'o Hours .,códeðóLJJe 4/17/2003 00:00 - 09:00 09:00 - 12:00 12:00 - 00:00 4/18/2003 00:00 - 03:00 03:00 - 04:00 04:00 - 11 :30 9.00 DRILL DRLG INTRM1 150-180 RPM. 2500 psi @ 142 SPM (608 GPM). P/U 135 klbs.; SIO 105 klbs.; Rot wt. 120 klbs. Rot. Torque on/off: 7500nOOO ft-Ibs. 3.00 DRILL CIRC INTRM1 Pumped 90 bbl. Hivis sweep and circulated hole clean. Returned fist-sized clumps of cuttings. 12.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 4089' MD (2858' TVD) to 5235' MD (3422' TVD). ADT = 8.79 hrs. Total ADT = 16.63 hrs. 10-15 klbs. WOS. 180 RPM. 3400 psi @ 142 SPM (608 GPM). P/U 140 klbs.; SIO 110 klbs.; Rot wt. 120 klbs. Rot. Torque on/off: 8000n500 ft-Ibs. 3.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 5235' MD to 5521' MD (3557' TVD). ADT = 2.58 hrs. 180 RPM; 10-15 klbs. WOS; 3800 psi @ 142 spm (607 gpm). P/U 145 klbs.; SIO 115 klbs.; Rotwt.125 klbs. Rot. torque on/off: 9000/8000 ft-Ibs. 1.00 DRILL CIRC INTRM1 Pumped 80 bbl. Hivis 11.7 ppg sweep and circulated around to reduce ECD from 12.8 ppg to 12.2 ppg. 7.50 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 5521' MD to 6190' MD (3853' TVD). ADT = 5.47 hrs. Total ADT = 24.68 hrs. 180 rpm; 10-15 klbs. WOS; 3950 psi @ 142 spm (607 gpm). P/U 148 klbs.; S/O 115 klbs.; Rot. wt. 125 klbs. Rot. torque on/off: 9000/8000 ft-Ibs. Pumped Hivis sweeps x 2 and POOH four stands from 6190' to 5712'. POOH on trip tank from 5712' to 5043' - insufficient hole fill. Pumped out of hole from 5043' to 4757'. Circulated bottoms up until hole clean. Continued POOH with pump from 4757' to 4184'. POOH on trip tank from 4757' to 3119' with no problems. Circulated bottoms up until hole cleaned up. RIH to 6098' with no resistance. Filled pipe at 5043'. Washed and reamed from 6098' to 6190' - no resistance, no fill. Took SPR's. ECD 11.2 ppg. Drilled 8-1/2" hole from 6190' MD (3853' TVD) to 7240' MD (4363' TVD). Sroke mud over to LSND at 7200'. ADT: 8.72 hrs. 180 rpm; 10-20 klbs. WOS. 3850 psi @ 142 spm (607 gpm). P/U 170 klbs.; S/O 120 klbs.; Rot. wt. 140 klbs. Rot torque on/off: 10000/9000 ft-Ibs. 12.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 7240' MD (4363' TVD) to 8371' MD (4917' TVD). ADT: 7.98 hrs. Total ADT: 41.38 hrs. 180 rpm; 15-20 klbs. WOS. 4180 psi @ 142 spm (607 gpm). P/U 190 klbs.; S/O 125 klbs.; Rot wt. 150 klbs. Rot torque on/off: 12000/10500 ft-Ibs. 12.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 8371' MD (4917' TVD) to 9300' MD (5366'TVD). ADT: 8.19 hrs. 170 rpm; 15-20 klbs. WOS; 4000 psi @ 128 spm (548 gpm). 11 :30 - 14:30 3.00 DRILL WIPR INTRM1 14:30 - 17:00 2.50 DRILL WIPR INTRM1 17:00 - 18:00 1.00 DRILL WIPR INTRM1 18:00 - 20:30 2.50 DRILL WIPR INTRM1 20:30 - 21 :30 1.00 DRILL WIPR INTRM1 21 :30 - 23:00 1.50 DRILL WIPR INTRM1 23:00 - 00:00 1.00 DRILL WIPR INTRM1 4/19/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 4/20/2003 00:00 - 12:00 Printed: 5/15/2003 8:49:32 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: , C()nocÓÞhillipsAI~ské3. Qþ~,r,~ti.(),n,s,....·,$.lI,r1'1m,~·rY'.'·Re,po.rt CD2-51 CD2-51 ROT - DRILLING doyon1 @ppco.com Doyon 19 [) a.te ,Sub FrÓrh..;To Hours Code Code ,Phase 4/20/2003 00:00 - 12:00 12:00 - 00:00 4/21/2003 00:00 - 03:00 Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: . . . .... .. . De~criptionofOperatiÓns 12.00 DRILL DRLG INTRM1 P/U 210 klbs.; S/O 125 klbs.; Rot wt. 155 klbs. Rot. torque on/off: 13000/12000 ft-Ibs. 12.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 9300' MD (5366' TVD) to 10410' MD (5895' TVD). ADT 8.43 hrs. Total ADT for bit: 58 hrs. 170 rpm; 15-20 klbs. WOB; 3620 psi @ 142 spm (607 gpm). P/U 245 klbs.; S/O 130 klbs.; Rot wt. 165 klbs. Rot torque on/off: 15500/14000 ft-Ibs. 3.00 DRILL DRLG INTRM1 Drilled 8-1/2" hole from 10410' MD (5895' TVD) to 10773' MD (6062' TVD). ADT 2.12 hrs. 170 rpm; 20 klbs. WOB; 3750 psi @ 142 spm (607 gpm). P/U 265 klbs.; S/O 130 klbs.; Rot wt. 165 klbs. Rot torque on/off: 16500/14000 t-Ibs. Pumped lo-vis then hi-vis sweeps. Circulated to clean hole. Flowchecked. Pumped out of hole 10 stands to 9822'. Changed mud pump liners to 5-1/2" from 6". POOH to 6080'. Some tight hole, 20-30k over pull, on first two stands, OK after that. Circulated to clean hole. Changed saver sub on TDS from XT-39 to NC50. Serviced TDS. RIH from 6080' to 10682'. Filled pipe at 8009' and 9918'. Washed from 10682' to 10773'. No fill. Changed liner in #2 mud pump. Drilled 8-1/2" hole from 10773' MD to 10830' MD. Tightened liner thread rings on #2 mud pump cylinders. Drilled 8-1/2" hole from 10830' MD to 11206' MD (6275' TVD). ADT: 2.87 hrs. Total ADT last 24 hrs: 4.99 hrs. 170 rpm; 15-20 klbs. WOB; 3240 psi @ 167 spm (600 gpm). P/U 270 klbs,; S/O 1340 klbs.; Rot wt. 175 klbs. Rot. torque on/off: 17000/16000 ft-Ibs. 1.25 DRILL OTHR INTRM1 Trouble shoot Geo Pilot - Circ @ 500 gpm 2300 psi @ 11,206'- observed housing roll. 1< Note - Drilled kelly down to 11,251' 03:00 - 05:30 2.50 DRILL CIRC INTRM1 05:30 - 05:45 0.25 DRILL OBSV INTRM1 05:45 - 07:30 1.75 DRILL WIPR INTRM1 07:30 - 11 :30 4.00 DRILL WIPR INTRM1 11 :30 - 12:30 1.00 DRILL CIRC INTRM1 12:30 - 13:30 1.00 DRILL OTHR INTRM1 13:30 - 14:00 0.50 RIGMNT RSRV INTRM1 14:00 - 16:30 2.50 DRILL WIPR INTRM1 16:30 - 17:00 0.50 DRILL WIPR INTRM1 17:00 - 18:30 1.50 RIGMNT RGRP INTRM1 18:30 - 19:00 0.50 DRILL DRLG INTRM1 19:00 - 20:00 1.00 RIGMNT RGRP INTRM1 20:00 - 00:00 4.00 DRILL DRLG INTRM1 4/22/2003 00:00 - 01 :15 01 :15 - 01 :30 01 :30 - 03:45 03:45 - 04:15 04:15 - 05:00 05:00 - 11 :30 11 :30 - 15:30 15:30 - 16:00 16:00 - 20:30 4/23/2003 20:30 - 00:00 00:00 - 01 :00 0.25 DRILL TRIP INTRM1 2.25 DRILL OTHR INTRM1 0.50 DRILL TRIP INTRM1 0.75 DRILL OTHR I NTRM1 6.50 DRILL TRIP INTRM1 4.00 DRILL TRIP INTRM1 0.50 WELCTL BOPE INTRM1 4.50 WELCTL BOPE INTRM1 3.50 WELCTL BOPE INTRM1 1.00 WELCTL BOPE INTRM1 POOH wi pump fl 11,206' to 10,902' Trouble shoot Geo Pilot - Circulate. Pumped hi-vis sweep. POOH w/ pump fl 10,902' to 10,773' (5" DP) Change 4 1/2" I F saver sub to XT39 TOOH on trip tank f/ 10,773' to 90' - Stand back HWDP - flex DC's Downloaded MWD. Changed out Geo Pilot rotary steerable assembly and stood back in derrick. Retrieved wear bushing. Installed test plug with test joint. Tested BOPE to 250/5000 psi (annular preventer to 250/3500 psi). Conducted accummulator test. Upper IBOP failed. Replaced upper IBOP. Tested same to 250/5000 psi OK. Test IBOP to 250 & 5000 psi - RD test equipment - pull test plug - set wear bushing Printed: 5/15/2003 8:49:32 AM ) ) 0.50 DRILL OTHR INTRM1 MWD tool quite pulsing - trouble shoot - unable to regain pulse * Contact Drilling team leader in Anchorage Decision made to call TD @ 13,256' MD 7131' TVD for 7" casing 1.50 DRILL CIRC INTRM1 Pump low/high vis sweep - circulate hole clean for wiper trip- 600 GPM 3600 psi 150 RPM 3.25 DRILL WIPR INTRM1 Wiper trip - Pump out f/13,256' to 12,330' - 9 bbl/min @ 1790 psi wI 100 RPM - POOH on trip tank fl 12,330' to 11,181' - some tight spots in HRZ 15 to 25 over & tight spots in sand stringers in the Albine 96 - 30 to 40 over - hole took proper fill on trip tank - monitor well - static RIH f/11,181' to 13186'. No resistance. Washed from 13186' to bottom at 13256'. No fill. Pumped sweep and circulated to clean hole. Pumped out of hole from 13256' to 12298'. POOH to 10775'. Maximum overpull 20 klbs. Changed saver sub from 4-1/2" IF to XT39. Changed mud bucket rubbers from 5" to 4". Contnue POOH f/10,775' to 550' - LD ghost reamer Handle SHA - std back HWDP & flex DC's - Down load MWD - LD MWD - Geo Pilot - bit - house keeping rig floor PU stack washer - flush stack - LD wash tool Pull wear bushing - install test plug wI 7" test jt. - change top pipe rams to 7" & test to 250 & 5000 psi - LD test jt. & test plug - set thin wall wear bushing RU to run 7" casing Held PJSM with crew on running 7' casing Run 7" casing - MU FS - 2 jts. 7" 26# L-80 STCM csg - FC - 2 jts. 7" 26# L-80 STCM csg - SakerLoc first 4 connections - pump through to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-51 C02-51 ROT - DRILLING doyon1 @ppco.com Doyon 19 D' t.. F' 'T H"..' C d' 8Üb Ph"" , a e . . rom -<0 . "ours .'" ·oe Code· ",ase 4/23/2003 01 :00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 1 0:30 10:30 - 11 :30 11 :30 - 12:00 1.00 WELCTL EORP 1.00 DRILL PULD 1.50 DRILL TRIP 1.00 RIGMNT OTHR 0.50 DRILL TRIP 4.50 DRILL TRIP 1.00 DRILL REAM 0.50 DRILL DRLG INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 4/24/2003 00:00 - 11 :30 11.50 DRILL DRLG INTRM1 11 :30 - 12:00 12:00 - 13:30 13:30 ~ 16:45 16:45 - 17:30 0.75 DRILL TRIP INTRM1 17:30 - 18:00 0.50 DRILL REAM INTRM1 18:00 - 20:00 2.00 DRILL CIRC INTRM1 20:00 - 23:00 3.00 DRILL TRIP INTRM1 23:00 - 00:00 1.00 DRILL TRIP INTRM1 4/25/2003 00:00 - 04:00 4.00 DRILL TRIP INTRM1 04:00 - 07:30 3.50 DRILL PULD INTRM1 07:30 - 08:00 0.50 DRILL OTHR INTRM1 08:00 - 10:00 2.00 CASE OTHR INTRM1 10:00 - 11 :15 1.25 CASE RURD INTRM1 11:15 -11:30 0.25 CASE SFTY INTRM1 11 :30 - 15:00 3.50 CASE RUNC INTRM1 Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: InstalllSOP componets to TD - Clean floor MU bit 2 RR1- Up load MWD RIH to 2560'. Cut and slipped 60' drilling line. Removed XT39 saver sub and installed 4-1/2" I Fsaver sub. Continued RIH. Filled pipe every 2000'. Washed from 11157' to 11251' with no resistance or fill. Drilled 8-1/2" hole from 11251' MD to 11282' MD (6314' TVD). ADT: 0.28 hrs. 170 rpm; 15-20 klbs. was; 3350 psi @ 164 spm (589 gpm). P/U 270 klbs.; SIO 130 klbs.; Rot wt. 175 klbs. Torque on/off: 16000/15000 ft-Ibs. Drilled 8-1/2" hole from 11282' MD (6314' TVD) to 12298' MD (6803' TVD). ADT: 8.41 hrs. Total ADT for this bit: 8.69 hrs. 150-170 rpm; 15-20 klbs. was; 3140 psi @ 153 gpm (549 gpm). P/U 295 klbs.; SIO 137 klbs.; Rot wt. 190 klbs. Torque on/off: 17500/16500 ft-Ibs. Drill 8 1/2" hole wI Geo Pilot f/12,298' to 13,256' MD 7131' TVD ADT-7.78 hrs RPM 160 WOS 15 to 20 k GPM 550 @ 3160 psi String Wt. PU 310 SO 135 ROT 188 Torque on I off btm 22000/21000 ftllbs * Note: Top Alpine C - 13,088' MD 7100' TVD Printed: 5/15/2003 8:49:32 AM ) ) Legal Well Name: CO2-51 Common Well Name: CO2-51 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 ···"Date Froh1+T6 Hours '.Cbde ,Sub Phase Códê. 4/25/2003 11 :30 - 15:00 3.50 CASE RUNC INTRM1 15:00 - 15:30 0.50 CASE CIRC INTRM1 15:30 - 20:00 4.50 CASE RUNC INTRM1 20:00 - 21 :00 1.00 CASE CIRC INTRM1 21 :00 - 00:00 3.00 CASE RUNe INTRM1 4/26/2003 00:00 - 01 :30 1.50 CASE RUNC INTRM1 01 :30 - 02:00 0.50 CASE NUND INTRM1 02:00 - 06:00 4.00 CEMENTCIRC INTRM1 06:00 - 06: 15 0.25 CEMENT SFTY INTRM1 06:15 - 08:30 2.25 CEMENT PUMP INTRM1 08:30 - 09:00 0.50 CEMENT RURD INTRM1 09:00 - 10:00 1.00 WELCTL OTHR INTRM1 10:00 - 12:00 2.00 WELCTL OTHR INTRM1 12:00 - 16:00 4.00 WELCTL BOPE INTRM1 16:00 - 16:30 0.50 DRILL PULD INTRM1 16:30 - 20:00 3.50 DRILL PULD INTRM1 20:00 - 00:00 4.00 DRILL PULD INTRM1 4/27/2003 00:00 - 02:30 2.50 DRILL TRIP INTRM1 02:30 - 03:30 1.00 DRILL TRIP INTRM1 03:30 - 05:00 1.50 RIGMNT RSRV INTRM1 05:00 - 07:00 2.00 DRILL TRIP INTRM1 07:00 - 08:00 1.00 DRILL REAM INTRM1 08:00 - 09:30 1.50 CEMENT COUT INTRM1 09:30 - 11 :00 1.50 DRILL CIRC INTRM1 Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: check floats - Continue running 7" 26# L-80 BTCM csg to 3107' (73 jts. total) Circulate casing volume - 5 bbls/min @ 380 psi PU wt. 135 SO wt. 112 Continued running 7" 26# L-80 BTCM csg to 8455'. Circulated bottoms up - 5 bpm @ 690 psi. P/U 250 klbs.; SIO 130 klbs. Continued running 7" 26# L-80 BTCM casing. At 0000 hrs. 11652' with no problems. Continue running 7" 26# L-80 BTCM casing to 13,209.51' - 314 jts total ran - PU hanger & landing jt. -land 7" casing in wellhead on FMC fluted mandrel hanger wi shoe @ 13,245.72' & FC @ 13,157' LD fill up tool & csg tongs - RU cement head Circulate and condition mud for cement job - Lower YP to 16 - Mud wt. rfl 10.0 ppg to 9.6 ppg - stage pumps slowly to 6.5 bbls/min @ 760 psi Held PJSM for cmenting 7" casing Cement 7" casing - pump 5 bbls Arco wash @ 8.3 ppg - Test lines to 3500 psi - Pump 15 bbls Arco wash - Mix & pump 50 bbls Mud Push XL @ 12.5 ppg - 5.25 bbls/min @ 800 psi - drop bottom plug - mix & pump 36 bbls slurry (Class G wi 0.20% D46, 0.25% D65, 0.40% D167, 0.020% B155) 36 bbls (173 sks) @ 15.8 ppg - 5 bbls/min @ 850 psi- drop top plug wi 20 bbls water fl Dowell - switch to rig pumps & displace wi 484 bbls 9.6 ppg mud @ 6 bbls/min @ 490 psi for 383 bbls- increase rate to 7 bbls/min @ 730 psi for 71 bbls - slowed pumps to 3 bbls/min for last 30 bbls 470 psi to 810 psi - Shut down - didn't bump plug - Bleed off pressure - floats held - CIP @ 0822hrs. - full circulation throughout job LD cement head & landing jt. Pull thin wal wear bushing - set & test 9 5/8"x7" pask off & test to 5000 psi Set test plug - change top pipe rams f/7" to 3 1/2" X 6" VBR Test BOPE - Hydril to 250 & 3500 psi - pipe rams, blind rams, kill & choke line valves, choke manifold valves, IBOP's - floor valves to 250 & 5000 psi - Performed accumlator closure test - Test witnessed & approved by Chuck Scheve AOGCC Pull test plug & set wear bushing PU drilling bales & DP elevators M/U 6-1/8" BHA. P/U bit and motor and adjusted motor to 1.15 deg. P/U and oriented MWDLWD. P/U PWD and TM. Uploaded MWD. P/U 3 x flex collars, xo, 3 x HWDP, jar, and 2 x HWDP. P/U 4" drill pipe and RIH. Continue RIH w/6 -1/8" BHA picking up 4" DP fl pipe barn fl 4488' to 7350' (219 jts. picked up) fill pipe every 20 stds. Continue RIH wi 6-1/8" BHA wi 4" DP fl derrick fl 7350' to 8980' PJSM - Slip & cut 60' drill line - service TD Continue RIH fl 8980' to 12,800' - fill pipe every 20 stds Wash fl 12,800' to 13,068' - tag top cmt @ 13,068' - (89' above FC- 3.4 bbls cmt vol. - 29.5 bbls cmt vol. in annulus) 210 GPM 1280 psi 50 RPM Clean out cmt fl 13,068' to 13,150' - 5 BPM 60 RPM 1800 psi 15 to 20k WOB Circulate hole clean for casing test - 50 bbls/min 60 RPM 1700 psi Printed: 5/15/2003 8:49:32 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-51 C02-51 ROT - DRILLING doyon1 @ppco,com Doyon 19 >< ',.. · .'.," , ..." ' SLlb HQursqod~, COde Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: Frdrn~ To DeSGriptionof Op~rati()ns 1.00 DRILL OTHR INTRM1 RU - pressure test 7" casing to 3500 psi for 30 mins. RD 1.00 CEMENT DSHO INTRM1 Clean out cement - FC - cement to FS - drill out shoe & clean out rat hole to 12,256' - 60 RPM - 1 0/12k WOB 5bbls/min @ 2150 psi 0.50 DRILL DRLH INTRM1 Drill 20' new hole fl 13,256' to 13,276' 1 0/12k WOB - 5 bbls/min @ 2150 psi 4/27/2003 11 :00 ~ 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 15:00 1.50 DRILL CIRC INTRM1 15:00 - 15:30 0.50 DRILL FIT INTRM1 15:30 - 18:00 2.50 DRILL CIRC PROD 18:00 - 00:00 6.00 DRILL DRLH PROD 4/28/2003 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 4/29/2003 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 4/30/2003 00:00 - 12:00 12.00 DRILL DRLH PROD Circulate hole clean for FIT wi 9.6 ppg mud wt. inlout 5 bbls/min 1890 psi 60RPM RU - preform FIT to 12.5 ppg EMW wi 1080 psi wi 9.6 ppg mud @ 7129' TVD - RD Change well over to 8.8 ppg FloPro - 5 bbls/min @ 1870 psi - 60 RPM - shut down - monitor well (static) - cleaning surface equipment. Took slow pump rates. Drilled 6-118" hole from 13276' MD to 13520' MD (7137' TVD). Finished build to horizontal. ADT: 4.7 hrs.. = ART: 2.10 hrs. + AST: 2.60 hrs. 80 rpm (TDS) + 225 rpm (motor); 5-12 klbs. WOB; 2150 psi @ 50 spm (214 gpm). P/U 225 klbs.; SIO 135 klbs.; Rot. wt. 175 klbs. Torque on/off: 16500/15500 ft-Ibs. Drill 6-1/8" horizontal section fl 13,520' to 14,100' MD 7128' TVD ADT - 7.95 hrs = AST - 2.34 hrs ART- 5.61 hrs. WOB 6/8 k RPM 80 GPM 210 @ 2480 psi St. wt. PU 225 SO 135 ROT 175 Torque onloff btm 14,000 113,000 ft/lbs Drilled 6-1/8" horizontal section from 14100' MD (7128' TVD) to 14627' MD (7124' TVD). ADT: 8.59 hrs = ART: 6.92 hrs. + AST: 1.67 hrs. Daily ADT: 16.54 hrs. = ART: 12.53 hrs. + 4.01 hrs. Total ADT: 21.24 hrs. = ART: 14.63 hrs. + 6.61 hrs. 70-80 rpm (TDS) + 225 rpm (motor); 8-10 klbs. WOB; 2450 psi @ 50 spm (214 gpm). P/U 215 klbs.; SIO 140 klbs.; Rot wt. 175 klbs. Torque on/off: 13500/12000 ft-Ibs. Drill 6-1/8" horizontal section fl 14,627' to 15,275' MD 7123' TVD - ADT - 7.8 hrs. = ART - 6.52 hrs. AST - 1.28 WOB 6/8 k RPM 80 (290 @ bit) GPM 210 @ 2410 psi St. Wt. PU - 220 SO - 135 ROT - 175 Torque onloff btm. 13,500 112,500 ft/lbs Drilled 6-1/8" horizontal section from 15275' MD (7123' TVD) to 15944' MD (7125' TVD). ADT: 8.9 hrs. = ART: 7.3 hrs. + AST: 1.6 hrs. Daily ADT: 16.70 hrs. = ART: 13.82 hrs. + 2.88 hrs. Total ADT: 37.94 hrs. = ART: 28.45 hrs. + 9.49 hrs. 80 rpm (TDS) + 225 rpm (motor); 8-10 klbs WOB; 2520 psi @ 50 spm (214 gpm). P/U 220 klbs.; SIO 135 klbs.; Rot wt. 170 klbs. Torque on/off: 14000/13000 ft-Ibs. Drill 6 1/8" horizontal section fl 15,944' to 16,534' MD 7128' TVD ADT- 7.59 = ART 6.60 AST 1.99 WOB 6/8 k RPM 80 TD (290 @ bit) GPM 210 @ 2480 psi String wt. PU 220 SO 150 ROT 170 Torque on I off btm - 14,000 113,000 Printed: 5/15/2003 8:49:32 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-51 C02-51 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub, Date . Fråm~T(')· Hours Göde Code Phase 4/30/2003 12:00 - 00:00 12.00 DRILL DRLH PROD 5/1/2003 00:00 - 02:30 2.50 DRILL DRLH PROD 02:30 - 11 :30 9.00 DRILL DRLH PROD 11 :30 - 15:00 3.50 DRILL crRC PROD 15:00 - 18:30 3.50 DRILL CIRC PROD 18:30 - 19:30 1.00 DRILL CIRC PROD 19:30 - 00:00 4.50 DRILL TRIP PROD 5/2/2003 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 03:00 1.00 DRILL CIRC PROD 03:00 - 04:30 1.50 DRILL TRIP PROD 04:30 - 05:00 0.50 DRILL CIRC PROD 05:00 - 06:00 1.00 DRILL TRIP PROD 06:00 - 13:00 7.00 DRILL TRIP PROD 13:00 - 14:30 1.50 DRILL PULD PROD 14:30 - 15:00 0.50 CMPL TN OTHR CMPL TN 15:00 - 16:00 1.00 CMPL TN OTHR CMPL TN 16:00 - 16:30 0.50 CMPL TN RURD CMPL TN 16:30 - 00:00 7.50 CMPL TN RUNT CMPL TN Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: Drill 6 1/8" horizontal section fl 16,534' to 16.993' MD 7144' TVD ADT- 8.4 hrs. = ART- 6.4 hrs. AST- 2 - Total ADT past 24 hrs. 15.99 hrs WOB 6/9 k RPM 80 TD (290 @ bit) GPM 210 @ 2550 psi String wt. PU 225 SO 125 ROT 170 Torque on/off btm 14,000 113,000 Nibs * Note: Decision made to Geo Search for base & top of Alpine sand TD will be extended to a max. depth of 17,560' MD Dri1l61/8" horizontal section fl 16,993' to 17,071' MD -7145' TVD WOB 8/10 k RPM 80(TD) 290 @ bit GPM 210 @ 2650 psi String wt. PU 225 SO 125 ROT 170 Torque onloff btm 14,500 113,000 ft/lbs. Drill 6 1/8" horizontal section fl 17,071' to 17,320' MD TD -7108' TVD Same peremeters as above ADT - 8.9 hrs = ART- 3.4 hrs AST - 5.50 hrs.(totallast 24hrs) Drilled past permitted TD of 17,071' - to find btm & top of Alpine Std. back 1 std. - PU 1 single - Pump low/high vis sweep & circulate hole clean - 5 bbllmin @ 2300 psi wi 80 RPM - PJSM - Change well over fl FloPro to Brine - Pumped 40 bbls HV Brine pill followed by 8.8 ppg KCL brine Pumping @ 210 gpm @ 2430 psi wi final pressure Of 1800 psi - 80 RPM - Clean surface equipment - monitoring well - static losses @ 90 to 120 BBLS/HR Mix & spot 40 bbls LCM pill wi 5 sxs. Flovis+ - hole getting sticky while spotting pill POOH fl 17320' to 17,056' - work through hole fl 17,056' to 17,012' (10 degree dogleg) pulling 65 over - had to back ream & pump out to 17,012' - continue POOH to 16,325' - had to work through several tight spots - continue POOH on TT fl 16,230' to 15,940' - hole taking 16 BPH Continue POOH on TT fl 15,940' to 13,206' - hole taking 12 - 14 bbls/hr. Monitor well - fluid level dropping - Spot 20 bbls LCM pill ( KCL brine wi 4 sks FloVis+) 5 blm @ 1400 psi Continue POOH on TT fl 13,206' to 10,690' - hole taking 8 to 10 BPH Cycle AGS - pump dry job - 5 BPM @ 1100 psi Continue to POOH fl 10,690' to 8,975' Continue POOH fl 8975' to 1050' - LD excess 4" drill pipe - 267 jts. - hole taking <8 BPH Handle BHA - std. back HWDP - Flush BHA - Std. back NM flex DC's - LD MWD, motor, & bit Pull wear bushing - PJSM on LD 5" drill pipe in mouse hole LD 12 stds. 5" drill pipe fl derrick in mouse hole - monitoring hole on TT - hole taking 4.5 BPH RU to run 41/2" completion - Held PJSM Run 41/2" completion - MU WLEG - 41/2" 12.6# L-80 IBTM tbg pup- XN nipple wi RHC plug installed - 2 jts. 41/2" 12.6# L-80 IBTM tbg - 4 1/2" 12.6# L-80 IBTM pup jt. - Mill out extension - Baker S3 Packer - 4 1/2" 12.6# L-80 IBTM pup jt.( all connections below packer BakerLoc) 2 jts.4 1/2" 12.6# L-80 IBTM tbg - 41/2" 12.6# L-80 IBTM pup jt.- Camco GLM wi KBG-2 wi dummy valve - 41/2" 12.6# L-80 IBTM pup jt. - 230 jts. - Printed: 5/15/2003 8:49:32 AM ·) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Frorn '.; To 5/2/2003 16:30 - 00:00 5/3/2003 00:00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 06:30 06:30 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 14:00 .'. CI;qn()c~()PliilHp$AI~ska . ..., ." . . . "' 'Oþ~rati()ns SUrnmEifY Aep()rt C02-51 C02-51 ROT - DRILLING doyon1 @ppco.com Doyon 19 ".'",...., ' "..·'·.,.Sub- Hours Code ., ',', , ,.., ..' ',,' ,'..' · ,.',. ".... "Qo(jEr Start: 3/12/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 3/12/2003 End: 5/3/2003 Group: Descriptignof ()per~tibns' Phase 7.50 CMPLTN RUNT CMPLTN DB nipple -14 jts. 41/2" 12.6# 1·80 IBTM tbg· to 10,904' Losses to well 243 bbls last 24 hrs. Total to well 383 bbls. 2.00 CMPLTN RUNT CMPLTN Continue running 41/2" 12.6# L-80 IBTM tbg fl 10,904' to 12,590' 41 jts. - MU FMC tbg hanger & landing jt. A - land tbg in wellhead wi tail @ 12,625.79' - XN nipple @ 12,613' Packer @ 12,531' GLM @ 12,416' DB nipple @ 2417' . Ran 289 total jts. 4 1/2" tbg 1.00 CMPL TN OTHR CMPL TN Land down landing A - set TWC - PU landing jt B - Test metal to metal seals on hanger to 5000 psi for 10 mins. - LD landing jt. B 1.50 CMPL TN NUND CMPL TN ND BOPE - Change saver sub on TD to 4 1/2" IF 2.00 CMPL TN NUND CMPL TN NU tree & test to 5000 psi - Pull TWC 3.50 CMPL TN FRZP CMPL TN RU hard lines to tbg & annulus - RU squeeze manifold - PJSM - Displace well wi 213 bbls 9.2 KCL brine & 219 bbls diesel (tbg vol + 2000' TVD for annulus) 2.00 CMPL TN PCKR CMPL TN RU lubricator - Drop packer setting ball/rod - wait 20 mins. attempt to pressure up tbg to set packer - pumped 2 bbls . no pressure build up - wait 10 mins. pumped 3 bbls no pressure build up - 15 mins. pumped 4 bbls @ 2 bbls/min noted pressure build up on tbg & annulus· ball not on seat * Notified Weekend duty Supervisor Randy Thomas Decision made to secure well & move - bring slickline on to chase ball to set & set packer - Notified Wells group - slickline crew to arrive 5/4/2003 0.50 CMPL TN OTHR CMPL TN Vac out lines - manifold - RD lines & manifold 0.50 CMPL TN OTHR CMPL TN RU FMC lubricator - set BPV - secure well 1.00 CMPL TN OTHR CMPL TN Finish injecting fluid wi ball mill Released rig @ 1400 hrs. 5/3/2003 Printed: 5/15/2003 8:49:32 AM CD2-51 (Final Surveys) MD Inc Azim. SSTVD TVD EIW Y X (ft) (Deg) (Deg) (ft) (ft) 349 2.95 66 297.007 348.907 3.114 N 4.781 E 5974287 N 371739.1 E 465.8 4.56 80.39 413.555 465.455 5.112 N 12.105 E 5974289 N 371746.5 E 556.58 6.23 92.16 503.932 555.832 5.529 N 20.586 E 5974289 N 371755 E 645.24 8.77 100.23 591.829 643.729 4.147 N 32.047 E 5974287 N 371766.4 E 735.2 10.81 102.53 680.474 732.374 1.098 N 47.033 E 5974284 N 371781.3 E 108.79 767.61 819.51 4.085 S 65.1 E 5974279 N --/ 824.35 13.57 371799.3 E 914.66 18.12 112.74 854.468 906.368 12.931 S 88.094 E 5974269 N 371822.1 E 1009.78 21.7 119.14 943.898 995.798 27.218 S 117.109 E 5974255 N 371850.9 E 1104.86 26.69 124.48 1030.609 1082.509 47.882 S 150.088 E 5974233 N 371883.5 E 1200.27 29.28 123.8 1114.856 1166.756 72.996 S 187.146 E 5974208 N 371920.2 E 1295.29 30.04 122.82 1197.426 1249.326 98.813 S 226.443 E 5974181 N 371959 E 1390.75 32.66 123.82 1278.943 1330.843 126.105 S 267.929 E 5974153 N 372000 E 1486.03 36.66 125.25 1357.3 1409.2 156.844 S 312.536 E 5974122 N 372044.1 E 1581.4 38.31 126.19 1432.975 1484.875 190.733 S 359.647 E 5974087 N 372090.6 E 1676.24 40.17 126.42 1506.426 1558.326 226.254 S 407.991 E 5974051 N 372138.3 E 1771.64 41.41 125.76 1578.653 1630.553 262.961 S 458.355 E 5974013 N 372188.1 E 1866.91 44.75 125.17 1648.229 1700.129 300.702 S 511 .352 E 5973974 N 372240.4 E 1962.36 51.87 121.89 1711.682 1763.582 339.944 S 570.778 E 5973934 N 372299.2 E 2057.52 58.08 120.34 1766.273 1818.173 380.157 S 637.478 E 5973893 N 372365.2 E 2152.74 59.52 120.13 1815.598 1867.498 421.168 S 707.845 E 5973851 N 372434.8 E 2247.92 60.08 120.49 1863.475 1915.375 462.684 S 778.861 E 5973808 N 372505.1 E ~ 2342.71 58.28 120.79 1912.038 1963.938 504.167 S 848.898 E 5973765 N 372574.4 E 2437.97 55.09 121.36 1964.353 2016.253 545.245 S 917.074 E 5973723 N 372641.9 E 2533.28 54.37 122.29 2019.388 2071.288 586.275 S 983.19 E 5973681 N 372707.3 E 2628.24 54.44 122.44 2074.66 2126.56 627.61 S 1048.411 E 5973638 N 372771.8 E 2723.6 53.82 122.54 2130.535 2182.435 669.118 S 1113.591 E 5973596 N 372836.3 E 2818.86 57.74 122.47 2184.096 2235.996 711.437 S 1180.008 E 5973552 N 372901.9 E 2914.1 56.36 122.7 2235.897 2287.797 754.476 S 1247.348 E 5973508 N 372968.5 E 3009.6 59.05 122.13 2286.916 2338.816 797.74 S 1315.493 E 5973464 N 373035.9 E 3066.83 59.08 122.85 2316.336 2368.236 824.108 S 1356.898 E 5973437 N 373076.9 E 3161.83 59.65 122.76 2364.745 2416.645 868.394 S 1425.603 E 5973391 N 373144.8 E 3257.8 60.19 122.85 2412.846 2464.746 913.386 S 1495.404 E 5973345 N 373213.8 E 3352.56 59.44 121.67 2460.492 2512.392 957.109 S 1564.667 E 5973300 N 373282.3 E 3448.22 60.2 123.2 2508.583 2560.483 1001.462 S 1634.454 E 5973255 N 373351.4 E 3543.57 64.47 124.82 2552.847 2604.747 1048.704 S 1704.425 E 5973206 N 373420.5 E 3639.01 63.44 123.36 2594.753 2646.653 1096.766 S 1775.431 E 5973157 N 373490.7 E 3734.58 63.42 122.13 2637.502 2689.402 1143 S 1847.323 E 5973109 N 373561.8 E 3829.34 63.43 119.82 2679.9 2731.8 1186.613 S 1919.979 E 5973065 N 373633.7 E 3924.02 61.7 118.42 2723.523 2775.423 1227.51 S 1993.38 E 5973022 N 373706.4 E 4021.28 59.56 120.24 2771.224 2823.124 1269.011 S 2067.272 E 5972980 N 373779.5 E 4116.64 59.49 120.39 2819.587 2871.487 1310.495 S 2138.22 E 5972937 N 373849.8 E 4212.14 59.39 120.05 2868.143 2920.043 1351.885 S 2209.279 E 5972894 N 373920.1 E 4307.75 59.15 120.13 2916.999 2968.899 1393.089 S 2280.388 E 5972852 N 373990.5 E - 4403.13 59.15 119.84 2965.909 3017.809 1434.013 S 2351.313 E 5972810 N 374060.7 E 4498.27 59.36 119.85 3014.546 3066.446 1474.705 S 2422.237 E 5972768 N 374130.9 E 4593.77 59.85 119.48 3062.865 3114.765 1515.474 S 2493.815 E 5972726 N 374201.8 E 4689.06 60.52 119.62 3110.244 3162.144 1556.249 S 2565.737 E 5972684 N 374273 E 4784.49 60.5 119.79 3157.221 3209.121 1597.411 S 2637.887 E 5972642 N 374344.5 E 4879.88 61.28 119.97 3203.627 3255.527 1638.93 S 2710.149 E 5972599 N 374416 E 4975.53 62.33 119.62 3248.818 3300.718 1680.817 S 2783.305 E 5972556 N 374488.4 E 5071.16 62.12 119.34 3293.382 3345.282 1722.457 S 2856.962 E 5972513 N 374561.4 E 5166.74 61.97 119.5 3338.188 3390.088 1763.928 S 2930.502 E 5972470 N 374634.2 E 5262.38 61.85 119.57 3383.221 3435.121 1805.521 S 3003.912 E 5972427 N 374706.9 E 5358.09 61.84 120.05 3428.382 3480.282 1847.47 S 3077.131 E 5972384 N 374779.4 E 5453.74 61.69 119.82 3473.633 3525.533 1889.522 S 3150.158 E 5972341 N 374851.7 E 5549.12 61.41 120.07 3519.072 3570.972 1931.383 S 3222.824 E 5972298 N 374923.6 E 5644.49 62.47 120.78 3563.933 3615.833 1974.003 S 3295.391 E 5972254 N 374995.4 E 5740.35 63.16 121.03 3607.728 3659.628 2017.8 S 3368.555 E 5972209 N 375067.8 E 5835.75 63.71 121.52 3650.392 3702.292 2062.098 S 3441 .483 E 5972163 N 375140 E 5930.56 63.79 122.42 3692.326 3744.226 2107.121 S 3513.617 E 5972117 N 375211.3 E 6026.07 64.7 121.08 3733.829 3785.729 2152.381 S 3586.765 E 5972070 N 375283.7 E 6120.91 64 119.89 3774.883 3826.783 2195.755 S 3660.437 E 5972026 N 375356.6 E 6217.45 63.22 120.16 3817.793 3869.693 2239.026 S 3735.311 E 5971981 N 375430.7 E 6313.15 62.53 120.98 3861 .426 3913.326 2282.342 S 3808.646 E 5971937 N 375503.3 E 6407.14 61,91 121.33 3905.233 3957.133 2325.363 S 3879.81 E 5971892 N 375573.7 E 6503.53 61.36 121.6 3951.026 4002.926 2369.635 S 3952.155 E 5971847 N 375645.3 E 6598.97 60.73 122.14 3997.231 4049.131 2413.727 S 4023.076 E 5971802 N 375715.5 E 6694.66 60.42 121.69 4044.242 4096.142 2457.788 S 4093.822 E 5971756 N 375785.5 E 6790.21 60.42 121.7 4091.409 4143.309 2501.447 S 4164.525 E 5971712 N 375855.4 E 6885.92 60.12 121 .76 4138.873 4190.773 2545.157 S 4235.215 E 5971667 N 375925.3 E 6981 .49 60.8 122.81 4185.993 4237.893 2589.57 S 4305.504 E 5971621 N 375994.9 E 7077.11 61.13 122.74 4232.401 4284.301 2634.827 S 4375.798 E 5971575 N 376064.4 E 7170.96 60.5 123.34 4278.165 4330.065 2679.499 S 4444.484 E 5971529 N 376132.3 E 7267.29 60.57 122.79 4325.55 4377.45 2725.257 S 4514.771 E 5971482 N 376201.8 E 7363.67 60.77 122.56 4372.76 4424.66 2770.62 S 4585.499 E 5971435 N 376271.7 E 7458.59 60.8 122.34 4419.09 4470.99 2815.072 S 4655.409 E 5971390 N 376340.9 E 7553.8 60.99 121.74 4465.401 4517.301 2859.203 S 4725.925 E 5971344 N 376410.6 E 7649.57 61.43 122.51 4511.525 4563.425 2903.836 S 4797.005 E 5971298 N 376480.9 E 7744.65 60.64 121 .54 4557.57 4609.47 2947.95 S 4867.529 E 5971253 N 376550.7 E 7840.13 60.51 121.02 4604.478 4656.378 2991.13 S 4938.603 E 5971209 N 376621 E - 7935.99 60.45 121.27 4651.711 4703.611 3034.273 S 5009.995 E 5971164 N 376691.6 E 8031.78 60.47 121 .45 4698.938 4750.838 3077.644 S 5081 .159 E 5971120 N 376762.1 E 8127.33 60.66 121.41 4745.895 4797.795 3121.037 S 5152.165 E 5971075 N 376832.3 E 8223.03 60.58 121.19 4792.846 4844.746 3164.361 S 5223.42 E 5971031 N 376902.8 E 8317.95 60.8 121.17 4839.312 4891.212 3207.212 S 5294.232 E 5970987 N 376972.9 E 8414.32 60.85 120.41 4886.291 4938.191 3250.284 S 5366.515 E 5970942 N 377044.4 E 8507.31 61.01 120.32 4931.473 4983.373 3291.37 S 5436.642 E 5970900 N 377113.8 E 8605.14 60.96 119.74 4978.924 5030.824 3334.184 S 5510.709 E 5970856 N 377187.2 E 8700.59 60.51 119.93 5025.585 5077.485 3375.61 S 5582.94 E 5970813 N 377258.7 E 8798.44 61.51 119.22 5073.009 5124.909 3417.851 S 5657.378 E 5970770 N 377332.4 E 8890.5 61.44 119.13 5116.971 5168.871 3457.28 S 5728.001 E 5970729 N 377402.3 E 8986.59 61.23 119.34 5163.064 5214.964 3498.458 S 5801.575 E 5970687 N 377475.2 E 9081.94 61.21 119.35 5208.97 5260.87 3539.414 S 5874.423 E 5970645 N 377547.3 E 9177.3 61.29 118.67 5254.838 5306.738 3579.958 S 5947.538 E 5970603 N 377619.7 E 9272.66 61.77 118.99 5300.296 5352.196 3620.381 S 6020.975 E 5970561 N 377692.4 E 9368.12 61.65 119.5 5345.538 5397.438 3661.447 S 6094.319 E 5970519 N 377765.1 E - 9463,59 61.36 120.27 5391.085 5442.985 3703.253 S 6167.066 E 5970476 N 377837.1 E 9559.07 61.3 120.93 5436.894 5488.794 3745.896 S 6239.173 E 5970432 N 377908.5 E 9654.44 61.58 120.91 5482.488 5534.388 3788.938 S 6311.034 E 5970388 N 377979.6 E 9749.98 61.71 120.96 5527.863 5579.763 3832.16 S 6383.151 E 5970343 N 378050.9 E 9845.07 61.84 121.07 5572.834 5624.734 3875.33 S 6454.956 E 5970299 N 378122 E 9940.89 61.99 121.2 5617.945 5669.845 3919.041 S 6527.316 E 5970254 N 378193.6 E 10036.58 62.06 121.54 5662.832 5714.732 3963.033 S 6599.471 E 5970209 N 378265 E 10132.32 61.58 121.15 5708.044 5759.944 4006.933 S 6671.546 E 5970163 N 378336.3 E 10227.86 61.08 121 .99 5753.881 5805.781 4050.817 S 6742.965 E 5970118 N 378407 E 10323.36 60.84 121.5 5800.239 5852.139 4094.747 S 6813.968 E 5970073 N 378477.2 E 10419.39 61.35 121.5 5846.656 5898.556 4138.672 S 6885.646 E 5970028 N 378548.1 E 10514.79 61.87 121.03 5892.016 5943.916 4182.228 S 6957.385 E 5969983 N 378619,1 E 10610.18 62.49 121.3 5936.534 5988.434 4225.887 S 7029.573 E 5969938 N 378690.5 E 10705.37 62.06 120.61 5980.819 6032.719 4269.229 S 7101.832 E 5969894 N 378762 E 10801.74 61.44 120.38 6026.433 6078.333 4312.308 S 7174.98 E 5969849 N 378834.4 E 10897.11 60.99 120.69 6072.356 6124.256 4354.774 S 7246.973 E 5969806 N 378905.7 E 10990.53 60.87 120.74 6117.746 6169.646 4396.479 S 7317.171 E 5969763 N 378975.2 E 11087.62 60.7 119.62 6165.136 6217.036 4439.079 S 7390.422 E 5969719 N 379047.7 E 11180.76 60.2 120.11 6211.071 6262.971 4479.425 S 7460.687 E 5969677 N 379117.3 E 11278.44 59.86 121.18 6259.868 6311.768 4522.555 S 7533.487 E 5969633 N 379189.3 E 11373.9 60.58 121.88 6307.28 6359.18 4565.883 S 7604.106 E 5969589 N 379259.2 E - 11469.17 60.67 122.41 6354.013 6405.913 4610.056 S 7674.4 E 5969543 N 379328.7 E 11564.55 60.88 122,11 6400.581 6452.481 4654.485 S 7744.79 E 5969498 N 379398.3 E 11659.43 61.3 122.05 6446.449 6498.349 4698.596 S 7815.164 E 5969452 N 379467.9 E 11755.07 61.57 121 .46 6492.18 6544.08 4742.803 S 7886.588 E 5969407 N 379538.6 E 11850.32 60.7 121.34 6538.162 6590.062 4786.263 S 7957.787 E 5969362 N 379609 E 11945.4 61.36 121.49 6584.214 6636.114 4829.621 S 8028.776 E 5969318 N 379679.3 E 12040.66 62.01 121.51 6629.397 6681 .297 4873.439 S 8100.28 E 5969273 N 379750 E 12135.95 62.68 121.66 6673.625 6725.525 4917.646 S 8172.18 E 5969227 N 379821.1 E 12231 . 1 9 62.4 122.05 6717.543 6769.443 4962.248 S 8243.961 E 5969181 N 379892.2 E 12326.38 62.13 122.51 6761.843 6813.743 5007.243 S 8315.193 E 5969135 N 379962.6 E 12421.47 61.89 122.82 6806.471 6858.371 5052.562 S 8385.88 E 5969089 N 380032.5 E 12516.28 62.41 124.41 6850.764 6902.664 5098.971 S 8455.685 E 5969041 N 380101.5 E 12611.29 64.87 125.93 6892.948 6944.848 5148.011 S 8525.26 E 5968991 N 380170.2 E 12706.69 67.65 126.49 6931.351 6983.251 5199.597 S 8595.711 E 5968938 N 380239.8 E 12801.36 69.63 127.92 6965.833 7017.733 5252.911 S 8665.924 E 5968884 N 380309.1 E 12896.98 72.25 131.67 6997.065 7048.965 5310.757 S 8735.329 E 5968824 N 380377.5 E --- 12992.03 74.45 134.76 7024.304 7076.204 5373.11 S 8801.673 E 5968761 N 380442.8 E 13087.61 76.79 138.26 7048.047 7099.947 5440.274 S 8865.366 E 5968693 N 380505.3 E 13190.11 80.7 142.53 7068.057 7119.957 5517.709 S 8929.404 E 5968614 N 380568 E 13288.3 84.07 146.62 7081.072 7132.972 5596.995 S 8985.785 E 5968534 N 380623 E 13381.02 89.57 149.81 7086.215 7138.115 5675.652 S 9034.518 E 5968455 N 380670.4 E 13479.3 91.17 150.09 7085.581 7137.481 5760.717 S 9083.73 E 5968369 N 380718.1 E 13574.73 90.63 150.43 7084.082 7135.982 5843.567 S 9131.063 E 5968285 N 380764.1 E 13668.11 91.05 153.17 7082.712 7134.612 5925.846 S 9175.181 E 5968202 N 380806.8 E 13765.7 91.48 155.93 7080.557 7132.457 6013.936 S 9217.103 E 5968113 N 380847.2 E 13861.52 91.73 156.17 7077.874 7129.774 6101.471 S 9255.985 E 5968025 N 380884.5 E 13956.92 90.68 150.79 7075.866 7127.766 6186.781 S 9298.557 E 5967939 N 380925.7 E 14052.36 91.24 151 .77 7074.267 7126.167 6270.467 S 9344.412 E 5967854 N 380970.1 E 14144.99 90.86 152.24 7072.569 7124.469 6352.244 S 9387.884 E 5967772 N 381012.1 E 14243.2 90.31 151.86 7071.567 7123.467 6438.994 S 9433.913 E 5967684 N 381056.7 E 14336.13 89.69 150.99 7071.567 7123.467 6520.603 S 9478.361 E 5967602 N 381099.7 E 14432.12 89.94 150.6 7071.877 7123.777 6604.39 S 9525.198 E 5967518 N 381145.1 E 14530.5 89.88 150.38 7072.031 7123.931 6690.007 S 9573.658 E 5967431 N 381192.1 E 14625.78 90.37 152.22 7071.823 7123.723 6773.577 S 9619.411 E 5967347 N 381236.4 E 14721.4 90.74 151.58 7070.897 7122.797 6857.922 S 9664.447 E 5967262 N 381280 E 14816.91 90 151.28 7070.28 7122.18 6941.799 S 9710.121 E 5967177 N 381324.2 E 14909.92 89.51 152.55 7070.678 7122.578 7023.855 S 9753.907 E 5967094 N 381366.6 E -- 15007.69 89.38 153.14 7071.625 7123.525 7110.843 S 9798.527 E 5967006 N 381409.7 E 15103.13 89.38 154.43 7072.658 7124.558 7196.46 S 9840.684 E 5966920 N 381450.4 E 15198.4 91.24 153.54 7072.142 7124.042 7282.071 S 9882.467 E 5966834 N 381490.7 E 15292.05 91.67 153.99 7069.765 7121.665 7366.047 S 9923.851 E 5966749 N 381530.7 E 15390.08 89.57 152.56 7068.704 7120.604 7453.592 S 9967.93 E 5966661 N 381573.3 E 15485.81 90.06 152.39 7069.013 7120.913 7538.486 S 10012.17 E 5966575 N 381616 E 15580.9 89.32 147.29 7069.528 7121.428 7620.674 S 10059.93 E 5966492 N 381662.4 E 15676.46 88.83 146.88 7071.07 7122.97 7700.884 S 10111.85 E 5966411 N 381712.9 E 15771.67 89.63 146.19 7072.35 7124.25 7780.302 S 10164.34 E 5966331 N 381764.1 E 15867.15 89.2 148.66 7073.325 7125.225 7860.751 S 10215.74 E 5966250 N 381814.1 E 15961.79 89.57 148.52 7074.341 7126.241 7941.518 S 10265.06 E 5966168 N 381862 E 16055.98 89.94 151.05 7074.744 7126.644 8022.904 S 10312.46 E 5966086 N 381908 E 16153.25 90.37 153.62 7074.48 7126.38 8109.046 S 10357.62 E 5965999 N 381951.7 E 16248.68 91.24 153.21 7073.14 7125.04 8194.377 S 10400.32 E 5965913 N 381992.9 E 16342.23 89.63 153.53 7072.429 7124.329 8277.998 S 10442.25 E 5965828 N 382033.4 E 16437.33 89.01 153.43 7073.558 7125.458 8363.085 S 10484.71 E 5965743 N 382074.4 E -- 16534.8 88.64 151.7 7075.557 7127.457 8449.571 S 10529.61 E 5965655 N 382117.8 E 16627.18 89.75 151 .98 7076.855 7128.755 8531.007 S 10573.2 E 5965573 N 382160 E 16726.02 88.77 151.17 7078.131 7130.031 8617.922 S 10620.24 E 5965486 N 382205.6 E 16821.46 86.85 147.6 7081.779 7133.679 8699.982 S 10668.8 E 5965403 N 382252.7 E 16917.04 85.92 148.34 7087.806 7139.706 8780.849 S 10719.39 E 5965321 N 382301.9 E 17012.65 86.67 148.84 7093.984 7145.884 8862.277 S 10769.11 E 5965239 N 382350.2 E 17108.14 96.18 150.81 7091.612 7143.512 8944.702 S 10817.04 E 5965155 N 382396.7 E 17202.98 100.61 151.37 7077.769 7129.669 9026.811 S 1 0862.39 E 5965073 N 382440.7 E 17241 .11 100.8 151.06 7070.686 7122.586 9059.648 S 10880.43 E 5965039 N 382458.2 E 17320 100.8 151.06 7055.904 7107.804 9127.464 S 382494.5 E 10917.93 E 5964971 N -- ~ ) ') ¿) œ-;? 'Ie¡ 12 -May-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C02-51 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) MAY 13 2003 Alaska 0.1 & Gas Cons. Comm' . Aná10rage "lIOn ç:¡-.... "J-.. ((j I ~~ <ã' Sperry-Sun Drilling Services .~,~ Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-51 Gyro Job No. AKF00002323383, Surveyed: 1 May, 2003 Survey Report 9 May, 2003 / -=.... Your Ref: API 501032044100 Surface Coordinates: 5974283.88 N, 371734.28 E (70020' 16.7129" N, 151002' 26.7931" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974283.88 N, 128265.72 W (Grid) Surface Coordinates relative to Structure: 158.72 S, 19.51 E (True) Kelly Bushing: 51. 90ft above Mean Sea Level Elevation relative to Project V Reference: 51.90ft Elevation relative to Structure: 51.90ft spe...........y-sul'l DRIL.L.ING seRVIc:es A Halliburton Company DEF N TIVE Survey Ref: svy229 Dríl/Quest 3.03.02.005 Page 2 0(2 9 May, 2003 - 15:02 --- ------------.----- 348.91 Tolerable Gyro 349.00 0.00 0.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) /---.., Survey tool program for CD2-51 Gyro Based upon Minimum Curvature type calculations. at a Measured Depth of 349.00ft., , The Bottom Hole Displacement is 5.71ft.. in the Direction of 56.919° (True). Magnetic Declination at Surface is 24.662°(12-Mar-03) The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2073' FNL, 1502' FEL and calculated along an Azimuth of 151.900° (True). All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 51.90' MSL. Northings and Eastings are relative to 2073' FNL, 1502' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -51.90 0.00 0.00 N 0.00 E 5974283.88 N 371734.28 E 0.00 Tolerable Gyro 72.00 0.000 0.000 20.10 72.00 0.00 N 0.00 E 5974283.88 N 371734.28 E 0.000 0.00 167.00 0.500 40.000 115.10 167.00 0.32 N 0.27 E 5974284.19 N 371734.55 E 0.526 -0.15 258.00 1.650 54.000 206.08 257.98 1.39 N 1.58 E 5974285.24 N 371735.89 E 1.287 -0.48 ~...., 349.00 2,950 66.000 297.01 348.91 3.11 N 4.78 E 5974286.91 N 371739.11 E 1.516 -0.50 DEFINITIVE Sperry-Sun Drilling Services Survey Report for Alpine CD-2 ~ CD2~51 Gyro Your Ref: AP/501032044100 Job No. AKF00002323383, Surveyed: 1 May, 2003 ) ) AOGCC Helen Warman 333 W, 7th Ave, Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-51 (Sag Corrected) Dear Dear Sir/Madam: Enclosed is one disk with the *,PTT and *,PDF files, Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0,00' MD 0,00' MD 17,320,00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 '7 I 1/ / ;/ Date J r:JJJtß I Signed ;~ O/tJ.N-/( Please call me at 273-3545 if you have any questions or concerns, Regards, Carl Ulrich Survey Manager Attachment(s) 01-Feb-05 ?:2G~-;{CI7 -\ I ') c:? od -dcf c¡ 12-May-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C02-51 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 17320.00'MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED MAY 13 2003 !ðJaska at: & Gas Cons, Commission Anchcege CJ'-. ~ '1)-- j , '0. a ~ Sperry-Sun Drilling Services ..--. Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-51 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 Survey Report 9 May, 2003 ,/- Your Ref: API 501032044100 Surface Coordinates: 5974283.88 N, 371734.28 E (70020'16.7129" N, 151002' 26.7931" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974283.88 H, 128265.72 W (Grid) Surface Coordinates relative to Structure: 158.72 S, 19.51 E (True) Kelly Bushing: 51.90ft above Mean Sea Level Elevation relative to Project V Reference: 51.90ft Elevation relative to Structure: 51. 90ft 5pE!r'r'Y-SU'" DRILLING seRVices A Halliburton Company DEF,N'TIVE SlIrvey Ref: svy244 Sperry-Sun Drilling Services DEF NTIVE Survey Report for A/pine CD~2 ~ CD2-51 Your Ref: AP/501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 349.00 2.950 66.000 297.01 348.91 3.11 N 4.78 E 5974286.91 N 371739.11 E -0.50 AK-6 BP JFR-AK 465.80 4.560 80.390 413.55 465.45 5.11 N 12.11 E 5974288.78 N 371746.47 E 1.587 1.19 556.58 6.230 92.160 503.93 555.83 5.53 N 20.59 E 5974289.06 N 371754.96 E 2.198 4.82 645.24 8,770 100.230 591.83 643.73 4.15 N 32.05 E 5974287.48 N 371766.39 E 3.095 11 .44 ,..-... - 735.20 10.810 102.530 680.47 732.37 1.10 N 47.03 E 5974284.17 N 371781.32 E 2.309 21.18 824.35 13.570 108.790 767.61 819.51 4.095 65.10 E 5974278.68 N 371799.30 E 3.428 34.27 914.66 18.120 112.740 854.4 7 906.37 12.93 5 88.09 E 5974269.44 N 371822.14 E 5.175 52.90 1009.78 21.700 119.140 943.90 995.80 27.22 S 117.11 E 5974254.66 N 371850.91 E 4.401 79.17 1104.86 26.690 124.480 1030.61 1082.51 47.88 S 150.09 E 5974233.44 N 371883.53 E 5.726 112.93 1200.27 29.280 123.800 1114.86 1166.76 73.00 5 187.15 E 5974207.69 N 371920.15 E 2.735 152.54 1295.29 30.040 122.820 1197.43 1249.33 98.81 5 226.44 E 5974181.21 N 371959.00 E 0.949 193.82 1390.75 32.660 123.820 1278.94 1330.84 126.11 5 267.93 E 5974153.21 N 372000.01 E 2.798 237.44 1486.03 36.660 125.250 1357.30 1409.20 156.84 5 312.54 E 5974121.71 N 372044.09 E 4.284 285.56 1581.40 38.310 126.190 1432.98 1484.88 190.735 359.65 E 5974087.02 N 372090.61 E 1.831 337.65 1676.24 40.170 126.420 1506.43 1558.33 226.25 5 407.99 E 5974050.68 N 372138.34 E 1.967 391.75 1771.64 41.410 125.760 1578.65 1630.55 262.96 5 458.36 E 5974013.12 N 372188.07 E 1.376 447.86 1866.91 44.750 125.170 1648.23 1700.13 300.705 511.35 E 5973974.48 N 372240.41 E 3.531 506.11 1962.36 51.870 121.890 1711.68 1763.58 339.94 5 570.78 E 5973934.22 N 372299.16 E 7.887 568.72 2057.52 58.080 120.340 1766.27 1818.17 380.165 637.48 E 5973892.87 N 372365.16 E 6.660 635.61 2152.74 59.520 120.130 1815.60 1867.50 421.175 707.84 E 5973850.67 N 372434.82 E 1.524 704.93 2247.92 60.080 120.490 1863.48 1915.38 462.68 5 778.86 E 5973807.94 N 372505.11 E 0.673 775.00 r- 2342.71 58.280 120.790 1912.04 1963.94 504.175 848.90 E 5973765.27 N 372574.43 E 1.918 844.58 2437.97 55.090 121.360 1964.35 2016.25 545.24 5 917.07 E 5973723.03 N 372641.89 E 3.386 912.93 2533.28 54.370 122.290 2019.39 2071.29 586.28 5 983.19 E 5973680.87 N 372707.30 E 1.098 980.26 2628.24 54.440 122.440 2074.66 2126.56 627.61 5 1048.41 E 5973638.43 N 372771.80 E 0.148 1047.45 2723.60 53.820 122.540 2130.54 2182.44 669.125 1113.59 E 5973595.81 N 372836.26 E 0.656 1114.76 2818.86 57.740 122.470 2184.10 2236.00 711.44 S 1180.01 E 5973552.36 N 372901.95 E 4.116 1183.38 2914.10 56.360 122.700 2235.90 2287.80 754.48 5 1247.35 E 5973508.18 N 372968.54 E 1.463 1253.06 3009.60 59.050 122.130 2286.92 2338.82 797.745 1315.49 E 5973463.75 N 373035.93 E 2.862 1323.32 3066.83 59.080 122.850 2316.34 2368.24 824.11 5 1356.90 E 5973436.68 N 373076.88 E 1.080 1366.08 3161.83 59.650 122.760 2364.75 2416.65 868.39 5 1425.60 E 5973391.23 N 373144.82 E 0.606 1437.51 3257.80 60.190 122.850 2412.85 2464.75 913.39 5 1495.40 E 5973345.05 N 373213.84 E 0.568 1510.08 3352.56 59.440 121.670 2460.49 2512.39 957.11 5 1564.67 E 5973300.15 N 373282.35 E 1.336 1581.27 3448.22 60.200 123.200 2508.58 2560.48 1001.46 S 1634.45 E 5973254.61 N 373351.36 E 1.595 1653.26 3543.57 64.4 70 124.820 2552.85 2604.75 1048.70 S 1704.42 E 5973206.18 N 373420.52 E 4.724 1727.89 ____ ________.n____________ - -- _..-----~--- - 9 May, 2003 - 15:02 Page 20'8 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 ~ CD2~51 Your Ref: API 501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 NortlJ Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3639.01 63.440 123.360 2594.75 2646.65 1096.778 1775.43 E 5973156.90 N 373490.69 E 1.747 1803.74 3734.58 63.420 122.130 2637.50 2689.40 1143.008 1847.32 E 5973109.45 N 373561.78 E 1.151 1878.38 3829.34 63.430 119.820 2679.90 2731.80 1186.61 8 1919.98 E 5973064.60 N 373633.68 E 2.180 1951 .08 3924.02 61.700 118.420 2723.52 2775.42 1227.51 8 1993.38 E 5973022.45 N 373706.37 E 2.250 2021.72 ,.,-. 4021.28 59.560 120.240 2771.22 2823.12 1269.01 8 2067.27 E 5972979.69 N 373779.54 E 2.739 2093.14 4116.64 59.490 120.390 2819.59 2871.49 1310.498 2138.22 E 5972937.00 N 373849.77 E 0.154 2163.15 4212.14 59.390 120.050 2868.14 2920.04 1351.898 2209.28 E 5972894.40 N 373920.11 E 0.324 2233.13 4307.75 59.150 120.130 2917.00 2968.90 1393.098 2280.39 E 5972851.99 N 373990.51 E 0.261 2302.97 4403.13 59.1 50 119.840 2965.91 3017.81 1434.01 8 2351.31 E 5972809.86 N 374060.72 E 0.261 2372.48 4498.27 59.360 119.850 3014.55 3066.45 1474.71 8 2422.24 E 5972767.96 N 374130.94 E 0.221 2441.78 4593.77 59.850 119.480 3062.87 3114.77 1515.478 2493.81 E 5972725.97 N 374201.81 E 0.612 2511.46 4689.06 60.520 119.620 3110.24 3162.14 1556.25 8 2565.74 E 5972683.97 N 374273.02 E 0.715 2581.30 4784.49 60.500 119.790 3157.22 3209.12 1597.41 8 2637.89 E 5972641.58 N 374344.46 E 0.156 2651.60 4879.88 61.280 119.970 3203.63 3255.53 1638.93 8 2710.15 E 5972598.83 N 374416.00 E 0.834 2722.26 4975.53 62.330 119.620 3248.82 3300.72 1680.828 2783.31 E 5972555.70 N 374488.43 E 1.144 2793.66 5071.16 62.120 119.340 3293.38 3345.28 1722.46 8 2856.96 E 5972512.81 N 374561.36 E 0.340 2865.09 5166.74 61.970 119.500 3338.19 3390.09 1763.93 8 2930.50 E 5972470.08 N 374634.18 E 0.216 2936.31 5262.38 61.850 119.570 3383.22 3435.12 1805.52 8 3003.91 E 5972427.24 N 374706.87 E 0.141 3007.58 5358.09 61.840 120.050 3428.38 3480.28 1847.478 3077.13 E 5972384.04 N 374779.36 E 0.442 3079.07 5453.74 61.690 119.820 3473.63 3525.53 1889.52 8 3150.16 E 5972340.75 N 374851.66 E 0.264 3150.56 5549.12 61.410 120.070 3519.07 3570.97 1931.388 3222.82 E 5972297.65 N 374923.60 E 0.373 3221.71 ~" 5644.49 62.470 120.780 3563.93 3615.83 1974.008 3295.39 E 5972253.80 N 374995.42 E 1.291 3293.49 5740.35 63.160 121.030 3607.73 3659.63 2017.808 3368.55 E 5972208.76 N 375067.83 E 0.756 3366.58 5835.75 63,71 0 121.520 3650.39 3702.29 2062.108 3441.48 E 5972163.22 N 375139.99 E 0.737 3440.01 5930.56 63.790 122.420 3692.33 3744.23 2107.128 3513.62 E 5972116.97 N 375211.34 E 0.856 3513.70 6026.07 64.700 121.080 3733.83 3785.73 2152.38 8 3586.76 E 5972070.46 N 375283.70 E 1.583 3588.08 6120.91 64.000 119.890 3774.88 3826.78 2195.758 3660.44 E 5972025.83 N 375356.62 E 1.351 3661.04 6217.45 63.220 120.160 3817.79 3869.69 2239.038 3735.31 E 5971981.29 N 375430.75 E 0.846 3734.48 6313.15 62.530 120.980 3861.43 3913.33 2282.34 8 3808.65 E 5971936.72 N 375503.33 E 1.049 3807.23 6407.14 61.910 121.330 3905.23 3957.13 2325.36 8 3879.81 E 5971892.49 N 375573.75 E 0.737 3878.70 6503.53 61.360 121.600 3951.03 4002.93 2369.648 3952.16 E 5971846.99 N 375645.32 E 0.622 3951.83 6598.97 60.730 122.140 3997.23 4049.13 2413.738 4023.08 E 5971801.69 N 375715.48 E 0.825 4024.13 6694.66 60.420 121.690 4044.24 4096.14 2457.798 4093.82 E 5971756.43 N 375785.46 E 0.522 4096.32 6790.21 60.420 121.700 4091.41 4143.31 2501.45 S 4164.53 E 5971711.56 N 375855.41 E 0.009 4168.1 3 6885.92 60.120 121.760 4138.87 4190.77 2545.16 S 4235.21 E 5971666.65 N 375925.34 E 0.318 4239.99 --------- ------- ---- 9 May, 2003 - 15:02 Page 3 0'8 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2~51 Your Ref: AP/501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub~Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6981.49 60.800 122.810 4185.99 4237.89 2589.57 S 4305.50 E 5971621.04 N 375994.86 E 1.192 4312.27 7077.11 61.130 122.740 4232.40 4284.30 2634.83 S 4375.80 E 5971574.59 N 376064.37 E 0.351 4385.30 7170.96 60.500 123.340 4278.17 4330.07 2679.50 S 4444.48 E 5971528.75 N 376132.28 E 0.873 4457.06 7267.29 60.570 122.790 4325.55 4377.45 2725.26 S 4514.77 E 5971481.80 N 376201.77 E 0.502 4530.53 .- 7363.67 60.770 122.560 4372.76 4424.66 2770.62 S 4585.50 E 5971435.23 N 376271.72 E 0.294 4603.86 7458.59 60.800 122.340 4419.09 4470.99 2815.07 S 4655.41 E 5971389.59 N 376340.86 E 0.205 4676.00 7553.80 60.990 121.740 4465.40 4517.30 2859.20 S 4725.93 E 5971344.26 N 376410.61 E 0.586 4748.15 7649.57 61.430 122.510 4511.52 4563.42 2903.84 S 4797.00 E 5971298.42 N 376480.91 E 0.841 4821.00 77 44.65 60.640 121.540 4557.57 4609.47 2947.95 S 4867.53 E 5971253.10 N 376550.67 E 1.219 4893.13 7840.13 60.51 0 121.020 4604.48 4656.38 2991.13 S 4938.60 E 5971208.71 N 376621.00 E 0.494 4964.70 7935.99 60.450 121.270 4651.71 4703.61 3034.27 S 5010.00 E 5971164.35 N 376691.64 E 0.235 5036.38 8031.78 60.470 121.450 4698.94 4750.84 3077.64 S 5081.16 E 5971119.77 N 376762.05 E 0.165 5108.16 8127.33 60.660 121.410 4745.90 4797.80 3121.04 S 5152.17 E 5971075.17 N 376832.31 E 0.202 5179.88 8223.03 60.580 121.190 4792.85 4844.75 3164.36 S 5223.42 E 5971030.63 N 376902.81 E 0.217 5251.66 8317.95 60.800 121.170 4839.31 4891.21 3207.21 S 5294.23 E 5970986.58 N 376972.88 E 0.233 5322.81 8414.32 60.850 120.410 4886.29 4938.19 3250.28 S 5366.52 E 5970942.28 N 377044.41 E 0.691 5394.86 8507.31 61.010 120.320 4931.47 4983.37 3291.37 S 5436.64 E 5970900.00 N 377113.83 E 0.192 5464.13 8605.14 60.960 119.740 4978.92 5030.82 3334.18 S 5510.71 E 5970855.92 N 377187.15 E 0.521 5536.78 8700.59 60.510 119.930 5025.58 5077.48 3375.61 S 5582.94 E 5970813.27 N 377258.66 E 0.502 5607.35 8798.44 61.510 119.220 5073.01 5124.91 3417.85 S 5657.38 E 5970769.76 N 377332.37 E 1.203 5679.67 8890.50 61.440 119.130 5116.97 5168.87 3457.28 S 5728.00 E 5970729.13 N 377402.31 E 0.115 5747.72 ~. 8986.59 61.230 119.340 5163.06 5214.96 3498.46 S 5801.57 E 5970686.70 N 377475.16 E 0.291 5818.69 9081.94 61.210 119.350 5208.97 5260.87 3539.41 S 5874.42 E 5970644.50 N 377547.30 E 0.023 5889.14 9177.30 61.290 118.670 5254.84 5306.74 3579.96 S 5947.54 E 5970602.71 N 377619.71 E 0.631 5959.34 9272.66 61.770 118.990 5300.30 5352.20 3620.38 S 6020.97 E 5970561.04 N 377692.45 E 0.583 6029.59 9368.12 61.650 119.500 5345.54 5397.44 3661.45 S 6094.32 E 5970518.72 N 377765.08 E 0.487 6100.36 9463.59 61.360 120.270 5391.09 5442.99 3703.25 S 6167.07 E 5970475.68 N 377837.10 E 0.771 6171.50 9559.07 61.300 120.930 5436.89 5488.79 3745.90 S 6239.17 E 5970431.81 N 377908.4 7 E 0.610 6243.08 9654.44 61.580 120.910 5482.49 5534.39 3788.94 S 6311.03 E 5970387.54 N 377979.58 E 0.294 6314.90 9749.98 61.710 120.960 5527.86 5579.76 3832.16 S 6383.15 E 5970343.10 N 378050.95 E 0.144 6386.99 9845.07 61.840 121.070 5572.83 5624.73 3875.33 S 6454.96 E 5970298.70 N 378122.00 E 0.171 6458.89 9940.89 61.990 121.200 5617.94 5669.84 3919.04 S 6527.32 E 5970253.76 N 378193.60 E 0.197 6531.53 10036.58 62.060 121.540 5662.83 5714.73 3963.03 S 6599.47 E 5970208.54 N 378265.00 E 0.322 6604.33 10132.32 61 .580 121.150 5708.04 5759.94 4006.93 S 6671.55 E 5970163.42 N 378336.31 E 0.617 6677.00 10227.86 61.080 121.990 5753.88 5805.78 4050.82 S 6742.97 E 5970118.32 N 378406.97 E 0.932 6749.35 ----------.. --- - -----~--- 9 May, 2003 - 15:02 Page 4 of 8 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2~51 Your Ref: AP/501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10323.36 60.840 121.500 5800.24 5852.14 4094.75 S 6813.97 E 5970073.18 N 378477.21 E 0.514 6821.55 10419.39 61.350 121.500 5846.66 5898.56 4138.67 S 6885.65 E 5970028.03 N 378548.13 E 0.531 6894.05 10514.79 61.870 121.030 5892.02 5943.92 4182.23 S 6957.38 E 5969983.26 N 378619.11 E 0.696 6966.27 10610.18 62.490 121.300 5936.53 5988.43 4225.89 S 7029.57 E 5969938.37 N 378690.54 E 0.697 7038.78 ,.-. 10705.37 62.060 120.610 5980.82 6032.72 4269.23 S 7101.83 E 5969893.80 N 378762.05 E 0.785 7111.05 10801.74 61 .440 120.380 6026.43 6078.33 4312.31 5 7174.98 E 5969849.47 N 378834.45 E 0.677 7183.50 10897.11 60.990 120.690 6072.36 6124.26 4354.77 5 7246.97 E 5969805.78 N 378905.70 E 0.551 7254.87 10990.53 60.870 120.740 6117.75 6169.65 4396.48 S 7317.17E 5969762.88 N 378975.18 E 0.137 7324.73 11087.62 60.700 119.620 6165.14 6217.04 4439.08 5 7390.42 E 5969719.04 N 379047.69 E 1.022 7396.81 11180.76 60.200 120.110 6211.07 6262.97 4479.435 7460.69 E 5969677.49 N 379117.25 E 0.705 7465.49 11278.44 59.860 121.180 6259.87 6311.77 4522.55 5 7533.49 E 5969633.13 N 379189.31 E 1.011 7537.83 11373.90 60.580 121.880 6307.28 6359.18 4565.88 5 7604.11 E 5969588.59 N 379259.17 E 0.987 7609.31 11469.17 60.670 122.410 6354.01 6405.91 4610.065 7674.40 E 5969543.23 N 379328.70 E 0.494 7681.39 11564.55 60.880 122.110 6400.58 6452.48 4654.49 5 7744.79 E 5969497.60 N 379398.32 E 0.352 7753.73 11659.43 61.300 122.050 6446.45 6498.35 4698.60 5 7815.16 E 5969452.29 N 379467.93 E 0.446 7825.79 11755.07 61.570 121.460 6492.18 6544.08 4742.805 7886.59 E 5969406.87 N 379538.59 E 0.611 7898.43 11850.32 60.700 121.340 6538.16 6590.06 4786.26 5 7957.79 E 5969362.20 N 379609.03 E 0.920 7970.30 11945.40 61.360 121.490 6584.21 6636.11 4829.62 5 8028.78 E 5969317.63 N 379679.27 E 0.708 8041.99 12040.66 62.010 121.510 6629.40 6681.30 4873.44 5 8100.28 E 5969272.60 N 379750.01 E 0.683 8114.32 12135.95 62.680 121.660 6673.63 6725.53 4917.655 8172.18 E 5969227.17 N 379821.15 E 0.717 8187.18 12231 .19 62.400 122.050 6717.54 6769.44 4962.25 5 8243.96 E 5969181.34 N 379892.15 E 0.467 8260.34 .r---"-_", 12326.38 62.130 122.510 6761.84 6813.74 5007.245 8315.19 E 5969135.14 N 379962.61 E 0.513 8333.58 12421.47 61.890 122.820 6806.47 6858.37 5052.56 5 8385.88 E 5969088.61 N 380032.51 E 0.383 8406.85 12516.28 62.410 124.410 6850.76 6902.66 5098.975 8455.69 E 5969041.02 N 380101.51 E 1.581 8480.67 12611.29 64.870 125.930 6892.95 6944.85 5148.01 5 8525.26 E 5968990.80 N 380170.24 E 2.959 8556.70 12706.69 67.650 126.490 6931.35 6983.25 5199.605 8595.71 E 5968938.01 N 380239.79 E 2.963 8635.39 12801.36 69.630 127.920 6965.83 7017.73 5252.91 5 8665.92 E 5968883.51 N 380309.08 E 2.521 8715.49 12896.98 72.250 131.670 6997.07 7048.97 5310.765 8735.33 E 5968824.48 N 380377.49 E 4.609 8799.20 12992.03 74.450 134.760 7024.30 7076.20 5373.11 5 8801.67 E 5968761.00 N 380442.76 E 3.880 8885.46 13087.61 76.790 138.260 7048.05 7099.95 5440.27 5 8865.37 E 5968692.76 N 380505.29 E 4.310 8974.70 13190.11 80.700 142.530 7068.06 7119.96 5517.71 5 8929.40 E 5968614.24 N 380568.00 E 5.589 9073.17 13288.30 84.070 146.620 7081.07 7132.97 5597.005 8985.79 E 5968534.00 N 380623.01 E 5.368 9169.67 13381.02 89.570 149.810 7086.22 7138.12 5675.65 5 9034.52 E 5968454.52 N 380670.39 E 6.854 9262.01 13479.30 91.170 150.090 7085.58 7137.48 5760.72 S 9083.73 E 5968368.63 N 380718.14 E 1.653 9360.23 13574.73 90.630 150.430 7084.08 7135.98 5843.57 S 9131.06 E 5968284.98 N 380764.05 E 0.669 9455.61 ________ ____ 6__--__-_.--- ____ ____.______ ...__ 9 May, 2003 - 15:02 Page 5 of 8 Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD~2 ~ CD2~51 Your Ref: AP/501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub~Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13668.11 91.050 153.170 7082.71 7134.61 5925.85 8 9175.18 E 5968201.96 N 380806.76 E 2.968 9548.97 13765.70 91.480 155.930 7080.56 7132.46 6013.94 8 9217.10 E 5968113.16 N 380847.17 E 2.862 9646.42 13861.52 91.730 156.170 7077.87 7129.77 6101.478 9255.99 E 5968024.98 N 380884.54 E 0.362 9741.95 13956.92 90.680 150.790 7075.87 7127.77 6186.788 9298.56 E 5967938.95 N 380925.65 E 5.745 9837.26 ,- 14052.36 91.240 151.770 7074.27 7126.17 6270.478 9344.41 E 5967854.49 N 380970.07 E 1.183 9932.68 14144.99 90.860 152.240 7072.57 7124.47 6352.24 8 9387.88 E 5967771.98 N 381012.13 E 0.652 10025.29 14243.20 90.310 151.860 7071.57 7123.47 6438.99 8 9433.91 E 5967684.46 N 381056.67 E 0.681 10123.49 14336.13 89.690 150.990 7071.57 7123.47 6520.60 8 9478.36 E 5967602.10 N 381099.72 E 1.150 10216.42 14432.12 89.940 150.600 7071.88 7123.78 6604.39 8 9525.20 E 5967517.53 N 381145.11 E 0.483 10312.39 14530.50 89.880 150.380 7072.03 7123.93 6690.01 8 9573.66 E 5967431.09 N 381192.10 E 0.232 10410.74 14625.78 90.370 152.220 7071.82 7123.72 6773.58 8 9619.41 E 5967346.75 N 381236.42 E 1.998 10506.01 14721.40 90.740 151.580 7070.90 7122.80 6857.92 8 9664.45 E 5967261.65 N 381280.01 E 0.773 10601.63 14816.91 90.000 151.280 7070.28 7122.18 6941.80 8 9710.12 E 5967177.00 N 381324.24 E 0.836 10697.1 3 14909.92 89.510 152.550 7070.68 7122.58 7023.85 8 9753.91 E 5967094.21 N 381366.62 E 1 .464 10790.14 15007.69 89.380 153.140 7071.63 7123.53 7110.848 9798.53 E 5967006.47 N 381409.74 E 0.618 10887.89 15103.13 89.380 154.430 7072.66 7124.56 7196.468 9840.68 E 5966920.15 N 381450.43 E 1.352 10983.27 15198.40 91.240 153.540 7072.14 7124.04 7282.078 9882.47 E 5966833.83 N 381490.74 E 2.164 11078.47 15292.05 91.670 153.990 7069.76 7121.66 7366.05 8 9923.85 E 5966749.16 N 381530.68 E 0.665 11172.04 15390.08 89.570 152.560 7068.70 7120.60 7453.59 8 9967.93 E 5966660.87 N 381573.26 E 2.592 11270.03 15485.81 90.060 152.390 7069.01 7120.91 7538.498 10012.17 E 5966575.24 N 381616.04 E 0.542 11365.75 15580.90 89.320 147.290 7069.53 7121.43 7620.67 8 10059.93 E 5966492.24 N 381662.38 E 5.419 11460.75 ~, 15676.46 88.830 146.880 7071.07 7122.97 7700.88 8 10111.85 E 5966411.16 N 381712.92 E 0.669 11555.96 15771.67 89.630 146.190 7072.35 7124.25 7780.308 10164.34 E 5966330.85 N 381764.05 E 1.110 11650.74 15867.15 89.200 148.660 7073.32 7125.22 7860.758 10215.74 E 5966249.54 N 381814.07 E 2.626 11745.92 15961.79 89.570 148.520 7074.34 7126.24 7941.528 10265.06 E 5966167.94 N 381862.00 E 0.418 11840.39 16055.98 89.940 151.050 7074.74 7126.64 8022.90 8 10312.46 E 5966085.75 N 381908.00 E 2.715 11934.51 16153.25 90.370 153.620 7074.48 7126.38 8109.058 10357.62 E 5965998.85 N 381951.68 E 2.679 12031.77 16248.68 91.240 153.210 7073.14 7125.04 8194.388 10400.32 E 5965912.80 N 381992.91 E 1.008 12127.15 16342.23 89.630 153.530 7072.43 7124.33 8278.00 8 10442.25 E 5965828.48 N 382033.41 E 1.755 12220.67 16437.33 89.010 153.430 7073.56 7125.46 8363.08 8 10484.71 E 5965742.68 N 382074.40 E 0.660 12315.72 16534.80 88.640 151.700 7075.56 7127.46 8449.57 8 10529.61 E 5965655.43 N 382117.81 E 1.815 12413.16 16627.18 89.750 151.980 7076.85 7128.75 8531.01 8 10573.20 E 5965573.26 N 382160.01 E 1.239 12505.53 16726.02 88.770 151.170 7078.13 7130.03 8617.928 10620.24 E 5965485.56 N 382205.56 E 1.286 12604.36 16821.46 86.850 147.600 7081.78 7133.68 8699.98 S 10668.80 E 5965402.68 N 382252.70 E 4.245 12699.62 16917.04 85.920 148.340 7087.81 7139.71 8780.85 S 10719.39 E 5965320.96 N 382301.90 E 1.242 12794.78 -----------~-------.-- -----. 9 May, 2003 - 15:02 Page 6 of8 DrillQuest 3.03.02.005 Alaska North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 17012.65 86.670 148.840 7093.98 7145.88 17108.14 96.180 150.810 7091.61 7143.51 17202.98 100.610 151.370 7077.77 7129.67 17241.11 100.800 151.060 7070.69 7122.59 .~ 17320.00 100.800 151.060 7055.90 7107.80 Sperry-Sun Drilling Services Survey Report for Alpine CD~2 . CD2-51 Your Ref: AP/501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 8862.28 S 10769.11 E 5965238.69 N 382350.23 E 0.942 12890.03 8944.70 S 10817.04 E 5965155.46 N 382396.74 E 10.170 12985.32 9026.81 S 10862.39 E 5965072.59 N 382440.68 E 4.707 13079.11 9059.65 S 10880.43 E 5965039.45 N 382458.15 E 0.942 13116.57 9127.46 S 10917.93 E 5964971.00 N 382494.48 E 0.000 13194.06 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 51.90' MSL. Northings and Eastings are relative to 2073' FNL, 1502' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2073' FNL, 1502' FEL and calculated along an Azimuth of 151.900° (True). Magnetic Declination at Surface is 24.661 0(12-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 17320.00ft., The Bottom Hole Displacement is 14230.66ft., in the Direction of 129.896° (True). Comments .-- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 17320.00 7107.80 9127.46 S 10917.93 E Projected Survey 9 May, 2003 - 15:02 --------- Page 70f8 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD~2 ~ CD2-51 Your Ref: AP/501032044100 Job No. AKZZ0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Survey tool program for CD2-51 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) ~, 0.00 349.00 0.00 349.00 348.91 17320.00 348.91 Tolerable Gyro (CD2-51 Gyro) 7107.80 AK-6 BP _IFR-AK (CD2-51) .- '-... ---------.---~-- 9 May, 2003 - 15:02 Page 8 of8 DrillQuest 3.03.02.005 ') , AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) ~ Od-~Y9 12-May-03 Re: Distribution of Survey Data for Well C02-51 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD 17,320.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED MAY 13 2003 Álasi\! O¡'¡ & Gas Cons. CommiS8ion Anchorage CJ- ~ «) \ ~ 'O~ Sperry-Sun Drilling Services /- Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-51 MWD Job No. AKMW0002323383, Surveyed: 1 May, 2003 Survey Report 9 Mays 2003 ~"~ Your Ref: API 501032044100 Surface Coordinates: 5974283.88 N, 371734.28 E (70020' 16.7129" N, 151002'26.7931" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974283.88 N, 128265.72 W (Grid) Surface Coordinates relative to Structure: 158.72 S, 19.51 E (True) Kelly Bushing: 51.90ft above Mean Sea Level Elevation relative to Project V Reference: 51.90ft Elevation relative to Structure: 51.90ft spe..-..-.y-sul'l DRILLING seRVIc:es A Halliburton Company Survey Ref: svy245 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2~51 MWD Your Ref: API 501032044100 Job No. AKMW0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub~Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 349.00 2.950 66.000 297.01 348.91 3.11 N 4.78 E 5974286.91 N 371739.11 E -0.50 MWD Magnetic 465.80 4.560 80.360 413.55 465.45 5.11 N 12.10 E 5974288.79 N 371746.47 E 1.586 1.19 556.58 6.230 92.130 503.93 555.83 5.54 N 20.59 E 5974289.06 N 371754.96 E 2.198 4.81 645.2 4 8.770 100.220 591.83 643.73 4.16 N 32.05 E 5974287.49 N 371766.39 E 3.096 11.43 ,-- 73S.20 10.810 102.530 680.4 7 732.37 1.11 N 47.03 E 5974284.19 N 371781.32 E 2.309 21.17 824.35 13.570 108.810 767.61 819.51 4.08S 65.10 E 5974278.69 N 371799.30 E 3.430 34.26 914.66 18.120 112.790 854.4 7 906.37 12.94 S 88.09 E 5974269.44 N 371822.13 E 5.177 52.90 1009.78 21.700 119.200 943.90 995.80 27.25 S 117.09 E 5974254.63 N 371850.88 E 4.403 79.19 1104.86 26.690 124.730 1030.61 1082.51 48.01 S 150.01 E 5974233.31 N 371883.44 E 5.759 113.00 1200.27 29.280 124.030 1114.86 1166.76 73.28 S 186.96 E 5974207.41 N 371919.96 E 2.736 152.70 1295.29 30.040 123.030 1197.43 1249.33 99.25 S 226.16 E 5974180.78 N 371958.70 E 0.954 194.07 1390.75 32.660 123.940 1278.94 1330.84 126.66 S 267.56 E 5974152.67 N 371999.64 E 2.789 237.75 1486.03 36.660 125.440 1357.30 1409.20 157.52 S 312.09 E 5974121.05 N 372043.63 E 4.292 285.95 1581.40 38.310 126.310 1432.98 1484.88 191.53 S 359.11 E 5974086.23 N 372090.06 E 1.817 338.10 1676.24 40.170 126.620 1506.43 1558.33 227.19 S 407.35 E 5974049.76 N 372137.68 E 1.972 392.28 1771.64 41.410 126.620 1578.65 1630.55 264.36 S 457.37 E 5974011.73 N 372187.06 E 1.300 448.63 1866.91 44.750 124.590 1648.23 1700.13 302.21 S 510.28 E 5973972.99 N 372239.32 E 3.796 506.94 1962.36 51.870 121.930 1711.68 1763.58 341.19 S 569.89 E 5973932.99 N 372298.25 E 7.743 569.40 2057.52 58.080 119.810 1766.27 1818.17 381.11 S 636.76 E 5973891.94 N 372364.43 E 6.775 636.11 2152.74 59.520 120.300 1815.60 1867.50 421.90 S 707.26 E 5973849.94 N 372434.22 E 1.575 705.30 2247.92 60.080 121.650 1863.48 1915.38 464.24 S 777.78 E 5973806.41 N 372504.01 E 1.360 775.86 /.?---. 2342.71 58.280 122.740 1912.04 1963.94 507.60 S 846.67 E 5973761.87 N 372572.14 E 2.140 846.56 2437.97 55.090 124.070 1964.36 2016.26 551.41 S 913.12 E 5973716.94 N 372637.84 E 3.546 916.50 2533.28 54.370 123.570 2019.39 2071.29 594.72 S 977.77 E 5973672.52 N 372701.73 E 0.868 985.16 2628.24 54.440 124.010 2074.67 2126.57 637.66 S 1041.94E 5973628.49 N 372765.16 E 0.384 1053.27 2723.60 53.820 127.41 0 2130.55 2182.45 682.75 S 1104.68 E 5973582.34 N 372827.12 E 2.961 1122.59 2818.86 54.740 122.570 2186.19 2238.09 727.06 S 1168.02 E 5973536.95 N 372889.69 E 4.236 1191.51 2914.10 56.360 122.360 2240.06 2291.96 769.21 S 1234.28 E 5973493.67 N 372955.22 E 1.711 1259.90 3009.60 59.050 122.060 2291.08 2342.98 812.24 S 1302.58 E 5973449.48 N 373022.77 E 2.829 1330.02 3066.83 59.080 123.510 2320.50 2372.40 838.82 S 1343.84 E 5973422.20 N 373063.58 E 2.174 1372.91 3161.83 59.650 122.430 2368.91 2420.81 883.30 S 1412.42 E 5973376.55 N 373131.39 E 1.148 1444.45 3257.80 60.190 124.710 2417.02 2468.92 929.22 S 1481.61 E 5973329.46 N 373199.77 E 2.131 1 517.54 3352.56 59.440 128.490 2464.68 2516.58 978.03 S 1547.35 E 5973279.52 N 373264.68 E 3.538 1591,57 3448.22 60.200 125.600 2512.77 2564.67 1027.83 S 1613.35 E 5973228.60 N 373329.81 E 2.730 1666,59 3543.57 64.470 124.470 2557.03 2608.93 1076.29 S 1682.49 E 5973178.97 N 373398.11 E 4.599 1741.90 ~---------- 9 May, 2003 - 15:02 Page 20f8 DrillQllest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - C02-51 MWD Your Ref: AP/501032044100 Job No. AKMW0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3639.01 63.440 124.390 2598.94 2650.84 1124.77 S 1753.21 E 5973129.29 N 373468.00 E 1.082 1817.97 3734.58 63.420 123.150 2641.69 2693.59 1172.28 S 1824.27 E 5973080.57 N 373538.23 E 1.161 1893.35 3829.34 63.430 128.200 2684.10 2736.00 1221.68 S 1893.08 E 5973029.99 N 373606.19 E 4.766 1969.34 3924.02 61.700 121.170 2727.77 2779.67 1269.49 S 1962.09 E 5972981.01 N 373674.37 E 6.837 204402 ,.-. 4021.28 59.560 121.280 2775.47 2827.37 1313.43 S 2034.57 E 5972935.84 N 373746.08 E 2.202 2116.92 4116.64 59.490 120.170 2823.83 2875.73 1355.42 S 2105.22 E 5972892.65 N 373816.00 E 1.006 2187.23 4212.14 59.390 120.790 2872.39 2924.29 1397.13 S 2176.09 E 5972849.73 N 373886.15 E 0.569 2257.41 4307.75 59.150 120.990 2921.24 2973.14 1439.32 S 2246.61 E 5972806.34 N 373955.94 E 0.309 2327.85 4403.13 59.150 120.040 2970.15 3022.05 1480.90 S 2317.16 E 5972763.56 N 374025.77 E 0.855 2397.75 4498.27 59.360 119.540 3018.79 3070.69 1521.52 S 2388.12 E 5972721.73 N 374096.02 E 0.503 2467.01 4593.77 59.850 119.270 3067.11 3119.01 1561.97 S 2459.88 E 5972680.06 N 374167.08 E 0.568 2536.49 4689.06 60.520 119.100 3114.49 3166.39 1602.28 S 2532.06 E 5972638.52 N 374238.56 E 0.720 2606.05 4784.49 60.500 120.160 3161.47 3213.37 1643.35 S 2604.26 E 5972596.22 N 374310.05 E 0.967 2676.28 4879.88 61.280 118.540 3207.87 3259.77 1684.19 S 2676.91 E 5972554.15 N 374381.99 E 1.694 2746.53 4975.53 62.330 117.900 3253.07 3304.97 1724.05 S 2751.19E 5972513.02 N 374455.57 E 1.246 2816.67 5071.16 62.120 117.660 3297.63 3349.53 1763.49 S 2826.04 E 5972472.31 N 374529.75 E 0.312 2886.72 5166.74 61.970 120.870 3342.44 3394.34 1804.75 S 2899.68 E 5972429.79 N 374602.67 E 2.971 2957.80 5262.38 61.850 122.640 3387.48 3439.38 1849.15 S 2971.42 E 5972384.17 N 374673.64 E 1.637 3030.76 5358.09 61 .840 120.490 3432.65 3484.55 1893.32 S 3043.32 E 5972338.78 N 374744.77 E 1.981 3103.59 5453.74 61.690 124.880 3477.91 3529.81 1938.81 S 3114.22 E 5972292.08 N 374814.88 E 4.046 3177.11 5549.12 61.410 122.470 3523.36 3575.26 1985.31 S 3184.00 E 5972244.40 N 374883.85 E 2.241 3250.99 /-- 5644.49 62.470 122.920 3568.22 3620.12 2030.77 S 3254.82 E 5972197.74 N 374953.89 E 1.187 3324.45 5740.35 63.160 122.590 3612.01 3663.91 2076.90 S 3326.53 E 5972150.38 N 375024.80 E 0.782 3398.93 5835.75 63.710 123.880 3654.68 3706.58 2123.67 S 3397.90 E 5972102.40 N 375095.36 E 1.340 3473.80 5930.56 63.790 124.250 3696.61 3748.51 2171.30 S 3468.34 E 5972053.57 N 375164.97 E 0.360 3548.99 6026.07 64.700 121.410 3738.12 3790.02 2217.92 S 3540.62 E 5972005.72 N 375236.44 E 2.842 3624.16 6120.91 64,000 118.890 3779.18 3831.08 2260.86 S 3614.54 E 5971961.52 N 375309.61 E 2.506 3696.86 6217.45 63.220 120.590 3822.09 3873.99 2303.75 S 3689.62 E 5971917.35 N 375383.96 E 1.772 3770,06 6313.15 62.530 121.500 3865.72 3917.62 2347.68 S 3762.60 E 5971872.19 N 375456.17 E 1.112 3843.18 6407.14 61.910 118.920 3909.54 3961.44 2389.52 S 3834.45 E 5971829.12 N 375527.29 E 2.517 3913.93 6503.53 61.360 122.460 3955.34 4007.24 2432.79 S 3907.37 E 5971784.61 N 375599.47 E 3.281 3986.45 6598.97 60.730 124.370 4001.55 4053.45 2478.78 S 3977.08 E 5971737.44 N 375668.37 E 1.871 4059.84 6694.66 60.420 123.520 4048.56 4100.46 2525.32 S 4046.22 E 5971689.72 N 375736.71 E 0.839 4133.46 6790.21 60.420 122.240 4095.73 4147.63 2570.43 S 4116.00 E 5971643.43 N 375805.71 E 1.165 420f),13 6885,92 60.120 121.730 4143.19 4195.09 2614.45 S 4186.49 E 5971598.20 N 375875.44 E 0.559 4278.1 G 9 May, 2003 - 15:02 Page 3 of 8 DrillQ/lest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD~2 - CD2-51 MWD Your Ref: AP/501032044100 Job No. AKMW0002323383, Surveyed: 1 May, 2003 Nortll Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) n100ft) 6981.49 60.800 123.280 4190.31 4242.21 2659.13 S 4256.61 E 5971552.33 N 375944.78 E 1.580 4350.60 7077.11 61 ,130 123.320 4236.72 4288.62 2705.03 S 4326.48 E 5971505.24 N 376013.86 E 0.347 4424.01 7170.96 60.500 123.110 4282.49 4334.39 2749.91 S 4395.03 E 5971459.19 N 376081.63 E 0.699 4495.89 7267.29 60.570 123.050 4329.87 4381.77 2795.69 S 4465.31 E 5971412.22 N 376151.11 E 0.091 4569.37 7363.67 60.770 123.020 4377.08 4428.98 2841.50 S 4535.75 E 5971365.21 N 376220.76 E 0.209 4642.95 ,,- 7458.59 60.800 122.480 4423.41 4475.31 2886.32 S 4605.43 E 5971319.21 N 376289.66 E 0.498 4715.31 7553.80 60.990 121.970 4469.72 4521.62 2930.67 S 4675.80 E 5971273.65 N 376359.27 E 0.509 4787.58 7649.57 61.430 122.130 4515.85 4567.75 2975.21 S 4746.94 E 5971227.90 N 376429.63 E 0.482 4860.38 7744.65 60.640 121.400 4561.89 4613.79 3019.01 S 4817.66 E 5971182.91 N 376499.60 E 1.068 4932.32 7840.13 60.510 119.220 4608.80 4660.70 3060.98 S 4889.45 E 5971139.72 N 376570.66 E 1.993 5003.16 7935.99 60.450 120.560 4656.04 4707.94 3102.54 S 4961.77 E 5971096.92 N 376642.25 E 1.218 5073.89 8031.78 60.470 120.320 4703.26 4755.16 3144.76 S 5033.62 E 5971053.47 N 376713.37 E 0.219 5144.98 8127.33 60.660 120.750 4750.22 4802.12 3187.04 S 5105.29 E 5971009.98 N 376784.31 E 0.439 5216.03 8223.03 60.580 120.790 4797.17 4849.07 3229.71 S 5176.95 E 5970966.09 N 376855.22 E 0.091 5287.41 8317.95 60.800 120.880 4843.64 4895.54 3272.13 S 5248.02 E 5970922.46 N 376925.56 E 0.246 5358.31 8414.32 60.850 120.360 4890.62 4942.52 3314.99 S 5320.43 E 5970878.37 N 376997.23 E 0.474 5430.22 8507.31 61.010 119.960 4935.80 4987.70 3355.82 S 5390.70 E 5970836.34 N 377066.79 E 0.413 5499.35 8605.14 60.960 119.840 4983.25 5035.15 3398.47 S 5464.86 E 5970792.43 N 377140.21 E 0.119 5571.90 8700.59 60.510 120.690 5029.91 5081.81 3440.43 S 5536.78 E 5970749.24 N 377211.40 E 0.909 5642.79 8798.44 61.510 119.330 5077.34 5129.24 3483.24 S 5610.90 E 5970705.18 N 377284.77 E 1.588 5715.45 8890.50 61.440 119.300 5121.30 5173.20 3522.84 S 5681.42 E 5970664.38 N 377354.61 E 0.081 5783.61 ,/-. 8986.59 61.230 120.300 5167.39 5219.29 3564.74 S 5754.59 E 5970621.23 N 377427.05 E 0.939 5855.03 9081.94 61.210 119.410 5213.30 5265.20 3606.34 S 5827.07 E 5970578.39 N 377498.81 E 0.818 5925.87 9177.30 61 .290 117.750 5259.17 5311.07 3646.33 S 5900.48 E 5970537.15 N 377571.53 E 1.528 5995.72 9272.66 61.770 118.270 5304.63 5356.53 3685.70 S 5974.49 E 5970496.52 N 377644.85 E 0.695 6065.31 9368.12 61.650 119.470 5349.87 5401.77 3726.28 S 6048.10 E 5970454.69 N 377717.75 E 1.114 6135.78 9463.59 61.360 120.040 5395.42 5447.32 3767.92 S 6120.94 E 5970411.81 N 377789.87 E 0.606 6206.82 9559.07 61.300 120.350 5441 .23 5493.13 3810.06 S 6193.35 E 5970368.44 N 377861.55 E 0.292 6278.09 9654.44 61 .580 118.730 5486.82 5538.72 3851.35 S 6266.22 E 5970325.90 N 377933.71 E 1.521 6348.85 9749.98 61.710 119.110 5532.20 5584.10 3892.01 S 6339.81 E 5970283.99 N 378006.59 E 0.376 6419.38 9845.07 61.840 120.170 5577.17 5629.07 3933.45 S 6412.63 E 5970241.32 N 378078.69 E 0.992 6490.23 9940.89 61 .990 120.240 5622.28 5674.18 3975.98 S 6485.69 E 5970197.55 N 378151.01 E 0.169 6562.15 10036.58 62.060 117.930 5667.17 5719.07 4017.05 S 6559.54 E 5970155.21 N 378224.14 E 2.133 6633.17 10132.32 61.580 120.520 5712.39 5764.29 4058.25 S 6633.18 E 5970112.76 N 378297.07 E 2.437 6704.20 10227.86 61 .080 126.240 5758.26 5810.16 4104.33 S 6703.14 E 5970065.49 N 378366.23 E 5.278 6777.80 ------_._~---- ----" - ---------.---- - 9 May. 2003 - 15:02 Page 4 of 8 Dri/lQlJest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-51 MWD Your Ref: API 501032044100 Job No. AKMW0002323383, Surveyed: 1 May, 2003 Nortl1 Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10323.36 60.840 121.050 5804.64 5856.54 4150.57 S 6772.61 E 5970018.07 N 378434.90 E 4.758 6851.31 10419.39 61.350 121.170 5851.05 5902.95 4194.01 S 6844.59 E 5969973.41 N 378506.12 E 0.542 6923.53 10514.79 61.870 120.140 5896.42 5948.32 4236.80 S 6916.78 E 5969929.39 N 378577.58 E 1.095 6995.28 10610.18 62.490 122.190 5940.94 5992.84 4280.46 S 6988.96 E 5969884.50 N 378649.00 E 2.009 7067.79 10705,37 62.060 125.940 5985.23 6037.13 4327.64 S 7058.75 E 5969836.14 N 378717.97 E 3.516 7142.28 ,-. 10801.74 61 .440 118.020 6030.90 6082.80 4372.56 S 7130.67 E 5969789.99 N 378789.11 E 7.267 7215.78 10897.11 60.990 118.620 6076.83 6128.73 4412.21 S 7204.25 E 5969749.08 N 378862.00 E 0.726 7285.42 10990.53 60.870 119.310 6122.22 6174.12 4451.75 S 7275.69 E 5969708.33 N 378932.75 E 0.658 7353.94 11087.62 60.700 122.130 6169.61 6221.51 4495.03 S 7348.52 E 5969663.81 N 379004.84 E 2.541 7426.43 11180.76 60.200 120.790 6215.55 6267.45 4537.32 S 7417.63 E 5969620.34 N 379073.22 E 1.362 7496.29 11278.44 59.860 120.310 6264.35 6316.25 4580.33 S 7490.51 E 5969576.09 N 379145.34 E 0.550 7568.55 11373.90 60.580 121.000 6311.76 6363.66 4622.58 S 7561.78 E 5969532.63 N 379215.88 E 0.981 7639.39 11469.17 60.670 121.750 6358.49 6410.39 4665.80 S 7632.66 E 5969488.20 N 379286.01 E 0.692 7710.90 11564.55 60.880 121.640 6405.06 6456.96 4709.53 S 7703.48 E 5969443.27 N 379356.08 E 0.242 7782.84 11659.43 61.300 121.960 6450.93 6502.83 4753.30 S 7774.07 E 5969398.30 N 379425.91 E 0.532 7854.69 11755.07 61.570 120.640 6496.66 6548.56 4796.94 S 7845.84 E 5969353.44 N 379496.92 E 1.245 7926.99 11850.32 60.700 121.660 6542.64 6594.54 4840.08 S 7917.23 E 5969309.08 N 379567.56 E 1.309 7998.68 11945.40 61.360 121.810 6588.69 6640.59 4883.84 S 7987.98 E 5969264.12 N 379637.55 E 0.708 8070.60 12040,66 62.010 121.230 6633.88 6685.78 4927.68 S 8059.47 E 5969219.06 N 379708.28 E 0.868 8142.94 12135.95 62.680 120.760 6678.11 6730.01 4971.14 S 8131.82E 5969174.37 N 379779.88 E 0.828 8215.36 12231 .19 62.400 121.890 6722.03 6773.93 5015.07 S 8204.01 E 5969129.21 N 379851.30 E 1.093 8288.12 /............ 12326.38 62.130 122.610 6766.33 6818.23 5060.03 S 8275.26 E 5969083.04 N 379921.78 E 0.727 8361.34 12421.47 61.890 126.670 6810.97 6862.87 5107.74 S 8344.33 E 5969034.15 N 379990.02 E 3.778 8435.96 12516.28 62.410 126.390 6855.26 6907.16 5157.64 S 8411.69 E 5968983.11 N 380056.51 E 0.607 8511.70 12611.29 64.870 127.420 6897.44 6949.34 5208.76 S 8479.75 E 5968930.83 N 380123.69 E 2.765 8588.85 12706.69 67.650 132.290 6935.86 6987.76 5264.73 S 8546.73 E 5968873.73 N 380189.71 E 5.506 8669.77 12801.36 69.630 130.870 6970.35 7022.25 5323.23 S 8612.68 E 5968814.10 N 380254.65 E 2.515 8752.44 12896.98 72.250 136.100 7001.59 7053.49 5385.42 S 8678.20 E 5968750.81 N 380319.09 E 5.850 8838.16 12992.03 74.450 138.310 7028.82 7080.72 5452.24 S 8740.05 E 5968682.94 N 380379.79 E 3.212 8926.24 13087.61 76.790 142.070 7052.57 7104.47 5523.35 S 8799.30 E 5968610.82 N 380437.81 E 4.529 9016.87 13190.11 80.700 142.530 7072.57 7124.47 5602.88 S 8860.76 E 5968530.26 N 380497.91 E 3.840 9115.97 13288.30 84.070 146.950 7085.59 7137.49 5682.32 S 8916.91 E 5968449.86 N 380552.69 E 5.629 9212.50 13381.02 89.570 150.750 7090.73 7142.63 5761.51 S 8964.77 E 5968369.87 N 380599.18 E 7.205 9304.90 13479.30 91.170 151.840 7090.09 7141.99 5847.71 S 9011.97 E 5968282.87 N 380644.90 E 1.970 9403.16 13574.73 90.620 157.280 7088.60 7140.50 5933.84 S 9052.94 E 5968196.05 N 380684.39 E 5.729 9498.44 -------~_._- ._~-- --- --._--"- ----._"---- 9 May, 2003 - 15:02 Page 50f8 DrillQuest 3.03.02.005 Sperry-Sun Dril'ing Services Survey Report for Alpine CD~2 . CD2~51 MWD Your Ref: AP/501032044100 Job No. AKMW0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 13668.11 91.050 153.320 7087.24 7139.14 6018.65 S 9091.95 E 5968110.59 N 380721.95 E 4.265 9591.63 13765.70 91 .480 156.4 70 7085.09 7136.99 6106.995 9133.34 E 5968021.55 N 380761.82 E 3.257 9689.05 13861.52 91.730 156.360 7082.40 7134.30 6194.775 9171.66 E 5967933.13 N 380798.64 E 0.285 9784.54 13956.92 90.680 150.900 7080.39 7132.29 6280.195 9214.01 E 5967847.00 N 380839.52 E 5.827 9879.83 14052.36 91.240 152.040 7078.80 7130.70 6364.03 S 9259.59 E 5967762.39 N 380883.65 E 1.331 9975.26 -- 14144.99 90.860 153.130 7077.10 7129.00 6446.24 S 9302.23 E 5967679.46 N 380924.88 E 1.246 10067.86 14243.20 90.310 152.070 7076.09 7127.99 6533.43 5 9347.42 E 5967591.52 N 380968.58 E 1.216 10166.06 14336.13 89.690 151.930 7076.09 7127.99 6615.485 9391.05 E 5967508.73 N 381010.80 E 0.684 10258.99 14432.12 89.940 150.380 7076.40 7128.30 6699.565 9437.36 E 5967423.88 N 381055.66 E 1.636 10354.97 14530.50 89.880 150.980 7076.56 7128.46 6785.33 5 9485.53 E 5967337.29 N 381102.36 E 0.613 10453.32 14625.78 90.370 152.590 7076.35 7128.25 6869.29 5 9530.58 E 5967252.57 N 381145.96 E 1.766 10548.60 14721.40 90.740 152.020 7075.43 7127.33 6953.95 S 9575.01 E 5967167.16 N 381188.94 E 0.711 10644.21 14816.91 90.000 151.730 7074.81 7126.71 7038.18 S 9620.04 E 5967082.18 N 381232.52 E 0.832 10739.72 14909.92 89.510 154.160 7075.21 7127.11 7121.00 S 9662.34 E 5966998.64 N 381273.40 E 2.665 10832.71 15007.69 89.380 156.500 7076.15 7128.05 7209.84 5 9703.14 E 5966909.12 N 381312.68 E 2.397 10930.29 15103.13 89.380 156.420 7077.19 7129.09 7297.33 5 9741.26 E 5966820.99 N 381349.29 E 0.084 11025.42 15198.40 91.240 154.030 7076.67 7128.57 7383.82 5 9781.18 E 5966733.83 N 381387.72 E 3.179 11120.52 15292.05 91.670 155.240 7074.29 7126.19 7468.42 5 9821.28 E 5966648.56 N 381426.37 E 1.371 11214.03 15390.08 89.570 153.350 7073.23 7125.13 7556.73 5 9863.79 E 5966559.53 N 381467.37 E 2.882 11311 .96 15485.81 90.060 151.940 7073.54 7125.44 7641.755 9907.78 E 5966473.77 N 381509.90 E 1.559 11407.68 15580.90 89.320 147.870 7074.06 7125.96 7724.01 S 9955.45 E 5966390.71 N 381556.15 E 4.350 11502.69 .r~ 15676.46 88.830 146.970 7075.60 7127.50 7804.52 S 10006.90 E 5966309.34 N 381606.22 E 1.072 11597.94 15771.67 89.630 146.440 7076.88 7128.78 7884.09 S 10059.16 E 5966228.88 N 381657.11 E 1.008 11692.75 15867.15 89.200 148.920 7077.85 7129.75 7964.775 10110.20E 5966147.34 N 381706.76 E 2.636 11787.96 15961.79 89.570 151.280 7078.87 7130.77 8046.80 S 10157.37 E 5966064.51 N 381752.52 E 2.524 11882.54 16055.98 89.940 152.120 7079.27 7131.17 8129.735 10202.02 E 5965980.83 N 381795.75 E 0.974 11976.73 16153.25 90.370 153.670 7079.01 7130.91 8216.31 S 10246.34 E 5965893.50 N 381838.58 E 1.654 12073.98 16248.68 91.240 153.210 7077.67 7129.57 8301.66 5 10289.01 E 5965807.44 N 381879.78 E 1.031 12169.36 16342.23 89.630 155.230 7076.96 7128.86 8385.89 5 10329.69 E 5965722.52 N 381919.01 E 2.761 12262.83 16437.33 89.010 155.130 7078.09 7129.99 8472.20 5 10369.61 E 5965635.54 N 381957.45 E 0.660 12357.76 16534.80 88.640 153.960 7080.08 7131.98 8560.19 5 10411.49 E 5965546.85 N 381997.82 E 1.259 12455.11 16627.18 89.750 152.830 7081.38 7133.28 8642.78 5 10452.85 E 5965463.57 N 382037.77 E 1.715 12547.44 16726.02 88.770 153.500 7082.66 7134.56 8730.96 S 10497.47 E 5965374.63 N 382080.87 E 1 .201 12646.25 16821.46 86.850 150.340 7086.31 7138.21 8815.10 S 10542.35 E 5965289.75 N 382124.30 E 3.872 12741.60 16917.04 85.920 149.920 7092.33 7144.23 8897.81 5 10589.86 E 5965206.23 N 382170.39 E 1.067 12836.95 ___ ____0__ _____ _ _ ..__ 9 May, 2003 - 15:02 Page 6 of 8 ÐrillQllp..c:;f 3.03.02.005 Alaska North Slope Measured Sub~Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 17012.65 86.670 150.340 7098.51 7150.41 171 08.14 96.180 151.050 7096.14 7148.04 17202.98 100.610 153.050 7082.30 7134.20 17241.11 100.800 152.300 7075.21 7127.11 ,-. 17320.00 100.800 152.300 7060-43 7112.33 Sperry-Sun Drilling Services Survey Report for Alpine CO~2 - C02-51 MWO Your Ref: API 501032044100 Job No. AKMW0002323383, Surveyed: 1 May, 2003 North Slope, Alaska Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 8980.55 S 10637.37 E 5965122.69 N 382216.48 E 0.899 12932.31 9063.69 S 10684.04 E 5965038.76 N 382261.73 E 9.987 13027.64 9146.55 S 10728.02 E 5964955.17 N 382304.27 E 5.116 13121.44 9179.83 S 10745.21 E 5964921.59 N 382320.90 E 1.996 13158.90 9248-44 S 10781.24 E 5964852.38 N 382355.74 E 0.000 13236.39 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 51.90' MSL. Northings and Eastings are relative to 2073' FNL, 1502' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2073' FNL, 1502' FEL and calculated along an Azimuth of 151.900° (True). Magnetic Declination at Surface is 24.661°(12-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 17320.00ft., The Bottom Hole Displacement is 14204.53ft., in the Direction of 130.6240 (True). Comments ~, Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ 17320.00 9248.44 S 10781.24 E Projected Survey 7112.33 9 May, 2003 - 15:02 Comment ------ ------ ---- Page 70f8 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for AlpIne CD-2 - CD2~51 MWD Your Ref: API 501032044100 Job No. AKMW0002323383. Surveyed: 1 May. 2003 North Slope, Alaska Alaska North Slope Survey tool program for CD2-51 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) - 0.00 349.00 0.00 349.00 348.91 17320.00 348.91 Tolerable Gyro (C02-51 Gyro) 7112.33 MWO Magnetic (C02-51 MWO) r--. ------------~--------_._-- --- ------------- 9 May, 2003 - 15:02 Page 8 0'8 Dril/Quest 3.03.02.005 Schlumbepgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503~5711 A TTN: Beth RECE'VED JUN 27 2003 Alaska oa &: Gt15 Co05. CofOf1\is8iQn Anchorage Well CD2-51~Cf?)-&LICf. CD2-36ff'¿~ -Of L( Job# Log Description 23350 23352 SCMT SCMT SIGNE~0)~V\ ~ "-o~" ~ Date 05/16/03 05/17/03 DATE: NO. 2887 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine BL Color Prints CD 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561~8317. Thank you. 06/24/03 -- .............--../ ) ') B08-Q)L\9 leJ-crZ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE:MWD Formation Evaluation Logs - CD2-51, May 23, 2003 AK-MW-2323383 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~...~._,.__.::> .. ..,.",'-. "é0\3-LJv'"\ ~ ,. 0 <1~~ ~~-~ ] LDWG formatted Disc with verification listing. API#: 50-103-20441-00. ~~~\~~ ¿ \1.~ ·t r¿,~ \~" 'It ßIIo à ,\c-Se.'\- ~ cJ.-" ~ \}. 0 ~~ '\.l. ~~ ~~FC~E'\¡ED " '" !i;>= JU~. I 0 r) ~'Or',.:r n L '- V0 .' . ,y' i¡ (' ""~"''''r'''' """1"P' ¡fJ'~n ¡:.¡Jð.SKS t,,;¡ l~ \Jti¡~ i.J'...d\:;. l.u. I 1",^,iVH .Anchor~¡e ) ) JOd-~,·L\ '\ MECHANICAL INTEGRITY REPORT' ........ ~IG RELEl-..S:':: OPER & FIELD é.:.~(,\Cð ?t~\'-\\V'> I ~\~'ioN?: "WELL NUMBER C \)d -$ \ ~?UD DÞ.:E: ::'ole Size TD : . till.. TVD¡ ?BTD: MD TVD Shoe: \ "S:d'i: Þ HD ~O6~ TVD i DV: MD -Tvu Shoe: till TVD¡ :OP: HD :7D Packer\J0\ HI) TVTI¡ Set at \~Cod ~ anå Perfs to :~ ~LL DATA Cas in g : '\ \ \ :"i:1e:r: : to' ~ ~ '-1 b ir: g: 4,\/::> 6C1IANIC;'.L INTEGRITY - P.tŒT /1 "'\ ~ ~iè ~~~, Annulus Press Test: ¡P ; 15 min i 30 min Comments: "..-- tŒCHlÜ';¡ICÞ.~ INTEGRITY - PART /2 ~ s5 b~\~ Cement Volumes:' Þ..mt.. l.iner "-J ~" ; Csg \'\~ <))(; DV ~)~ Cûlt -"01 to cover perf s <! "'"Sa"1n \l ~ ciO ~ ~ \«:> ~<.D.~ s~~ç\.<.\(.t--..\ '+0 tt'~.~ c ({ \tV\(; "-.\-,. \0 -\~~ \()\> ð\--\"'~ ~\ ~\"e- Theoretical Toe ~ \Gao\,",-~~\-r>~.crJ:.~\~\,,-(?-, Cement Bond Log (Yes or No) '<fc~ ; ~n AOGCC File ·'(t~ " r ,,~~~.\ '<-~\~~ ~ð'Ç~~ *'~t0<C CBL :::valuation, ::0rle ,-above perfs -\-D ~ \ d-'ts~u Co ~a~Q..~ç-~~ Q.~~ <è.... r ~~\-..)~~ ~ '" ~~~\ s"-~\.J..)<; ~'l. '-E \ \.~\f'.....-\- \Do,,'Ðt,,~~ '!:'=\ \: ~ tiì" D-~c\.,u..~ \v_ ~ P.,t ~'--"\ \i'-'\. cr C ({ '\J"I\..<l" ~ --\- ~ ')( \ ~\.~, '\ ~ <...'t \f\A.ú\('\ \"""" \ '" +~cfð<LQ þ<t..ç- \ ,,-\-~ ~ Q \. ':> .. . Prociu~tiorl Log: Type Evaluation CONCLUSIONS: ? ar t : 1 : ? a.r:: : 2 : k:S:-- \~ \~t-('çx~.;)~ n .. kZ~SldðO) ~ . ... - - CD2-51 Approval to commence injection ) ) Subject: CD2-51 Approval to commence injection Date: Mon, 19 May 2003 16:11 :37 -0800 From: "Clifford L Crabtree" <C.L.Crabtree@conocophillips.com> To: winton_aubert@admin.state.ak.us, Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Christopher J. Alonzo" <Chris.Alonzo@conocophillips.com> Winton/Tom Attached you will find a tubing detail and bond log for Alpine Injection well 2~51. This Cement Bond Log indicates good to excellent bond across the interval that was possible to log using conventional e-line techniques. Other wellbore details are: API number 50-103-20441 Tubing Tail 12,626' MD (6,892' ss) @ 65 deg Alpine C Sand Top 13,080' MD (7,039' ss) @ 77 deg 7" Casing Shoe 13,246' MD (7,069' ss) Completion MIT Tested to 3500 psi for 30 minutes - OK (5-05-03) The drilling 7" Casing cement job summary was: Held PJSM for cementing 7" casing. Cement 7" casing - pump 5 bbls Arco wash @ 8.3 ppg - Test lines to 3500 psi - Pump 15 bbls Arco wash - Mix & pump 50 bbls Mud Push XL @ 12.5 ppg - 5.25 bbls/min @ 800 psi - drop bottom plug - mix & pump 36 bbls slurry (Class G w/ 0.20% 046, 0.25% 065, 0.40% 0167, 0.020% B155) 36 bbls (173 sks) @ 15.8 ppg - 5 bbls/min @ 850 psi - drop top plug w/20 bbls water f/ Dowell - switch to rig pumps & displace w/484 bbls 9.6 ppg mud @ 6 bbls/min @ 490 psi for 383 bbls - increase rate to 7 bbls/min @ 730 psi for 71 bbls - slowed pumps to 3 bbls/min for last 30 bbls 470 psi to 810 psi - Shut down - didn't bump plug - Bleed off pressure - floats held - CIP @ 0822hrs. - full circulation throughout job. LD cement head & landing jt. We will forward the '1320 map' once it has been drafted. We hereby request approval to begin injection operations following changeover of the annular fluid, which will most likely take several weeks due to the fact that wellhead is currently obstructed by Doyon 19 and will be for the next two wells. We will schedule a state witnessed MIT after the well is stablized on injection. Best Regards Cliff Crabtree Cliff Crabtree ConocoPhillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842; Cell: (907) 240-5357 Email: ccrabtr@ppco.com; Fax:: (907) 265-1515 (See attached file: C02-51 Tbg detail.xls)(See attached file: CD2-51_SCMT_16May03.zip) .....---.--.----- -~.--._-- Name: C02-51 Tbg detail.xls . ~C02-51 Tbg detail.xls Type: EXCEL File (application/msexcel) . Encoding: base64 1 of 2 5/19/2003 4:38 PM ~D2-51 Approval to commence injection 2 of 2 ) ) ""..'~.'",.",. '___... .__ _____"""~""'''''',.,..'M...''''u,,~.''''''''''.''''''''''''......~... '''''''.''''' .. ,.,,,.. 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Z U a 0 (i1 c a 9 :z 0 U U I ~ C\ I:i ë j¡j 15 ~ .AI ~ ... 0 SLIM CEMENT MAPPING TOOL (SCMT-BB) PSP:PRESSURE/TEMPERATURE 16 MAY 2003 8ev.: 2524' FNL Be 79g D2' FEL AT SURFACE K.B. G.L. 51.1;1 t D.F. 15.Qt 8ev.: 0 t MSL OF OF Permanent Datum: Log Measured From: (}illing tv1easured From: :51 .Q t abo"W Perm. Datum Sedion 8 Township 11 N Range HE AP I Serial No. :5D-1 D3-2D441-DO 1 ð-tvtry:.2003 ONE 17320 t Logging Date Rm t-.ÞJlT'ber Depth [)iller SchlulT'berger Depth 8allDm LDg hl2rual Top LDg hl2rual Casing Fluid Twe Salinity Density Fluid Le\el 8 ITICAS INGIT'UBING STRING Bit Size From To CasingITubing Size \.IIèi ght Grade From To Ma)òITIJm Fècorded T elT'perallJres LDgger On BallDm I Time Lnit t-.ÞJlT'ber I LDœtion 12931 t 34t DIES EL I BRINE 8.500 in 11251 t 13256 t 7 DOD in 26 IbnVt L-SO 34t 13246 t 147 degF 1 ð-May:.20D3 212S I PRUDHOE BAY 114:47 Oil Density 'tntiIIer Sali nity Gas GraUty ~ 80 C Bw ~ 119g Bubble Point PreSlSllÆ Bubble Point TeJ11lel"iillLlre Solution Û 0 R Ma)Òrrum De'liation CEMEt-lTING OAT A Primary'Squee2!e Casing String t-b Lead CelTtli!nt T\Çe \.tlulTIi!! Density 'U1.Bœr Loss Pdditiæs Tail CelTIi!!nt T\pe 'vtIlulTIi!! 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J" , ......r...."...,..... ..."', ..., ~ ) ) Conoc~illips . , ·ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 14, 2003 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval - Temporary Shutdown of Drilling Operations CD2-51 Dear Sir or Madam: Phillips Alaska, Inc, hereby applies for Sundry Approval to temporarily shutdown drilling operations on well C02-51 with Doyon rig 19, at Alpine. It is intended to move the rig off CD2-51 in order to drill a Tabasco horizontal well from 2T pad, It is planned to return to CD2-51 and finish drilling the well after drilling the Tabasco well (approximately April 25,2003), Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for securing the well. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120, ~~e~ 'V \../( _. J/Íý!òJ Vern Johnson Drilling Engineer Attachments cc: CD2-51 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Steve Moothart ATO 1530 ATO 868 ATO 848 ATO 844 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation RE~r~~~v'~~)) ._ ltY .. I:~ MAR 1 4 2003 ~()J&=~ e-mail : Tommy_Thompson @ anadarko.com ) ) PSI' .- \5 r~j~ .03.//7 ÎP I' ;1 ì 71 r/ .,1> STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 207~FNL, 1502IFEL,Sec.2,T11N,R4E,UM At top of productive interval 25761 FNL, 23041 FWL, Sec. 7, T11 N, R5E, UM At effective depth At total depth 461' FNL, 9401 FEL, Sec. 18, T11 N, R5E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 3131 2401 3131 2401 measured true vertical Length 801 Casing Conductor Surface Production Size 16" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers & SSSV (type & measured depth) None Operational shutdown _XX Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service _XX (as proposed) (as proposed) feet feet feet feet Cemented Plugs (measured) Junk (measured) Portland Type III 13. Attachments Description summary of proposal _XX 14. Estimated date for commencing operation March 14, 2003 16. If pr~o~~~as verbally approved (j-Y!.-:., , v (~ . . - L s I, '-\ - 0 ') Name of appro~ Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed A ~ J 11 JIJ Chip Alvord ~ ~ ~ Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) RKB 36' I 52.7' AMSL 7. Unit or Property name Other Colville River Unit 8. Well number CD2~51 9. Permit number / approval number 202-249 10. API number 50-103-20441-00 11. Field / Pool Colville River Field/Alpine Oil Pool Measured Depth 114' True vertical Depth 114' HE EI E· MAR 1 4 200'3' N_Cl&Qø_~~) ~ Detailed operations program _ 15. Status of well classification as: Oil Title: Alpine Drilling Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechan;callntegrity~D ~UbSeqUent fonn requ;red 10- ~ Approved by order of the Commission ~~ ~ / Form 10-403 Rev 06/15/88 · BOP sketch Gas Suspended _ Questions? Call Vern Johnson 265-6081 Date 6/1i'{C)j Prepared by Sharon Allsup-Drake I Approval no." ", <-=3ö.~ - ¿) ?J'? 4ð'-\ {\(" dS .a~).<.~) ~,~ ~',\(::.'ss. a~([,~\-\G~~ "-"':>'''\'''C0\~O d~~ Date 6.5//7/0) Commissioner RBDMS 8Ft I (' SUBMIT IN TRIPLICATE , i ) ) ....,1' Temporary Halt to Drilline Operations ProP'ram: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12, 13. 14, Run and cement 9-5/8" casing as per drilling program. Note: displace the top plug with mud. Lay down excess drillpipe. (Plan to keep +/- 2400 ft of 4" drillpipe to use as a circulation string.) Nipple down the riser, Install FMC unihead. Pressure test casing to 2500 psi. (AOGCC requirement). Pick up and Rlli with +/-2400 ft of 4" drillpipe open ended (2000+ ft TVD). Make up the tubing hanger and crossover to the last joint of drillpipe and roughly orient the string so that the hanger matches up with the centering guide in the tubing bowl. Back out and recover landing joint. Install the 2-way check (in the lowermost' Cameron' profile in the wellhead). PIU the landing joint and MID to the tubing hanger. Then internally pressure test the hanger seals to 5000 psi. Pressure test the casing to 2500 psi. Remove the landing joint. Install the wellhead adapter assembly. Pressure test the wellhead adapter assembly to 5000 psi. Remove the 2-way check with the FMC lubricator. ù? Conventionally circulate diesel to freeze protect through the t~. Shut in the well on both the tubing and annulus sides. RIU the FMC lubricator and install the BPV in the lower 'Cameron' profile, Ensure all surface valves are in the closed position. RDMO Doyon 19, Waming: could not send message for past 4 hO''') ) I," - Subject: Warning: could not send message for past 4 hours Date: Fri, 14 Mar 2003 18:51 :20 -0600 From: Mail Delivery Subsystem <MAILER-DAEMON@ppco.com> To: <tom_maunder@admin.state.ak.us> ********************************************** ** THIS IS A WARNING MESSAGE ONLY ** ** YOU DO NOT NEED TO RESEND YOUR MESSAGE ** ********************************************** The original message was received at Fri, 14 Mar 2003 14:14:15 -0600 from ancmaiI1.state.ak.us [146.63.92.75] ----- Transcript of session follows ----- <Vern.Johnson@conocophillips.com>... Deferred Warning: message still undelivered after 4 hours Will keep trying until message is 5 days old Reporting-MTA: dns; mailman1.ppco.com Arrival-Date: Fri, 14 Mar 2003 14:14:15 -0600 Final-Recipient: RFC822; Vern.Johnson@conocophillips.com Action: delayed Status: 4.2.0 Last-Attempt-Date: Fri, 14 Mar 2003 18:51 :20 -0600 Will-Retry-Until: Wed, 19 Mar 2003 14:14:15 -0600 Subject: Re: Temporary halt to drilling operations - Alpine CD2-51 Date: Fri, 14 Mar 2003 11 :09:56 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Vernon T Johnson <Vern.Johnson@conocophillips.com> Thanks Verno What you propose is acceptable. This email is your "verbal" approval to proceed as planned. Please get the 403 to us either today or Monday. Good luck with the move. Hope is it a round trip. Tom Maunder, PE AOGCC Vernon T Johnson wrote: > Tom, > > Yes, a string of 4" drillpipe will be ran in to +/- 2000' TVD, and hung off > on the tubing hanger (complete with a tubing x DP crossover). > > Vern Johnson > 907-265-6081 (w) > 907~265-1515 (fax) > 907-748-3906 (Cell) > Vern.Johnson@conocophillips.com > > > Tom Maunder <tom _ maunder@admin.state.ak.us> > > 03/14/200309:48 AM 1 of 2 3/15/2003 1 :03 PM Warning: could not send message for past 4 hOllrs ) ') > > > > > > > Vern, > Will the circulating string be left in the well?? > Tom > > Vernon T Johnson wrote: > > > Tom, » > > As discussed, it is currently planned to temporarily halt drilling > > operations on C02-51. This is to facilitate moving Doyon rig 19 from > > Alpine to Kuparak. It is planned to drill a Tabasco well from 2T pad > > during the limited ice road season. After drilling the Tabasco well, > Doyon > > 19 will be moved back to Alpine to continue drilling C02-51. » > > The well will be secured after cementing 9-5/8" surface casing and > running > > a circulation string in to displace to diesel freeze protect fluid. » > > A form 10-403 and accompanying program will be sent to the AOGCC today. » > > Vern Johnson > > 907-265-6081 (w) > > 907-265-1515 (fax) > > 907-748-3906 (Cell) > > Vern.Johnson@conocophillips.com > (See attached file: tom_maunder.vcf) To: Vernon T Johnson/PPCO@Phillips cc: Subject: Re: Temporary halt to drilling operations - Alpine C02-51 '" ,.·..·....·....···..."..~·"'\\"'V...M'''....''''..^y..'^:....A'' ^ ,-v,. v w..¡y"w_.IW'W...'....w/,¡".\""''IA#IM''''k;, Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 3/15/2003 1 :03 PM Re: Temporary halt to drilling operations - Alpine 9D2-51 ) Subject: Re: Temporary halt to drilling operations - Alpine CD2-51 Date: Fri, 14 Mar 2003 11 :09:56 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Vernon T Johnson <Vern.Johnson@conocophillips.com> cXJd-d-~; Thanks Verno What you propose is acceptable. This email is your "verbal" approval to proceed as planned. Please get the 403 to us either today or Monday. Good luck with the move. Hope is it a round trip. Tom Maunder, PE AOGCC Vernon T Johnson wrote: > Tom, > > Yes, a string of 4" drillpipe will be ran in to +/- 2000' TVO, and hung off > on the tubing hanger (complete with a tubing x OP crossover). > > Vern Johnson > 907-265-6081 (w) > 907-265-1515 (fax) > 907-748-3906 (Cell) > Vern.Johnson@conocophillips.com > > > > > > > > > > > > Vern, > Will the circulating string be left in the well?? > Tom > > Vernon T Johnson wrote: > > > Tom, » > > As discussed, it is currently planned to temporarily halt drilling > > operations on C02-51. This is to facilitate moving Doyon rig 19 from > > Alpine to Kuparak. It is planned to drill a Tabasco well from 2T pad > > during the limited ice road season. After drilling the Tabasco well, > Doyon > > 19 will be moved back to Alpine to continue drilling C02-51. » > > The well will be secured after cementing 9-5/8" surface casing and > running > > a circulation string in to displace to diesel freeze protect fluid. » > > A form 10-403 and accompanying program will be sent to the AOGCC today. » > > Vern Johnson > > 907-265-6081 (w) Tom Maunder <tom_maunder@admin.state.ak.us> 03/14/2003 09:48 AM To: Vernon T Johnson/PPCO@Phillips cc: Subject: Re: Temporary halt to drilling operations - Alpine C02-51 1 of 2 3/14/2003 11:10 AM ) ~lfŒ\~1L ,~c Œ\ - ® ~-r¡ ® ~~ln1ulb ~J W~ln1@,-'0,tru ) AIfA~HA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 FRANK H. MURKOWSK/, GOVERNOR 333 W. "{TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Unit CD2-51 ConocoPhillips Alaska, Inc, Permit No: 202-249 Surface Location: 2073' FNL, 1502' FEL, Sec, 2, T11N, R4E, UM Bottornhole Location: 461' FNL, 940' FEL, Sec. 18, T11N, R5E, UM Dear Mr, Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued, Operations must be conducted in accordance with AS 31,05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager), Sincerely, ~;r~ Michael L, Bill Commissioner BY ORDER OF THE COMMISSION DATED this/3~day of January, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section 1/J6 A- I /I 0 I " ?, I' ) ,) 1a. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Drill X F¡edrill 1 b Type of Well ,.-/ Exploratory Re-Entry Deepen Service x Development Gas Name of Operator 'Or 1r" OJ l\ ( 5. Datum Elevation (OF or KB) ~hillipi AlaÐtm, lt1c. ~rnrl/;¡;s ttlPl5kA- ~ DF 52' feet Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380075,372097,25559 Location of well at surface 7. Unit or property Name Type of Work Stratigraphic Test Development Oil Single Zone Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool 2. 3. 2073' FNL, 1502' FEL, Sec. 2, T11 N, R4E, UM At target (=7" casing point) Colville River Unit 8. Well num~ CD2~51 9, Approximate s, date 01/20/2003 14. Number of acres in property 11. Type Bond (see 20 MC 25.025) Statewide Number 4. 2576' FNL, 2304 FWL, Sec. 7 T11 N, R5E, UM At total depth 461' FNL, 940' FEL, Sec. 18 T11 N, R5E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-50 Crosses 380075 to Feet 11.4' at 350' MD .¡ 372097 &25559 Unit or property Name #59-52-180 Amount Feet 2560 $200,000 15. Proposed depth)Þ'1D and TVD) 17071' MD 7167' MD feet 17. Anticipated pressure (see 20 MC 25.035(e)(2)) ,/ Kickoff depth 300 feet Maximum hole angle 86.9° Maximum surface 2526 psig At total depth (TVD) 3220 at psig 7115' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 3084' 37' 37' 3121' 2390' 553 Sx Arcticset III L & ",' 230 Sx Class G v' 8.5" 7" 26# L-80 BTC~M 13448' 37' 37' 13485 7142' 211 Sx Class G ..". N/A 4.5" 12.6# L-80 I BT mod 12600 32' 32' 12632 6958' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth RECEIVED DEC Z 0 2002 ~as1ta Oil & Gas Cons. Commission . S Anchorage 0 ·11' Dlverter ketch n Ing program X Seabed report 20 AAC 25.050 requirements X Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~_ ,} rjJ Signed a,~ f\\~..v-r.( Title Drilling Team Leader Commission Use Only , Permit Number I API number I Approval date .\ 1~ 0 tQ... I See cov, er !etter for 2. a <... - Z. 7' 7 50- I ð 3 . ::l. 0 'i' ¿,¡ / fì ! ":') Other requirements Conditions of approval Samples required Yes ~ Mud log re::¡ Hied Yes.~ Hydrogen sulfide measures Yes~' Directional survey required ~ No '-1...' Required working pressure for BOPE ~ 'T¿~t- t?el=-.j....,.¡ ~OOC' t.-t~i' ^-f ILit~l ¿,,,,ú'.cÍ4~. , ,2M 3M 5M 10M 15M L - r. , Other: ft,i·~A~:IS.O:.S (~)Ü-)I ~t"~vteï' V(l;«'~~.t1'\.t:"Lt l,S f,v'C(.,¿Je~, µLr~ C"I.-tt ~r,.(ItI.I"j YiÖ~1.t"<d ,ìe,t l~ AAc. 25. ~ j 1.. (. b)) f ,,-~~e. w'- <lc'f ~\,. . f~I.~A.;\.C rH.el..''- t ì S iA,.'''-.t,,~.d. ~' Approved by ORIGINAL SIGNED BY Commissioner ~~eO~~~~[ssion Date \ 1:2 ~? Form 10-401 Rev. 7-24-89 M L. BiU sub~ 'n'1{¡plicate O~~ "..\ ~'\',~ l~~ & ~i " î Ii /i }_ 6- t~r Date I Z / Ie¡ / Q L... ) ) CD2-51 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,12-1/411 Hole /9-5/8" Casina Interval Event Risk Level //~-ì Mitigation Strategy Conductor Broach Low M9f1'itor ceJrar continuously during interval. Well Collision medium f?!.yro sjpgle shots, traveling cylinder diagrams Gas Hydrates Low' ~r well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increased mud weight Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole /7" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheoloç¡y, lost circulation material I Reduced trip speeds, mud properties, proper hole . filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps, Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems alarms, standard well control practices, mud scavengers ,6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitiqation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7' shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weiç¡hted sweeps. ~"'/..., Abnormal Reservoir Medium BOPE drills, Keep mud weight abov '9.. pg. / Pressure Check for flow during connections a If needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers O· "..,_.'", . I., " ,.,. ~ ~ . ~...) 1/ .~ ì l ,'\ i~'5 __ ) ) Alpine: CD2-51 1. 2. 3. 4. 5. 6. 7. 8. 9. Procedure Move on Doyon 19. Drill 12- %" hole to the surface casing point as per the directional plan. Run and cement 9-5/8" surface casing. Install and test BOPE to 5000 psi. / Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Pick up and run in hole with 8~1/2" drilling BHA. Drill 8-%" hole to intermediate casing point in the Alpine Sands. 5~~~.D-1)rogram: GR/RES/PWD) Run and cement 7" casing as per program. Top of cement/Jo34JeèÍ MD above Alpine reservoir. Carry ./ out a leak off test down the 9~5/8" x 7" casing annulus to ~ the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. ..~ 10. BOPE test to 5000 psi. /' 11. 12. 16. 17. 18. 19. 20. 21. 22. Run drilling 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. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). Circulate the hole clean and pull out of hole. / Run 4-%, 12.6#, L~80 tubing with DB nipple, gas lift mandrels, and 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 tubing to diesel and install freeze protection in the annulus. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. ,/ Set BPV and secure well. Move rig off. O II"" · ,"', r ~ 1. ", 1 ',I . ., '. ': / II fi i ~,i ¡ J 'i,~1,- ) ) Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25,050~b)~,.-.''¡S- ovided in following attachments. C02-50 will be the closest well to CD2~51. Well separation i 11.2 t at 350 ft MD. Accounting for survey uncertainty, the ellipse to ellipse separation is 5 ft at 350 ft~. Drllllna Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD2-51 will be injected into a permitted annulus on C02 pad or the class 2 disposal well on CD1 pad, The CD2-51 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 ceme~,fill above the top of the Alpine as per regulations. We request that CD2-51 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 near the below the base of the Schrader Bluff Formation (C-40). These 300- 400' 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 TVO) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 - 1081 = 1910 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 850/0 of 850/0 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 5,41 0 psi 4.599 psi 7,240 psi 6,154 psi t" , J f Ii ' V j ~ .~'...,i I j .~ ,'1 ¡,. ) ) C02-51 DRilLING FLUID PROGRAM Density PV YP Funnel Viscosity I nitial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH KCL SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8~" Section - 6 1 18" point - 12 ÿ4," 9.6~ 8.8 - 9.6 ppg 9.0-9.3 ppg 10- " 10-15 20 - 60 15 - 25 25 - 30 100 - 200 4-8 10 - 15 <18 12 - 20 NC - 10 cc /30 min 4 - 12 cc/30 min (drilling) 12 - 14 cc/30 min 8.5- 9.0 9.0 -10.0 9.0- 9.5 60/0 Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing, Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel I polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 60/0 KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo~Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. C - ~' ~ . I . t ~ 6 .~. ~ f. . j I ¡ t¡¡ "', ":r:'I~. ) ) CD2-51 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 : Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (Ibs. / Qal) (psi) (psi) 16 114/114 10.9 52 53 9 5/8 3121 12390 14.5 1081 1566 7" 13485 I 7142 16.0 3231 2519 / NIA 17071 17167 16.0 3243 NIA . NOTE: The Doyon 195000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Iblgal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1081 - (0.1 x 2390') = 842 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1] x 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3231 - (0.1 x 7142') = 2518 psi 3. Drilling below intermediate casing (7') ASP = FPP - (0.1 x D) / = 3243 - (0.1 x 7167') = 2526 psi OR· .~""': ~ '\ & .~ L r. ,;¡' 1 ~, t' . ,'~ ,;. ~ '11 ~1 i 9 ¡.J l-i - ) ) Colville River Field CD2-51 Injection Well Completion Plan - - - 16" Conductor to 114' . 4-1/2" Camco DB Nipple (3.812') at 2000' TVD = 2385' MD 9-5/8" 36 ppf J~55 BTC Surface Casing @ 3121' MD 12390' TVD cemented to surface - - Updated 12/18/02 Packer Fluid mix: ,9.::> PP9 KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Tubing suspended with diesel Cameo KBG-2 GLM (3.909" DRIFT ID) wI dummy Baker 53 Packer WI millout extension at +1- 12560' MD <200' TVD from top of Alpine TOC @ +1-J221,S' MD 16764' TVD (>1034' ME> aþóve top Alpine) \......-" Top Alpine at 13249' MD / 7126' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 13485/7142' TVD @+/- 89.60 Well TD at 170711 MD I 7167' TVD / O ~;¡, ,~ "'<...., ~ ~I~ L ,.,' ~ ",,; ,I ~'~ 1â\;;Îi'~r¿', ) ) " Alpine. CD2-51 Well Cementing Requirements 9 5/8" Surface Casine run to 3121' MD I 2390' TVD Cement from 3121' MD to 2621' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2621' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1561' MD). Lead slurry: System: (2621'-1561') X 0.3132 fe/ft X 1.5 (50% excess) = 498.0 re below permafrost 1561' X 0.3132 re/ft X 4 (300% excess) = 1955.6 re above pemlafrost Total volume = 498.0 + 1955.6 = 2453.6 fe => 553 Sx @ 4.44 felsk ~...---". '''''] 553 x ArcticSet Lite 3 @ 10.7 PPG yielding ~:;t;V""fe/sk, Class G + 30% D053 thixotropic .. ditive, 0.6% D046 antifoamer, 1.5% D079 exte~l.5% SOOI accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant 516' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 re/ft. = 34.7 ft.3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 fe/sk ~x Class ~. ,,""~% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOl accelerat.or@15.8 ~yielding~3Isk 7" Intermediate Casine: run to 13485' MD I 7142' TVD Cement from 13485'MD to +1- 12215' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail slurry: System: Slurry: Syst.em: (13485' - 12485') X 0.1268 ft.3/ft X 1.4 (40% excess) = 225.5 fe annular vol. 80' X 0.2148 re/ft. = 17.2 feshoejoint volume Total volume = 225.5 + 17.2 = 242.7 ft3 => 211 Sx @ 1.15 fe/sk ~... c"/ (~..ßx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and '6:18% D167 fluid loss additive @ 15.8 PPG yielding~I'Sf<.- . 1 By Weight Of mix Water, all other additives are BWOCement C '"'"'. P ",f!'".. .~!'\~ ~ jt~i::¡'~J '1 ~. \.;i J ¡ \~ / '\ i!YIJ C) =0 -......-q !;~) --..,- ~:=:: :?--'-~ tf- Sperry-Sun Drilling Services -' roposal Report 19 December, 2002 Your Ref: Rotary Steerable (Rotary Build & Land w/4° DLS) Surface Coordinates: 5974283.88 N~ 371734.28 E (70020' 16.7129" N~ 208057' 33.2069" E) Grid Coordinate System: NAD27 Alaska State Planes~ Zone 4 Kelly Bushing: 52.00ft above Mean Sea Level '--- '-...-ï .....y-tp:1 ., bFfíL:...LfNG':- ~$ÊJ:tv:ït~es A Haßiburtofl Cotnpany Proposal Ref: pro 100 11 Page 2 of 11 19 December, 2002 - 9:11 DriHQuest 3.03.02.005 rr-- ~... .~- djl 964.31 1037.07 1109.83 1148.35 C-40 1182.59 0.000 0.000 0.000 0.000 0.000 58.000 58.000 58.000 58.000 58.000 2500.00 2600.00 2700.00 2752.94 2800.00 372687.64 E 372759.57 E 372831.51 E 372869.58 E 372903.44 E 5973688.62 N 5973643.70 N 5973598.79 N 5973575.01 N 5973553.87 N 963.40 E 1036.09 E 1108.78 E 1147.26 E 1181.48E 578.87 8 622.558 666.22 8 689.35 8 709,90 8 2060.96 2113.96 2166.95 2195.00 2219.94 2008.96 2061.96 2114.95 2143.00 2167.94 121.000 121.000 121.000 121.000 121.000 (- 818.79 891.55 0.000 0.000 2300.00 58.000 121.000 2400.00 58.000 121.000 372543.77 E 372615.70 E 5973778.45 N 5973733.53 N 818.02 E 890.71 E 491.51 8 535.198 1954.98 2007.97 1902.98 1955.97 r-~-. "'<-, 675.46 746.16 -- 770.28 End Dir, 8tart 8ail @ 58.0° : 2233.3:: MD,1919.65ftTVD 3.000 3.000 3.000 :;.tk0~ 1665.36 40.961 ,.... 1¿\f{tfOO ·_gJ;t~, f4f}9.99 ~!!!:!I;!'l:~~ !~!:~ 2200.00'~i/ 57.000 121.000 1849.74 2233.33 58.000 121.000 1867.65 372402.07 E 372471.97 E 372495.81 E 5973866.92 N 5973823.28 N 5973808.39 N 674.82 E 745.46 E 769.55 E 405.48 8 447.928 462.40 8 1845.11 1901.74 1919.65 401.20 Permafrost 420.89 479.94 542.17 607.40 3.000 3.000 3.000 3.000 3.000 372130.92 E 372150.39 E 372208.77 E 372270.29 E 372334.78 E 5974036.22 N 5974024.07 N 5973987.62 N 5973949.20 N 5973908.93 N 400.82 E 420.49 E 479.49 E 541.66 E 606.83 E 240.84 8 252.66 8 288.108 325.46 8 364.62 8 1551.99 1577.95 1650.47 1719.30 1784.24 121.000 121.000 121.000 121.000 121.00Q 1200.00 1300.00 1400.00 1500.00 1600.00 178.60 219.53 264.36 312.95 365.17 3.000 3.000 3.000 3.000 3.000 27.000 30 .000 33.000 36.000 39.000 371910.85 E 371951.32 E 371995,63 E 372043.67 E 372095.30 E 5974173.63 N 5974148.36 N 5974120.69 N 5974090.70 N 5974058.46 N 178.43 E 219.33 E 264.11 E 312.65 E 364.83 E 35.81 55.83 80.20 108.84 141.67 700.00 800.00 900.00 1000.00 1100.00 3.000 3.000 3.000 3.000 3.000 371769.68 E 371789.48 E 371813.57 E 371841.88 E 371874.34 E 5974261.78 N 5974249.41 N 5974234.37 N 5974216.70 N 5974196.43 N 645.08 742.31 838.18 932.43 1024.81 121.000 121.000 121.000 121.000 121.000 12.000 15.000 18.000 21.000 24.000 -~ 2.25 8.98 20.17 400.00 500.00 600.00 3.000 3.000 3.000 371736.50 E 371743.15 E 371754.22 E 3.000 6.000 9.000 1.358 5.398 12.11 8 399.95 499.63 598.77 34 7 .95 447.63 546.77 121ßOO 121ßOO 121ßOO 8HL (2073' FNL & 1502' FEL, 8EC; T11 N - R4E) Begin Dir @ 3.00/100ft in 12-1/4" He 300.00ft MD, 300.00ft TVD 0,00 0.000 0.000 300.00 0.00 E O.OON 300.00 248.00 0.000 0.00 5974283.88 N 0.00 0.00 E O.OON 0.00 -52.00 0.000 0.000 Global Coordinates Northings Eas.&! (ft) Measured Depth (ft) local Coordinates Northings Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Comment Azlm, Incl. Alaska North Slope North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for Plan: CD2-51 - CD2-51 (wp03) Your Ref: Rotary Steerable (Rotary Build & Land w/4° DLS) Revised: 19 December, 2002 Page 3 of 11 19 December, 2002 - 9:11 DriHQuest 3.03.02.005 ~~ ""- 2744.45 2819.77 2895.08 2970.40 3045.71 ~k~~.-. ::.~~--::~ 4900.00 5000.00 5100.00 5200.00 5300.00 0.000 0.000 0.000 0.000 0.000 374448.26 E 374522.78 E 374597.29 E 374671.80 E 374746,31 E 5972590.10 N 5972543.63 N 5972497.17 N 5972450.70 N 5972404.24 N 120.967 120.967 120.967 120.967 120.967 61.417 61.417 61.417 61.417 61.417 2742.56 E 2817.85 E 2893.15 E 2968.45 E 3043.74 E 1647.11 S 1692.30 S 1737.48 S 1782.66 S 1827.85 S 3264.52 3312.36 3360.21 3408,05 3455.89 3212.52 3260.36 3308.21 3356.05 3403.89 If""'- ~, ~ 2367.88 2443.19 2518.51 2593.82 2669.14 61.417 61.417 61.417 61.417 61.417 4400.00 4500.00 4600.00 4700.00 4800.00 0.000 0.000 0.000 0.000 0.000 374075.70 E 374150.21 E 374224.73 E 374299.24 E 374373.75 E 5972822.42 N 5972775.96 N 5972729.49 N 5972683.03 N 5972636.56 N 3025.31 3073.15 3120.99 3168.83 3216.68 2973.31 3021.15 3068.99 3116.83 3164.68 120.967 120.967 120.967 120.967 120.967 2366,08 E 2441.37 E 2516.67 E 2591.97 E 2667.26 E 1421.20 S 1466.38 S 1511.56 S 1556.75 S 1601.93 S CJ --,' ;..x·, ,?t~L ~ _~_~, !~J r. 3700.00 61.417 120.9~Z,~~"~3o; ~¡:¡I;ji\~i~~' ª:¡r 4300.00'mt~ 61.417~-120.967 2925.46 1991.30 2066.62 2141.93 2217.25 2292.56 0.000 0.000 0.000 0.000 0.000 373703.14 E 373777.65 E 373852.16 E 373926.68 E 374001.19 E 5973054.74 N 5973008.28 N 5972961.81 N 5972915.35 N 5972868.89 N 1989.60 E 2064.89 E 2140.19 E 2215.49 E 2290.78 E 1195.28 S 1240,46 S 1285.65 S 1330.83 S 1376.01 S 2786.09 2833,93 2881.78 2929.62 2977.46 1840.67 1915.99 1965.97 C-20 0.000 0.000 0.000 373554.12 E 373628.63 E 373678.08 E 5973147.67 N 5973101.21 N 5973070.37 N 1839.00 E 1914.30 E 1964.27 E 1104.91 S 1150.09 S 1180.08 S 1765.46 1788.79 End Dir, Start Sail @ 61.417° : 3631.11 ftMD,2657.45ftTVD 3.000 3.000 373479.71 E 373502.78 E 3600.00 60.484 120.976 3631.11 61.417 120.967 5973194.08 N 5973179.68 N 1763.81 E 1787.13 E 1473.63 1546.39 1619.15 1691.91 1704.43 Begin Dir @ 3.00/100ft : 3517.20ft to. 2600.00ft TVD 0.000 0.000 0.000 0.000 0.000 373191.18 E 373263.11 E 373335.04 E 373406.98 E 373419.35 E 58,000 58.000 58.000 58.000 58.000 3200.00 3300.00 3400.00 3500.00 3517.20 5973374.21 N 5973329,30 N 5973284.38 N 5973239.47 N 5973231.74 N 2379.91 2432.90 2485.89 2538.88 2548.00 121.000 121.000 121.000 121.000 121.000 -- 9-5/8" Casing Pt... Drill out 8-1/2" He 3120.92ft MD, 2390.00ftTVD 9 5/8" Casing C-3O 1427.07 0.000 373145.15 E 2346.00 121.000 58.000 3136.01 856.66 S 2398.00 1255.35 1328.11 1400.87 1416.09 58.000 58.000 58.000 58.000 2900.00 3000.00 3100.00 3120.92 753.58 S 797.26 S 840.94 S 850.07 S 2272.93 2325.92 2378.92 2390.00 2220.93 2273.92 2326.92 2338.00 121.000 121.000 121.000 121.000 Measured Depth (ft) Global Coordinates Northings E (ft) Local Coordinates Northings Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Comment Azlm. Incl. Alaska North Slope North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for Plan: CD2~51 ~ CD2~51 {wp03} Your Ref: Rotary Steerable (Rotary Build & Land w14° DLS) Revised: 19 December, 2002 DriHQuest 3.03.02.005 Page 4 of 11 Sperry-Sun Drilling Services Proposal Report for Plan: CD2~51 ~ CD2~51 (wp03) Your Ref: Rotary Steerable (Rotary Build & Land w14° DLS) Revised: 19 December, 2002 North Slope, Alaska Local Coordinates Global Coordinates Northings Eastings Northings Eastjng«*4 \~_ RiU - Section Comment (ft) (ft) (ft) Z-~ ,-'~:=-- .~::-~, "-~~c:::ö_ -';.~;: -:::0':;::,;'''-. ::;~"" ~~, ~";=-:. 1873.03 S 3119.04 E 5972357.77 N ,_ 37~i~ "*1.000 3121.03 1918.21 S 3194.34 E 5972311.31 N -~~74895r~ E 0.000 3196.34 1963,40 S 3269.63 E 59z2vta4 N -'~969.85 E 0.000 3271.66 2008.58 S 3344.93 E 591tH~_N 3"44.36 E 0.000 3346.97 2053.76 S 342io22 ~~1It-l1.9WN 375118.87 E 0.000 3422.29 125.45 N 375193.39 E 0.000 3497.60 -" 972078.98 N 375267.90 E 0.000 3572.92 5972036.05 N 375336.75 E 0.000 3642.51 K-3 Marker 5972032.52 N 375342.41 E 0.000 3648.23 5971986.05 N 375416.92 E 0.000 3723,55 3796.70 E 5971939.59 N 375491.43 E 0.000 3798.86 3872.00 E 5971893.12 N 375565.95 E 0.000 3874.18 3947.30 E 5971846.66 N 375640.46 E 0.000 3949.49 3985.05 E 5971823.36 N 375677 .82 E 0.000 3987.26 K-2 Marker 4022.59 E 5971800.20 N 375714.97 E 0.000 4024.81 2460.41 S 4097.89 E 5971753.73 N 375789.48 E 0.000 4100.12 2505.60 S 4173.18 E 5971707.27 N 375864.00 E 0.000 4175.44 2550.78 S 4248.48 E 5971660.80 N 375938.51 E 0.000 4250.75 2595.96 S 4323.78 E 5971614.34 N 376013.02 E 0.000 4326.07 2641.15 S 4399.07 E 5971567.87 N 376087.53 E 0.000 4401.38 2686.33 S 4474.37 E 5971521 .41 N 376162.04 E 0.000 4476.70 2731.51 S 4549.67 E 5971474.94 N 376236.56 E 0.000 4552.01 2776.70 S 4624.96 E 5971428.48 N 376311.07 E 0.000 4627.33 2821.88 S 4700.26 E 5971382.01 N 376385.58 E 0.000 4702.64 -' 2867.07 S 4775.55 E 5971335.55 N 376460.09 E 0.000 4777.96 2912.25 S 4850.85 E 5971289.08 N 376534.61 E 0.000 4853.27 2957.43 S 4926.15 E 5971242.62 N 376609.12 E 0.000 4928.59 3002.62 S 5001.44 E 5971196.15 N 376683.63 E 0.000 5003.90 3047.80 S 5076.74 E 5971149.69 N 376758.14 E 0.000 5079.22 3092.98 S 5152.03 E 597110322 N 376832.65 E 0.000 5154.53 19 December, 2002 - 9:11 i'~---- fß~ ~- 4604.12 4651.97 4699.81 4747.65 4795.50 ~~.I_- 7700.00 61.417 120.967 4552.12 7800.00 61.417 120.967 4599.97 7900.00 61.417 120.967 4647.81 8000.00 61.417 120.967 4695.65 ( 8100.00 61.417 120.967 4743.50 4364.91 4412.75 4460.60 4508.44 4556.28 .~~k_{i:t~1 \, 6700.00 61.417 120.96Z~_ ·{i1~73. 6800.00 61.417 120,9Ø~f¡f~;" _ ~\21.5 ;;;:;t,:i~~,;~~J ~:~ 7 400.001'%:.' é1.417~'120.967 4408.60 7500.00'£b: 61.417 120.967 4456.44 7600.00 61.417 120.967 4504.28 Alaska North Slope Measl.l'ed Sub-Sea Vertical Depth lnel. Azlm. Depth Depth (ft) (ft) (ft) 5400.00 61.417 120.967 3451.74 3503.74 5500.00 61 .417 120.967 3499.58 3551.58 5600.00 61.417 120.967 3547.42 3599.42 5700.00 61.417 120.967 3595.26 3647.26 5800.00 61 .417 120.967 3643.11 3695.11 5900.00 61 .417 120.967 3690.95 3742.95 6000.00 61.417 120.967 3738.79 3790.79 6092.40 61.417 120.967 3783.00 3835.00 6100.00 61.417 120.967 3786.64 3838.64 6200.00 61.417 120.967 3834.48 3886.48 6300.00 61.417 120.967 6400.00 61.417 120.967 6500.00 61.417 120.967 6550.15 61.417 120.967 6600.00 61.417 120.967 DriHQuest 3.03.02.005 Page 5 of 11 Sperry-Sun Drilling Services Proposal Report for Plan: CD2~51 - C02-51 (wp03) Your Ref: Rotary Steerable (Rotary Build & Land w14° DLS) Revised: 19 December, 2002 North Slope, Alaska ~~ ~~~ Local Coordinates Global Coordinates Northings Eastings Northings Easting~ '~~_ RdR - Section Comment (ft) (ft) (ft) 3138.17 S ~~;:: ~ ~~~~g~~ ~ ~~xr ~OOO 5229.85 3183.35 S 0.000 5305.16 3228.53 S 5377.92 E 5~~QØJ$~3 N '~056.19 E 0.000 5380.48 3273.72 S 5453.22 E n 59Fa17SN 3~.70 E 0.000 5455.79 3318.90 S _d~~'¡1 íf:~~¡'. 377205.22 E 0.000 5531.11 824.43 N 377279.73 E 0.000 5606.42 -" j 70777.97 N 377354.24 E 0.000 5681.74 5970731.51 N 377428.75 E 0.000 5757.05 5970685.04 N 377503.26 E 0.000 5832.37 5970638.58 N 377577.78 E 0.000 5907.68 5980.29 E 5970592.11 N 377652.29 E 0.000 5983.00 6055.59 E 5970545.65 N 377726.80 E 0.000 6058.31 6130.88 E 5970499.18 N 377801.31 E 0.000 6133.63 6206.18 E 5970452.72 N 377875.83 E 0.000 6208.94 6281.48 E 5970406.25 N 377950.34 E 0.000 628426 3815.92 S 6356.77 E 5970359.79 N 378024.85 E 0.000 6359.57 3861.10 S 6432.07 E 5970313.32 N 378099.36 E 0.000 6434.89 3906.28 S 6507.36 E 5970266.86 N 378173.87 E 0.000 6510.20 3951.47 S 6582.66 E 5970220.39 N 378248.39 E 0.000 6585.52 3981.20 S 6632.22 E 5970189.81 N 378297.43 E 0.000 6635,09 Albian-97 3996.65 S 6657.96 E 5970173.93 N 378322.90 E 0.000 6660.83 4041.83 S 6733.25 E 5970127.46 N 378397.41 E 0.000 6736.15 4087.02 S 6808.55 E 5970081.00 N 378471.92 E 0.000 6811.46 4132.20 S 6883.85 E 5970034.53 N 378546.44 E 0.000 6886.78 -' 4177.38 S 6959.14 E 5969988.07 N 378620.95 E 0.000 6962.09 4222.57 S 7034.44 E 5969941.60 N 378695.46 E 0.000 7037.41 4267.75 S 7109.73 E 5969895.14 N 378769.97 E 0.000 7112.72 4312.94 S 7185.03 E 5969848.67 N 378844.48 E 0.000 7188.04 4358.12 S 7260.33 E 5969802.21 N 378919.00 E 0.000 7263.35 4370.30 S 7280.63 E 5969789.68 N 378939.09 E 0.000 7283.66 Albian-96 19 December, 2002 - 9:11 r-- "" ,- 5991.57 6039.41 6087.26 6135.10 6148.00 C) 10600.00 61.417 120.967 10700.00 61.417 120.967 iit.--:::~_~ 10800.00 61.417 120.967 ~~¡ 1 ~ 10900.00 61.417 120.967 ('"~ ) 10926.96 61.417 120.967 5939.57 5987.41 6035.26 6083.10 6096.00 5752.36 5800.20 5848.04 5895.88 5943.73 5269.77 5317.61 5365.45 5413.3 5461-"'"" _ ."£t~_ ~~. 9700.00 61.417 120.967 ~ï~ß508¡ 9800.00 61.417 12Q.~~~¿), ·}~6.83'- 9900.00 61.417 1¿(f~67 '''~n; ŠM4.67 1 0000.00 61.4.t~{fff;!~~}&Ó~h;:if:~ 5652.51 10065.8J&!~.-, 61.#lV f~-f).~i:·'c-- 5684.00 ~;;~gK'i~,. f'\3;"._._~t§i ''¡~; 10100.00 61.417~~:'20.96i 5700.36 10200.00~i;'if,(ß1.4t11 "~~~~20.967 5748.20 10300.00~~~;\ 61.417 ""120.967 5796.04 10400.00 t,;W 61.417 120.967 5843.88 10500.00 61.417 120.967 5891.73 120.967 120.967 120.967 120.967 120.967 9200.00 9300.00 9400.00 9500.00 9600.00 61 .417 61.417 61.417 61.417 61.417 Alaska North Slope Measured Sub-Sea Vertical Depth Incl. Azlm. Depth Depth (ft) (ft) (ft) 8200.00 61.417 120.967 4791.34 4843.34 8300.00 61.417 120.967 4839.18 4891.18 8400.00 61.417 120.967 4887.03 4939.03 8500.00 61.417 120.967 4934.87 4986.87 8600.00 61.417 120.967 4982.71 5034.71 8700.00 61.417 120.967 5030.55 5082.55 8800.00 61.417 120.967 5078.40 5130.40 8900.00 61.417 120.967 5126.24 5178.24 9000.00 61.417 120.967 5174.08 5226.08 9100.00 61.417 120.967 5221.93 5273.93 DriHQuest 3.03.02.005 Page6of11 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-51 - C02-51 (wp03) Your Ref: Rotary Steerable (Rotary Build & Land wI 4° DLS) Revised: 19 December, 2002 North Slope, Alaska Local Coordinates Global Coordinates Northings Eastings Northings EasUng~:;' ~_ R. ~. Section Comment (ft) (ft) (ft) 4403.30 S 7335.62 E 5969755.74N .37~1?" ~OOO 7338.67 4448.49 S 7410.92 E 5969709.28 N~790œro2 E 0.000 7413.98 4493.67 S 7486.21 E 5~~:atN ~]42.53E 0.000 7489.30 4538.85 S 7561.51 E ~,59C1f516'N 3~7.05 E 0.000 7564.61 4584.04 S 76ae~81 E~~~.. 379291.56 E 0.000 7639.93 523.42 N 379366.07 E 0.000 771524 ~ 969476.96 N 379440.58 E 0.000 7790.56 5969430.49 N 379515.09 E 0.000 7865.87 5969384.03 N 379589.61 E 0.000 7941.19 5969337.56 N 379664.12 E 0.000 8016.50 8088.00 E 5969291.46 N 379738.05 E 0.000 8091.23 Top HRZ 8088.58 E 5969291.10 N 379738.63 E 0.000 8091.82 8163.88 E 5969244.63 N 379813.14 E 0.000 8167.13 8239.18 E 5969198.17 N 379887.66 E 0.000 8242.45 8314.47 E 5969151.70 N 379962.17 E 0.000 8317.76 5002.11 S 8333.51 E 5969139.95 N 379981.01 E 0.000 8336.81 Base HRZ 5035.87 S 8389.77 E 5969105.24 N 380036.68 E 0.000 8393.08 5058.78 S 8427.94 E 5969081.68 N 380074.46 E 0.000 8431.26 K-1 5064.56 S 8437.58 E 5969075.73 N 380084.00 E 0.000 8440.91 Begin Dir @ 4.000o/100ft: 12463.5C MD,6883.12ftTVD 5081.44 S 8464.99 E 5969058.39 N 380111.11 E 4.000 8468.70 5102.35 S 8497.17 E 5969036.93 N 380142.93 E 4.000 8502.30 Kuparuk 5131.51 S 8539.22 E 5969007.05 N 380184.48 E 4.000 8547.83 5159.27 S 8576.65 E 5968978.66 N 380221.42 E 4.000 8589.94 LCU --- ~ 5187.03 S 8611 .91 E 5968950.30 N 380256.20 E 4.000 8631.03 5247.72 S 8682.69 E 5968888.41 N 380325.94 E 4.000 8717.90 5313.27 S 8751.23 E 5968821.69 N 380393.34 E 4.000 8808.00 5383.39 S 8817.18 E 5968750.46 N 380458.08 E 4.000 8900.91 5395.52 S 8827.92 E 5968738.15 N 380468.62 E 4.000 8916.67 Miluveach A 5453.06 S 8876.47 E 5968679.78 N 380516.17 E 4.000 8990.30 Alpine D 5457.71 S 8880.23 E 5968675.07 N 380519.86 E 4.000 8996.17 19 December, 2002 - 9:11 r-- -2::...J_,..~ .._:;..!.-.._~ l ___ ~ ..... 7052.92 7079.95 7084.00 7101.00 7102.22 11999.22 61.417 120.967 6609.00 12000.00 61.417 120.967 6609,37 12100.00 61.417 120.967 6657.22 12200.00 61.417 120.967 6705.0~?~. 12300.00 61.417 120.967 ".~¡'{}fPlJ 12325.29 61.417 120.967 '1~1765. 12400.00 61.417 12019Ø7Î~!t;,,~0.7 12450.70 61.417 120:967 "<" ~5.00 12463.50 61.41} .','.t20.9E!7...., 6831.13 :::::::!¡:j~,!::~: :::: 12600.00~:;& 64.874"125.706 6892.80 12651.19 }~t:', 66.208 127.412 6914,00 12700.00 67.498 129.006 6933.19 12800.00 70.187 132.182 6969.29 C,) 12900.00 72.930 135.251 7000.92 ::t::J 13000.00 75.718 138.231 7027.95 =C,., ,. 13016.70 76.187 138.721 7032.00 ("'c", 13093.89 78.369 140.961 7049.00 ~.~... ~'~ 13100.00 78.542 141.137 7050.22 6920.00 6944.80 6966.00 6985.19 7021.29 6900.33 Alaska North Slope Measured Sub~Sea Vertical Depth Incl. Azim. Depth Depth (ft) .......-- (ft) (ft) 11000.00 61.417 120.967 6130.94 6182.94 11100.00 61.417 120.967 6178.79 6230.79 11200.00 61.417 120.967 6226.63 6278.63 11300.00 61.417 120.967 6274.47 6326.4 7 11400.00 61.417 120.967 6322.31 6374.31 11500.00 61.417 120.967 6370.16 6422.16 11600.00 61.417 120.967 6418.00 6470.00 11700.00 61.417 120.967 6465.84 6517.84 11800.00 61.417 120.967 6513.69 6565.69 11900.00 61.417 120.967 6561.53 6613.53 DrillQuest 3,03.02.005 - 7" Casing Pt... Hold 89.60 in 6-1/8" Hole: 13484.80ft MO, 7090.00ft TVC 7" Casing TARGET (Heel): 13484.59ft MD, 7090.00ft TVO (2575' FNL & ~ ""14' FWL, 8EC 7 - T11 N - R4E)___/ Target - C02-51 (Heel), 100.00 Radi Current Target Alpine C Comment North Slope, Alaska Page 7 of 11 19 December, 2002 - 9:11 r-- ..... t-' -~. -, ~, 13484.80 89.601 151.906 7090.00 7142.00 ~~1l8~~90.4O E 5968353.04 N 380724.55 E 0.000 9376.10 4li'1;,'~~~~ 13500.00 89.601 151.906 7090.11 714~1.~':§7¡fg;~8 9097.56E 5968339.51 N 380731.47E 0.000 9391.29 13600.00 89.601 151.906 7090.80 c,,",~¡14~0'~~~~þ~t~877.82 8 9144.65 E 5968250.50 N 380777.05 E 0.000 949129 13700.00 89.601 151.906 7091.5Q-;,o~_-~~~ -~~-f9'5966.038 9191.74E 5968161.50N 380822.63E 0.000 9591.29 13800.00 89.601 151.906 7092;~B-:"~~t-ff. 6054.258 9238.83 E 5968072.49 N 380868.20 E 0.000 9691.29 - . ~.: ~ _. ..~c. C - - - .... ~ - ~- , - ~.' -' ~ . - ~. 6142.468 9285.92 E 5967983.48 N 380913.78 E 0.000 9791.29 6230.68 8 9333.01 E 5967894.47 N 380959.35 E 0.000 9891.28 7146.29 6318.89 8 9380.11 E 5967805.46 N 381004.93 E 0.000 9991.28 7146.99 6407.11 8 9427.20 E 5967716.46 N 381050.50 E 0.000 10091.28 7147.68 6495.328 9474.29 E 5967627.45 N 381096.08 E 0.000 10191.28 7096.38 7148.38 6583.548 9521.38 E 5967538.44 N 381141.65 E 0.000 10291.27 7097.08 7149.08 6671.758 9568.47 E 5967449.43 N 381187.23 E 0.000 10391.27 14600.00i'~l;i; 89.601"151.906 7097.78 7149.78 6759.978 9615.56 E 5967360.43 N 381232.81 E 0.000 1049127 14700.00 ';:!/ 89.601 151.906 7098.47 7150.47 6848.188 9662.65 E 5967271.42 N 381278.38 E 0.000 10591.27 14800.00 89.601 151.906 7099.17 7151.17 6936.40 8 9709.75 E 5967182.41 N 381323.96 E 0.000 10691.26 14900.00 89.601 151.906 7099.87 7151.87 7024.618 9756.84 E 5967093.40 N 381369.53 E 0.000 10791.26 ~ 15000.00 89.601 151.906 7100.56 7152.56 7112.83 8 9803.93 E 5967004.39 N 381415.11 E 0.000 10891.26 00=,-. 15100.00 89.601 151,906 7101.26 7153.26 7201.048 9851.02 E 5966915.39 N 381460.68 E 0.000 10991.26 ..,"': 15200.00 89.601 151.906 7101.96 7153.96 7289.268 9898.11E 5966826.38N 381506.26E 0.00011091.25 ~,~ 15300.00 89.601 151.906 7102.65 7154.65 7377.478 9945.20E 5966737.37N 381551.83E 0.000 11191.25 9093.31 9138.49 9191.87 9291.36 9375.88 Alaska North Slope Measured Sub-Sea Vertical local Coordinates Global Coordinates Depth Inel. Azlm. Depth Depth Northings Eastings Northings Easu- _C (ft) (ft) (ft) (ft) (ft) (ft) 13200.00 81 .394 143.985 7067.64 7119.64 5535.89 8 13245.98 82.713 145.279 7074.00 7126.00 5573.03 8 13300.00 84.267 146,790 7080.12 7132.12 5617.538 13400.00 87.154 149.568 7087.60 7139.60 5702.258 13484.59 89.601 151.906 7090.00 7142.00 5776.00 8 Sperry-Sun Drilling Services Proposal Report for Plan: CD2~51 - CD2~51 (wp03) Your Ref: Rotary Steerable (Rotary Build & Land w/4° DLS) Revised: 19 December, 2002 DriHQuest 3.03.02.005 - TARGET (Toe) Total Depth: 17071.' MD, 7115.00ft TVD (461 , FNL & 94C FEL, SEC 18 - T11N - R4E) 6-1/8" Open Hole Target - C02-51 (Toe), 100.00 Radil Current Target - Comment North Slope. Alaska 12791.21 12891.21 12962.26 12291.22 12391,22 12491.22 12591.22 12691.21 11791.24 11891.23 11991.23 12091.23 12191.23 11291.25 11391.25 11491,24 11591.24 11691.24 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 382281.04 E 382326.62 E 382359.00 E 382053.17 E 382098.74 E 382144.32 E 382189.89 E 382235.47 E 381825.29 E 381870.86 E 381916.44 E 381962.01 E 382007.59 E Page8of11 19 December, 2002 - 9:11 k-~~ Based upon Minimum Curvature type calculations, at a Measured Depth of 17071.05ft., The Bottom Hole Displacement is 14003.99ft., in the Direction of 129.671 ° (True). ~ Magnetic Declination at Surface is 24.758°(03-Dec-02) r--The Dogleg Severity is in Degrees per 100 feet (US). :~ Vertical Section is from 2073' FNL, 1502' FEL and calculated along an Azimuth of 151.910° (True). All data is in F6ét (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52' MSL. Northings and Eastings are relative to 2073' FNL, 1502' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4, 5965313.25 N 5965224.24 N 5965161.00 N 10698.66 E 10745.76 E 10779.21 E 8788.92 S 8877.13 S 8939.81 S 5965758.29 N 5965669.28 N 5965580.27 N 5965491.26 N 5965402.25 N 10463.21 E 10510.30 E 10557.39 E 10604.48 E 10651.57 E 203.32 N 966114.32 N 5966025.31 N 5965936.30 N 5965847.29 N 7465.69 S 7553.90 S 7642.12 S 7730.33 S 7818.55 S Global Coordinates Northings Eas~ (ft) Local Coordinates Northings Eastings (ft) (ft) Sperry-Sun Drilling Services Proposal Report for Plan: C02-51 - CD2-51 (wp03) Your Ref: Rotary Steerable (Rotary Buifd & Land w14° DLS) Revised: 19 December, 2002 O·~Yr¡:-~j 89.601 151.906 7110.32 89.601 151.906 7111.02 89.601 151.906 7111.72 89.601 151.906 7112.4 89.601 151.906 ~1.1~î E:~,:š~t~!~ 1~:! -.-:'.' Sub-Sea Vertical Incl. Azim, Depth Depth (ft) (ft) 89.601 151.906 7103.35 7155,35 89.601 151.906 7104.05 7156.05 89.601 151.906 7104.75 7156.75 89.601 151.906 7105.44 7157.44 89.601 151.906 7106.14 7158.14 89.601 151.906 7106.84 7158.84 89.601 151.906 7107.53 7159.53 89.601 151.906 7108.23 7160.23 89.601 151.906 7108.93 7160.93 89.601 151.906 7109.63 7161.63 16900.00 17000.00 17071.05 16400.00 16500.00 16600.00 16700.00 16800.00 15900.00 16000.00 16100.00 16200.00 16300.00 15400.00 15500.00 15600.00 15700.00 15800.00 Measured Depth (ft) Alaska North Slope DriNQuest 3.03.02.005 Page 9 of 11 Northings Eastings Dip Up-Dip Formation Name (ft) (ft) Angle Dim. 240.84 S 400.82 E 0.000 359.020 Permafrost 689.35 S 1147.26 E 0.000 0.000 C-40 856.66 S 1425.73 E 0.000 0.000 C-30 - ./ 1180.08 S 1964.27 E 0.000 359.020 C-20 2185.88 S 3640.39 E 0.000 359.020 K-3 Marker 2392.71 S 3985.05 E 0.000 359.020 K-2 Marker 3981.20 S 6632.22 E 0.000 359.020 Albian-97 4370.30 S 7280.63 E 0.000 359.020 Albian-96 4854.78 S 8088.00 E 0.000 359.020 Top HRZ 5002.11 S 8333.51 E 0.000 359.020 Base HRZ 4002.00 5684.00 6096.00 6609.00 6765.00 19 December, 2002 ~ 9:11 .,..:- -,-. ~I_ ---'n.~ =;'~;2:.. r--- j ~iit.-:-~_ ~.J -...... 4054.00 5736.00 6148.00 6661 .00 6817.00 ~ 6550.15 '--JJ 10065.81 ~~ -=Z4,.._:;I 10926.96 _........ 11999.22 C': "·'1 12325.29 ~<...Jo-'" Formation Toos _.YWJð'o '~~'!!Ji1~[ni1,~~:, M~~~jt~~!;~'::99'99 2752.94\jy;.~~\ 2195.00"'- 2143.00 3136.01 ,;;,:; 2398.00 2346.00 3866.37 2770.00 2718.00 6092.40 3835.00 3783.00 -- - R4E) 300.00ft MD, 300.00ft TVD .ftMD,1919.65ftTVD " Hole: 3120.92ft MD, 2390.00ft TVD ~~ 17.20ftMD,2600.00ftTvD ", StartB @ 61.417°: 3631.11ftMD,2657.45ftTVD r @ 4.000°/1 OOft : 12463.50ft M D, 6883.12ft TVD (Heel) : 13484.59ft MD, 7090.00ft TVD (2575' FNL & 2304' FWL, SEC 7 - T11 N - R4E) asing Pt... Hold 89.6° in 6-1/8" Hole: 13484.80ft MD, 7090.00ft TVD TARGET (Toe) Total Depth: 17071.05ft MD, 7115.00ft TVD (461 , FNL & 940' FEL, SEC 18 - T11 N - R4E) 1073.78 S 5064.56 S 5776.01 S 5776.19 S 8939.81 S ·f 0.00 E 0.00 E 769.55 E 1414.76 E 1702.82 E 0.00 N 0.00 N 462.39 S 850.07 S 1023.16 S 3631.11 2657.45 12463.50 6883.12 13484.59 7142.00 13484.80 7142.00 17071.05 ___ 7167.00 0.00 300.00 1919.65 2390.00 2600.00 Comment Station Coordinates TVD Northings Eastings (It) (ft) (ft) North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for Plan: CD2~51 - CD2-51 (wp03) Your Ref: Rotary SteerabJe (Rotary Build & Land w14° DLS) Revised: 19 December, 2002 0.00 300.00 2233.33 3120.92 3517.20 Measured Depth (ft) Comments Alaska North Slope Sperry-Sun Drilling Services Proposal Report for Plan: CD2-51 - CD2~51 (wp03) Your Ref: Rotary SteerabJe (Rotary Build & Land wI 4° DLS) Revised: 19 December, 2002 North Slope, Alaska Alaska North Slope Formation Tops (Continued) Measured Vertical Sub~Sea Depth Depth Depth Northings Eastings Dip Up-Dip (ft) (ft) (ft) (ft) (ft) Angle Dim, 12450.70 6877.00 6825.00 5058.78 S 8427.94 E 12543.13 6920.00 6868.00 5102.35 S 8497.17 E 12651 .19 6966.00 6914.00 5159.27 S 8576.65 E 13016.70 7084.00 7032.00 5395.52 S 8827.92 E 13093.89 7101.00 7049.00 5453.06 S 8876. 13245.98 7126.00 7074.00 5573.03 S Alpine C --' From Measured Vertical ,Me ~~t,..~~~!'~'~~E \:: ~ ~s Casing Detail Casina details 2390.00 7142.00 <Run-TO> 9 518" Casing 7" Casing 6-118" Open Hole <:J ::1:] ~.-,. ~" .l1.;_~. J e_ ·:-2,;:: -' ~'!'-"":-'--~ ~... - ,", 'c--. :l~ r-- 19 December, 2002 ~ 9:11 Page 10 of 11 DriHQuest 3.03.02.005 Alaska North Slope Sperry-Sun Drilling Services Proposal Report for Plan: CD2-51 - CD2~51 (wp03) Your Ref: Rotary Steerable (Rotary Build & Land w/4° DLS) Revised: 19 December, 2002 North Slope, Alaska Targets associated with this wellpath Target Name CD2-51 (Ge~Poly) '0 ::t:J ---- ~- ...-"'- F. L~ -- CD2-51 (Toe) ~~~ .......",--,. _ _~".-_;J "'~C~d;t ~~~::;~J &~ 19 December, 2002 ~ 9:11 Targe ates Eastings Target Target (ft) Shape Type 5776.00 S 9090.30 E Polygon Current Target 5968353.23 N 380724.45 E 70019' 19.8475" N 209001' 58.5247" E ~. 7142.00 5767.90 S 7180.43 E 7142.00 8921.73 S 8854.62 E 7142.00 9006.62 S 8686.05 E 7142.00 5868.97 S 7002.13 E el/GlobaI Coordinates #1 7090.00 5968394.00 N 378815.00 E #2 7090.00 5965212.00 N 380435.00 E #3 7090.00 5965130.00 N 380265.00 E #4 7090.00 5968296.00 N 378635.00 E Geographical Coordinates #1 70019' 19.9476" N 209001' 02.7817" E #2 700 18' 48.9098" N 209001' 51.5376" E #3 700 18' 48.0767" N 209001' 46.6166" E #4 700 19' 18.9552" N 209000' 57.5750" E 7142.00 5776.00 S 9090.30 E Circle Current Target Mean Sea Level/Global Coordinates: 7090.00 5968353.23 N 380724.45 E Geographical Coordinates: 70019' 19.8475" N 209001' 58.5247" E Target Radius: 100.00ft / '- 7167.00 8939.81 S 10779.21 E Circle Current Target Mean Sea Level/Global Coordinates: 7115.00 5965161.00 N 382359.00 E Geographical Coordinates: 70018' 48.7071" N 209002' 47.6862" E Target Radius: 100.00ft Page 11 of 11 DriNQuest 3.03.02.005 ConocoPhillips Alaska, Inc. Colville River Unit Alpine (CD2 Pad) CD2-51 {wp03? G '~·II· · .·.onOCur.1I . IPS -tí" _ wi -IV-sun '-C- fit .···i.:'ÎN .."Ä' . ....., ,.,* ~_..,- ,b·",· '. ~"~ ;_,Jfi~ f\ V1);.r_ A HaHUM'ton Company SHL (207::1' FNL c,, 1502' FEL, SEG 2 - T11 N - H4E) / 0-- - - .._- -.- -'- - - - - - - - - - - - - - - - - ~ / Begin Dir @ 3.0"/100ft in 12-1/4" Hole: 300.con MD. 300.00ft NO 1500 - :::J ~ 3000 - N L!) II ca ~ !;. .c ã. ~ 4500 - (ij d :I:'J -.''''' ç-~ooo - ~~,..;¡ *'~"-.;II ~-:~~ .... J~~ r~-- II J:: o c: :;:: 7500 - ¡¡¡ ãi o en DriJlQuest 3.03.02.005 Well: Current Well Properties CD2-51 #' ~(5'r¡J5" I" I I I I I I I I Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 5974283.88 N, 371734.28 E 158.72 S. 19.51 E 70° 20' 16.7129" N, 208c 57' 332069" E 2073' FNL & 1502' FEL, SEC 2 - T11 N - R4E --- RKB Elevation: North Reference : Units: 52.00ft above Mean Sea Level True North Feet (US) End Dir, Start Sail @ 58.0" : 2233,33ft MD, 1919.65ft NO 7" Casing~ ... Drill o~ 8-1/2" Hole: 3120.92ft MO, 2390.00ft NO .p>,ø ./ aegln O'ir @ '3.00/100t ;-351'7.2Òtt,iö. 260o.00ft NO ,$>.' .' , . -, -. ,........., -...... '.~- -" End ~r. Start Sail @ 61.417" : 3631.11ftMO,2657.45ftTVD .;p:"Ø" .,.. ~ ,.. -" '.. ..-,....- '.' ".-.-'-.'.- .- ... ..--:-'~. -.-., .._-~~-~ ---. - 9-518" C$ PI. MD: 3120.9211 TVO: 2390.oon --:. ,-~---_',-c:_-:---. ";:, ~-~-'~-.- "- ~--~'-.---.- - ~ -~-~~~-".- -- _ ____o·~____ __ .4 .~' ¡o,. ..-- ~o~ ~ð ~ - -í$)A- -~"""' ,,~<:) 'V'V~ ?«), <::J~,\4<) '\'V~\~' '!¡.,0· ~\'" ~~ _Ð;. ,,,.... <- -<-0 _,^'. ð,t;..«). 'VG An..':- ~~. \ ...~ ^ eçv',.,,\<) _....' ~. fI<1 b<'c-9:J'(J ~~ Ç(,.0 íó'~V' <J <!<. '\ ~ .........- O§ 'V 11<' <:; '!:;o "" "\ - ø ..I:'\Y"" <:!>'~~<)' ~'?J~v 6" ~y ,,0 'J:J'T , iš<'- ~<::J~ ~"~~ <: òtb~~~' oØ\,"\""o "tb ~.Go.,=>. x-e0 r¿,.,=>\J' -<-èi- ~~ '\ ~o·, 'b0 - .uuu~rof ....,7 .-;'~;'~" . _~~~;~~~~!:"~'v' .....c:c~. ~~~~è ~ ~~.. ~~~;~~~~,~,~~ ~~>, T1~u;~u~: c ~~D~.80ft / TVD: 7142,ooft CD2-51 (Heel} CD2-51 (Toe) 7142.00 TVD. 5776.00 5.9090.30 E 7167,00 TvD, 8939.815,10779.21 E I I I I I 7500 9000 10500 12000 13500 f - o I I 1500 3000 Scale: 1 inch = 1500ft I 4500 I 6000 CJ ~,. =od_J ~:..~ s:;J ~~L'i'\...' :.: ~~~:3 ~-~- ~~~ -->' ~ ~ ¡---II .s:::. (.) £ - '~·II· Conocur.1I . IpS ConocoPhillips Alaska, Inc. Colville River Unit Alpine (CD2 Pad) CD2..51 ·:wp03? ~-I'Y-5UI1 Q.,A~ .6J;ll\Î,Ø~;~JiR-VJJ;!!,. A Halliburton Company o 2000 4000 6000 8000 1??oo 12000 14000 16000 I /' SHL (2073' FN~ & 1502' FEL, SEC 2 - ;11 N - R4E} I I I I I Scale: 1 inch = 2~Oft R=::11~~~Oi'@:=:~~::Z:~~:~-----------------------o N I .~#" - 9-5/8" Casing PI ... Drill out 8-1/2" Hole: 3120.92ft MD, 2390.00f! NO f(~~'-~ I 9-518' eGg Pl ~ ",Q V1>. i ~~:3~~9;grt Begin Dír @ 3.0°/1000 : 3517.200 MD, 26OO.00ft NO Reference is True North I o -2000 - End Dìr, Start Sail @ 61.417~; 3631.11ftMD,2657.45ftNO Well: (/) 0) c :i: t o Z -4000 - Af..oþ ~O V~ð A ~q -6000 - Begin Dir @ 4.000'/1000 : 12463.50ft MD, 6883. 12ft TVD TARGET (Heel) : 134B4.59ft MD, 7090.00ft NO (2575' FNL & 2304' FWL, SEC 7 - T11 N - R4E) 7" Casing PI ... Hold 89.60 in 6-1/8" Hole: 13484.8Oft MD, 7090.00ft TVD -8000 - ¡¡¡ ëã (.) Cfj Scale: 1 inch = 2000ft o I 2000 I 4000 DrillQuest 3.03.02.005 Horizontal Coordinates: Rei. G!ob¡¡ CoorrlinaIes : Rei. S!IucIure : Rei. Geographical CoordinaIes : RKB E1êvæioo : North Refer"""" : Unils : #" CD2-51 (Heel) ., 7142.00 TVD, 5776.00 S, 9090.30 E ~ /....$'oØr- Csg Pl Q- MD: 13484.BOrt TVD: 7142.00ft Current Well Propertìes CD2~1 5974283.88 N, 371734.28 E 158.72 S. 19.51 E 70" 20' 16.7129" N,208° 57332069' E 2073' FNL& 1502' FEl,SEC2 - T11N-R4E 52.0011 above Mean Séa Level True North Feet (LIS) TARGET lToe) Total Depth: 17071.05f1 MO, 7115.00ft ND (461' FNL & 940' FEL, SEC 18 - T11N - R4E) CD2-51 (Toe) 7167.00 TID. 8939.81 S.. 10779.21 E I 6000 I 8000 Eastings I 1 ??oo I 12000 I 14000 I 16000 Reference is True North --~ - ·2000 - -4000 (/) 0) c :i: 1:: o Z - -6000 -..-/' - -8000 8 o C\I II .s:::. .~ iD ãi (.) rJ) ConocoPhillips Alaska, Inc. ÇD2~5c1 (wpº3) MD Inc Azim. SSTVD TVD NIS EIW V X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) 0.00 0.00 0.00 -52.00 0.00 0.00 N 0.00 E 5974283.88 N 371734.28 E 0.00 0.00 SHL (2073' FNL & 1502' FEL 300.00 0.00 0.00 248.00 300.00 0.00 N 0.00 E 5974283.88 N 371734.28 E 0.00 0.00 Begin Dir in 12-1/40 Hole 1665.36 40.96 121.00 1499.99 1551.99 240.84 S 400s82 E 5974036.22 N 372130.93 E 3.00 401 ,20 Permafrost 2233.33 58.00 121.00 1867.65 1919.65 462.40 S 769.56 E 5973808.39 N 372495.81 E 3.00 770.28 End Dir; Start Sail 2752.94 58.00 121 .00 2143.00 2195.00 689.35 S 1147.26 E 5973575.01 N 372869.58 E 0.00 1148.35 C-40 -~ 3120.92 58.00 121,00 2338.00 2390.00 850.07 S 1414.76 E 5973409.73 N 373134.29 E 0.00 1416.09 9-5/8" Csg Pt on Drill out 8-1/2" Hole 3136.01 58.00 121 .00 2346.00 2398.00 856.67 S 1425.73 E 5973402.95 N 373145.15 E 0.00 1427.07 C-30 3517.20 58.00 121.00 2548.00 2600.00 1023.16 S 1702.82 E 5973231.74 N 373419.35 E 0.00 1704.43 Begin Dir @ 3.0o/100ft 3631.11 61.42 120.97 2605.45 2657.45 1073.79 S 1787.13 E 5973179.68 N 373502.79 E 3.00 1788.79 End Dir; Start Sail 3866.37 61 .42 120.97 2718.00 2770.00 1180.08 S 1964.27 E 5973070.37 N 373678.08 E 0.00 1965.97 C-20 6092.40 61 .42 120.97 3783.00 3835.00 2185.88 S 3640.39 E 5972036.05 N 375336.75 E 0.00 3642.51 K-3 Marker 6550.15 61 .42 120.97 4002.00 4054.00 2392.71 S 3985.06 E 5971823.36 N 375677.82 E 0.00 3987.26 K~2 Marker 10065.81 61 .42 120.97 5684.00 5736.00 3981.21 S 6632.22 E 5970189.81 N 378297.43 E 0.00 6635.09 Albian-97 10926.96 61.42 120.97 6096.00 6148.00 4370.30 S 7280.63 E 5969789.68 N 378939.09 E 0.00 7283.66 Albian-96 11999.22 61 .42 120.97 6609.00 6661.00 4854.79 S 8088.00 E 5969291.46 N 379738.05 E 0.00 8091 .23 Top HRZ 12325.29 61 .42 120.97 6765.00 6817.00 5002.11 S 8333.51 E 5969139.95 N 379981 .01 E 0.00 8336.81 Base HRZ 12450.70 61 .42 120.97 6825.00 6877.00 5058.78 S 8427.94 E 5969081.68 N 380074.46 E 0.00 8431.26 K-1 12463.51 61.42 120.97 6831.13 6883.13 5064.56 S 8437.58 E 5969075.73 N 380084.00 E 0.00 8440.91 Begin Dir @ 4.00/100ft 12543.13 63.41 123.77 6868.00 6920.00 5102.35 S 8497.17 E 5969036.93 N 380142.93 E 4.00 8502.30 Kuparuk 12651.19 66.21 127.41 6914.00 6966.00 5159.27 S 8576.65 E 5968978.66 N 380221.42 E 4.00 8589,94 LCU 13016.70 76.19 138.72 7032.00 7084.00 5395.52 S 8827.92 E 5968738.15 N 380468.62 E 4.00 8916.67 Miiuveach A 13093.90 78.37 140.96 7049.00 7101.00 5453.06 S 8876.47 E 5968679.78 N 380516.18 E 4.00 8990.30 Alpine D "'-~'" 13245.98 82.71 145.28 7074.00 7126.00 5573.03 S 8966.43 E 5968558.30 N 380604.07 E 4.00 9138.49 Alpine C 13484.59 89.60 151.91 7090.00 7142.00 5776.00 S 9090.30 E 5968353.23 N 380724.45 E 4.00 9375.88 TARGET (Heel) : 13484.59ft MD ~:19.60 151.91 7090.00 7142.00 5776.19 S 9090.40 E 5968353.04 N 380724.55 E 0.00 9376.10 7" Csg pt an Drill out 6-118" Hole ,,~071.9~_/ 9.60 151.91 7115.00 7167.00 8939.81 S 10779.21 E 5965161.00 N 382359.00 E 0.00 12962.26 TAf3§E,- (foe) T()t?I..Depth [f~ ~O I'...~,. ~~:Z~ ~'~ v,.) gz--...:;<-:-..- - ;ø ~2 J~ L;-:¡.............-~ [3 ~PERRY_SUN RES ) Anticollision Report 'I 'I' ,Cbn~p:ij}y: þhillJpsAlåskrflnc> : .~jeJd( '. ",', CÞlVil/è ~iVér. Unit ' ' ,·'Rer~rence $it,~: " Alpine.¢D,2, " Rde~tJceWen Þran: C02-51,., ' ,1~eter~Qcie .weµpa~~t ' CD2~51' , . , GLOBAl.. SCAN APPLIED: All weJJpaths within 200'+ 100/1000 uf reference Interpolatiun Methud: MD InteryaJ: 50.00 ft Depth Range: 36.10 to. 17071.59 ft Maximum Radius: 1903.55 ft Reference: Error Mudel: Sc.an Methud: Errur Surface: Time: ' ,1Ö:52:0~: ~,~: ' ViI elli pj~':CP2w5'1', true'North 52,' MSL5RO"· , .'. " :þti: '. Or~k~ Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing "l>8t~:' ,'·~2I19/2Qq2...," , , , , O,.ur~t.ate(N:Ð} Rérer~I'te: , Vertical (1'VD) Refereµ,ce~ Suryey Program fur Definitin Weltpath Date: 8/28/2002 Validated: No Planned :From To. Suryey ft ft 36.10 1000.00 1000.00 17071.59 Versiun: 4 Tuulc.od,e To.o.l Name Planned: CD2-51 (wp03) V9 Planned: CD2-51 (wp03) V9 CB-GYRO~SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Ca'5illg Points o:MD ft, , " 3120.92 13484.80 17071.50 rryn, 'ft ' , 2390.00 7142.00 7167.00 J>i~t,J''' ': In 9.625 7.000 6.125 , , > Holé $j~ ' , , <ín,..' 12.250 8.500 6.125 Namø' 95/8" 7" 6-1/8" Open Hole Summary '~~~.~~~~"~~~;.,~~~.~.~,QO'~et '1re~lp~b ,.,~~~~.~~-.'~r..~~~~..~> ' ,Refett>Qce:, Ol,'fs~t ' " , 'p,. '9r~Ç.,.., N(~.('..o MJo~'abJe ,.SJ~~" , ",',,',WeU:, ' " ,. .'..' Wenpath ' 1\1D ',MO,' ',:Distance Area l)(tviatlon', ' Waflijllg /' I, ' . " . , , ,ff' ' ft ft'., 'ft ft: "'0' Alpine CD1 CD1-40 CD1-40 V1 16961.31 14300.00 1523.26 527.70 995.63 Pass: Major Risk Alpine CD2 CD2-26 CD2-26PB1 V2 438.29 450.00 246.23 7.16 239.11 Pass: Major Risk Alpine CD2 CD2-26 CD2-26PB2 V3 475.07 490.10 246.20 7.65 238.65 Pass: Major Risk Alpine CD2 CD2-28 CD2-28 (Rig Surveys) V 346.53 350.00 231.26 6.23 225.03 Pass: Major Risk Alpine CD2 CD2-28 Plan: CD2-28 V9 Plan: 346.53 350.00 230.66 7.19 223.47 Pass: Major Risk Alpine CO2 CD2-29 CD2-29 V6 300.00 300.00 220.81 5.58 215.23 Pass: Major Risk Alpine CD2 CD2-32 CD2-32 PB1 VO 347.10 350.00 190.16 6.01 184.15 Pass: Major Risk Alpine CD2 CD2-32 CD2-32 VO 347.10 350.00 190.16 6.01 184.15 Pass: Major Risk Alpine CO2 CD2-33 C02-33 V2 347.25 350.00 180.08 5.64 174.44 Pass: Major Risk Alpine CO2 CD2-33 CD2-33A V1 347.25 350.00 180.08 5.59 174.49 Pass: Major Risk Alpine CD2 CD2-33 CD2-34B V1 347.25 350.00 180.08 5.64 174.44 Pass: Major Risk Alpine CD2 CD2-34 CD2-34 V3 249.97 250.00 171 .42 5.09 166.33 Pass: Major Risk Alpine CD2 CD2-34 CD2-34PB1 V2 249.97 250.00 171.42 5.09 166.33 Pass: Major Risk Alpine CO2 CD2-35 CD2-35 V1 347.54 350.00 158.97 5.94 153.04 Pass: Major Risk Alpine CD2 CD2-35 CD2-35A VO Plan: CD2-3 347.54 350.00 158.97 5.83 153.15 Pass: Major Risk Alpine CO2 CD2-38 CD2-38 V5 395.95 400.00 129.53 6.67 122.87 Pass: Major Risk Alpine CO2 CD2-39 CD2-39 V1 881.80 900.00 113.43 15.28 98.52 Pass: Major Risk Alpine CO2 CD2-39 CD2-39PB1 VO 881.80 900.00 113.43 15.28 98.52 Pass: Major Risk Alpine CO2 CD2-41 CD2-41 V9 348.46 350.00 98.22 6.21 92.01 Pass: Major Risk Alpine CD2 CD2-42 CD2-42 vo 348.57 350.00 90.00 5.70 84.31 Pass: Major Risk Alpine CD2 CD2-42 CD2-42PB1 VO 348.57 350.00 90.00 5.70 84.31 Pass: Major Risk Alpine CO2 CD2-44 CD2-44 V15 12680.81 14554.50 311.87 352.75 17.65 Pass: Major Risk Alpine CO2 CD2-45 CD2-45 V4 Plan: CD2-45 840.82 850.00 62.21 15.49 47.07 Pass: Major Risk Alpine CD2 CD2-46 CD2-46 V2 349.19 350.00 49.75 5.69 44.07 Pass: Major Risk Alpine CD2 CD2-47 CD2-47V2 398.37 400.00 40.10 6.61 33.52 Pass: Major Risk Alpine CD2 CD2-48 CD2-48 V1 349.53 350.00 30.51 6.43 24.08 Pass: Major Risk Alpine CD2 CD2-49 CD2-49 V1 349.59 350.00 17.75 5.84 11.93 Pass: Major Risk Alpine CD2 CD2-50 CD2-50 V2 349.79 350.00 11.37 6.62 4.76 Pass: Major Risk Alpine CD2 CD2-50 C02-50PB1 V2 349.79 350.00 11.37 6.62 4.76 Pass: Major Risk Alpine CO2 Plan: C02-31 PLAN: CD2-31 (GR Horz) 346.82 350.00 200.26 6.61 193.65 Pass: Major Risk Alpine CO2 Plan: CD2-31 Plan: CD2-31 (ST Core) 346.82 350.00 200.26 6.72 193.54 Pass: Major Risk Alpine CO2 Plan: CD2-31 Plan: CD2-31 PB1 (Core 346.94 350.00 200.67 7.13 193.54 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: C02-ERO 1 VO P 485.20 500.00 197.58 8.19 189.39 Pass: Major Risk Alpine CO2 Plan: CD2-31 Prelim: CD2-ERD 2 VO P 346.71 350.00 200.02 6.60 193.42 Pass: Major Risk Alpine CD2 Plan: CD2-31 Prelim: CD2-ERD 3 VO P 393.19 400.00 200.14 7.18 192.95 Pass: Major Risk Alpine CD2 Plan: C02-31 Prelim: CD2-ERD 4 VO P 299.95 300.00 200.63 6.04 194.59 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: CD2-ERD 5 VO P 439.48 450.00 197.29 7.60 189.70 Pass: Major Risk Alpine CO2 Plan: CD2-31 Prelim: CD2-ERD 6 VO P 346.72 350.00 199.71 6.58 193.14 Pass: Major Risk Alpine CO2 Plan: CD2-31 Prelim: C02-ERD 7 VO P 393.21 400.00 199.75 7.16 192.60 Pass: Major Risk Alpine CO2 Plan: CD2-31 Prelim: C02-ERD 8 VO P 299.95 300.00 200.39 6.12 194.27 Pass: Major Risk Alpine CO2 Plan: C02-37 Plan: CD2-37 V14 Plan: 299.97 300.00 140.26 6.12 134.14 Pass: Major Risk Alpine CO2 Plan: C02-37 Rig: C02-37 VO 347.52 350.00 139.96 6.21 133.78 Pass: Major Risk ORd'~~ ," 7 A , ,.~~ ..~ ~:'~f ~ ~ ti hq .. ~,I fß 1 ~1iI J , "~ ,I ~.~J ~PERRY_SUN RES ") Anticollision Report '1,' " ,'''' '1 ". ',12I1W2Q02, ~~: 'CbJUPanY:' , ,'PhillIpS AI~$~a /n~: ,,·DaN~ 1'~~1e: ' 10,:$2:03 ' 2 .' Fie~d:, ' , 'COiViIe ~ÌVf:ir Unit', " , " , " ' , I 'Reference Sit~: Alpine CD2. ' ço~()rdfu~te(N¡'1) R~reren~~ . W ell: Pt~': CP2-5'(.'1"rueNorth .', Refêt~nce WeD,: Þ/an:, CD¿~5' Verticol {l'VD)Refere'~~e~ 5?~ MSL 52.0 ' ' , ,R,efe.:'enceWe~paQtt ' 'Cb2~S.f ' :Pb~ ,Or~le' , Smnmary '~~~~"L~~';."~I'~,~"L~~~' otrset. '''~elÎpåth' ,~'.,~,:".~",L~..~.~~:"~..."~', ' I :' ". I 'Ofts~t , . "Ct¡'~ctr NQ~Gò MIQ",~le, ' , ,Refer~il(~' I , Site' 'WeD'" ' ,~ellpath, "MD ' " ,'M.O: " Distance ' A,~a Deviation, WW'W~g , fL ' ft 'fl: , ft' 'ft ,', Alpine CO2 Plan: C02-43 C02-43 (GR Core Pilot) 348.60 350,00 80,09 6.70 73.39 Pass: Major Risk Alpine CO2 Plan: C02-43 C02-43 (ST Core) V7 PI 348.68 350.00 80.30 6.69 73.61 Pass: Major Risk Alpine CO2 Plan: C02-43 Plan: C02-43 (GR Horz) 348,68 350.00 80.30 6.69 73.61 Pass: Major Risk Alpine CO2 Plan: C02-43 Plan: C02-43 (ST Horz) 348.60 350.00 80.09 6.70 73.39 Pass: Major Risk Alpine CO2 Plan: CO2-54 C02-54 VO Plan: A15 (p 450.24 450.00 27.10 8.38 18.72 Pass: Major Risk Alpine CO2 Prelim: C02-30 C02-30 VO Plan: C02-30 393.48 400.00 210.44 7.62 202.83 Pass: Major Risk Alpine CO2 Prelim: C02~36 C02-36 VO Plan: C02-36 862.38 900.00 131.11 14.99 117.09 Pass: Major Risk Alpine CO2 Prelim: C02~40 C02-40 VO Plan: C02-40 396.38 400.00 110.69 7.67 103.03 Pass: Major Risk Alpine CO2 Prelim: CO2-52 C02-52 V1 Plan: CO2-52 450.47 450.00 10.50 8.05 2.46 Pass: Major Risk Alpine CO2 Prelim: C02~53 C02-53 VO Plan: CO2-53 400.63 400.00 20.69 7.60 13.09 Pass: Major Risk Alpine CO2 Prelim: C02~55 C02-55 PB1 V1 Plan: CO 401.17 400.00 40.59 7.49 33.10 Pass: Major Risk Alpine CO2 Prelim: C02~55 C02-55 VO Plan: CO2-55 401.17 400,00 40.59 7.60 33.00 Pass: Major Risk Alpine CO2 Prelim: CO2-56 C02-56 V1 Plan: CO2-56 401.63 400.00 50.43 7.65 42.78 Pass: Major Risk Alpine CO2 Prelim: C02~57 C02~57 VO Plan: C02~57 350.98 350.00 60.17 6.98 53.19 Pass: Major Risk Alpine CO2 Prelim: CO2-58 C02~58 PB1 VO Plan: CD 351.15 350.00 70.19 6.87 63.32 Pass: Major Risk Alpine CO2 Prelim: CO2-58 C02-58 VO Plan: CO2-58 351.15 350.00 70.19 6.98 63.21 Pass: Major Risk Alpine Outlands Alpine 1 Alpine 01 B V1 7043.95 4500.00 471.37 178.37 321.36 Pass: Major Risk O R ',' ......,~. "e ,"," 1.,j~i. ., ." 'I J".I . : i,: .,1 ;¡ \Ie ~.i ~ \~:,A N ~I ~ J ..,~ WEU.PATHDHTAII$ em-51 fuyoo19 52' MSL 52.006 0ñgi1 0rigiI Stanilg +N!-S +Fl-W FromTVD QOO OJ)) 0.00 Rig: Ref!;""""" V.Secti>n Angle 129.61> COMPA."'Y DETAII$ ~ AmbInc. Thgi=ilg ~ c.kubOOÐMeIOC-d: MiWunemv-_e .Eiro£ Sy>tem: ISCWSA S.,.., Memcd: Tn" Cyh:Ier North .Eiro£ Smf>ce: EII¡>tCaI + c..¡'g WamÍlg Me<hod: Rub; &sed AI,rTI-COLUSION SETIINGS Interpolation Method:.\ID Interval: SO.OO Depth Range From: 36.10 To: 1707159 Maximnm Range: 1903.55 Reference: Pian: CD2-51 (v.''03 SI:>t NlA lDngiude Ul'Or26.793W L3àu1e 70'2O't6,7t3N WELl. DI3T AILS N>rtb.i>g Eumg m4283.88 371734,18 +Ei·W 44.16 +NI·S ·357.11 <œ II: CO2. ToM 300 500 1000 1500 2000 2500 3500 4500 5500 6500 7500 8500 9500 105(){ li5(){ 135(){ 155(){ 175(){ From Colour o ~~~~_.ç.-~ 300 500 - 1000 - 1500 - 2000 2500 - 3500 4500 - 5500 ~ 6500 - 7500------ 8500 - 9500 ~ 10500 11500 - 13500 - 15500 - Colour To MD -~-=~=-~- 300 500 - 1000 - 1500 - 2000 2500 - 3500 4500 - 5500 .~ 6500 - 7500 -+4 8500 - 9500 -40 - 10500 11500 - 13500 - 15500 - 17500 From o 300 500 1000 1500 2000 2500 3500 4500 5500 6500 7500 8500 9500 10500 11500 13500 15500 -- '-' "90 CD2-51 (wp03) Approved Plan Centre to Centre Separation [20ftJìn] VS [deg] Travelling Cylinder Azimuth (TFO+AZI) 27[ -10 Plan: CD2--54 (CD2-54) -20 -30 -40 -W -30 -10 -0 90 rrb ' Ai3 SECTIo}.$~ET AILS _J~ MD Ine Az TVD +N/-S +FJ-W DLeg TFace VSe.c Target ~-,::- ~~'!'IIt rr~c'1') 36.10 0.00 0.00 36.10 0.00 0.00 0.00 0.00 0.00 ,.:- ~.... .: 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 tc.....''"."it7sL.c: o.:oO--""'"J...... 2233.33 58.00 121.00 1919.65 -462.40 769.55 3.00 121.00 887.53 __ 4 3139.79 58.00 121.00 2400.00 -858.31 1428.47 0.00 0.00 1647.46 . S-:;~ 3539.87 62.00 121.00 2600.00 -1036.73 1725.41 1.00 0.00 1989.92 :--6-'- 3562.60 61.32 120.96 2610.79 -1047.03 1742.56 3.00 -177.31 2009.69 - ?12462.19 61.32 120.96 6881.90 -5064.04 8437.63 0.00 0.00 9727.42 - 13484.83 89.60 151.91 7142.00 -5776.42 9091.08 4.00 51.74 10685.16 CD2-51 (Heel 3) :;-'-'17071.59 89.60 151.91 7167.00 -8940.47 10780.15 0.00 0.00 14005.12 Cm-51 (Toe) Travelling Cylinder Azimuth (1FO+AZI) [deg] vs Centre to Centre Separation [200ftJìn] SURVEYPROORAM Depth Fm Depth To SurveylPlan Tool 36.10 1000.00 Planned: CO2-51 (wp03) V9 CB-GYRO-SS 1000.00 17071.59 Planned: CO2-51 (wp03) V9 MWD+IFR-AK-CAZ~C 23 00 00 ~ >¡" ~ ~~ ¡jo . 00 ConocoPhllllps Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ) ) ConocJPhillips December 19, 2002 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-51 Dear Sir or Madam: v.-a- . <; e,y \t t c...e.. ConocoPhillips Alaska, Inc, hereby applies for a Permit to Drill an onshore BtGehJction well from the}<fpine CD2 drilling pad. The intended spud date for this well is January 20 2002. It is intended that Doyon Rig 19 be used to drill the well. CD2-51 will be drilled to penetrate the Alpine reservoir horizontally. After settm9J" intermediate casing, the horizontal section will be drilled and the well completed as an open hole)nJ~ At the end of the work pro~m, the well will be closed in awaiting completion of well work and facilities ~ that will allow the well to begin production. /" ",,-'I d~t',,"t that it is planned to drill the surface hole without a diverter. There have bee~::Jells drilled on CD1 pad and 2?;Surface holes drilled on CD2 pad with no significant indication of gas or shallo~s hydrates. All of t~ells n C02 have surface casing shoes within a 2000' radius of the planned surface casing shoe of CD2-51, ThejJ1ter-~ediate hole section on CD2~51 is +/~ 10364 ft long. It is planned to drill the section in one run, which t could take more than 8 days. ConocoPhillips is requesting that the weekly BOP test requirement be extended to . (two we~ . This will ensure that the hole section can be drilled and 7" casing ran without having to trip the drilling ~m6ly for the BOP test. It is also requested that the packer placement requirement be relaxed to place the completion pac~ 200ft TVD /' above the Alpine formation. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: -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 pr?~osed ~rilling program, including a request for approval of annular pumping operatiort'ìt£CE\V ED -A dnlllng fluids program summary. K ~Proposed completion diagram. ~Pressure information as required by 20 ACC 25.035 (d)(2). GEC 2.0 2002 ~CD2-51 Cementing Requirements. , -Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). , l&GaSCons.comm\ss\o,n 'Mas\G 0\ AnchOrage Information pertinent to this application that is presently on file at the AOGCC: ~Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). -A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265~6081 or Chip Alvord at 265~6120. £::17_ Vern Johnson Drilling Engineer Attachments IZ/Í'/8L cc: C02-51 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail : ) ) ATO 1530 A TO 868 A TO 848 A TO 844 Anadarko ~ Houston Kuukpik Corporation Tommy_ Thompson@ anadarko.com ~.~ tffifÞ~'þf~.;¿-¡p.~id~>~~'i:~~~--~"t"~~w-crC-~=o- &.. s. t<. ALL.SUP-DRAt<ij PHILliPS,·PETRO.lEUMCOMPANY 71JGSJ. ANCHORAGE'AK99501 ;~G'O··'''~~j¡(i'.~~..=;,:"~:;;~¿,.o1 1014 DATEP~~Z4 2eo~4J311 ~- 5 ii', ~ f ~~ ~~~ ~~ !f.ò ...... CHASE Chase Manhattan Bank USA, NA Valid Up To 5000 Dollars , _ ~ M'-EMO' cP2-,:;! ~'_h"""~'''''M.''''''''_g_ ·~~dt ~ ¿ I I ~~~ ~ -""-~ l1.~3 ¡'~~I,':2_~,?~pOI, 2 'i'~~?,I~ ¡'19...,¡'I,,~.., r- r~'_~~~'''' PA YTOTHE ðr. ·.··.·-Il1rfi.·.',···..··...-e-...··i·.i..~..··.··.I1'C,··.·....······iAi·¡I}Lp.··......···...·. ····....'/dJ.·· .... ... .,...................... L.··..··/ll,. ... '~..... ..............~~... .... . ~rknLLi ]Jf;~!' J~;;ø- 1$(60.00 ~ I , CJ. Secut"t F~ DOLLARS ill ~"'-. .-- RECEIVED DEC 2 Ö 2002 Alaska Oil & Gas Gons. Commission . Anchorage ') ¡ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPAN~Æl;!,' 1_< WELL NAMEC.la. (' J) ?, -51 FIELD & POOL '/ ~ C>/ð~ INIT CLASS /- þC-o'7 "'7 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . , . . . . . , fy : N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . , . . . . . . . . . . . . . Y N 4. Welllocated in a defined pool.. . . . . . , . . , . , . , . . . Y N 5. Well located proper distance from drilling unit boundary. . Y N 6, Well located proper distance from other wells.. . . , . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . , . . . . . . Y N L£?~ /~ ~ / 8. If deviated, is wellbore plat included.. . . . . . , . . . . . . . Y N ,.Ja.s.- ~."..<- 9. Operator only affected party.. . , , , . . . . . . . , . . . . . Y \I , 10. Operator has appropriate bond in force. . . . , , . . . . . . . Y\I 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . Y N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #..LiL!i Y N (Service Well Only) 14, All wells w/in ~ mile area of review identified, , . . . . . . .. ::u N ENGINEERING Q N œN ~ &; Å-IJ '('.e Ó UR<";. l eAi . j~ IÌ,Y.I"~ /'1. ¥-N- All", i.)N * Y N IM~{ \I e"ý ~' v...lc;;t-êd . ~ .~. fl/l ~t- /VI VJ q, ~ , P f j . NM~¡) '25'2(, fJ$l' N ø~ <'·ee M.te.,. be It) w , á)N X ¡V. A I APPR DATE W(¡Â- '(Iolo~ (Service Well Only) GEOLOGY APPR DATE tf¿ /~h~ (Exploratory Only) Rev: 10/15/02 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . , . , 17. CMT vol adequate to circulate on conductor & surf csg. . . , 18. CMT vol adequate to tie-in long string to surf csg. . . , . . . 19. CMT will cover all known productive horizons. . . .. . . . .. . 20. Casing designs adequate for C, T, B & permafrost. . , . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. , . 23. Adequate wellbore separation proposed.. .'., . . .. . . . . 24. If diverter required, does It meet regulations. ., , . . . . , . 25, Drilling fluid program schematic & equip list adequate. . , . . 26, BOPEs, do they meet regulation. . , , , . . , . . . . . , , . 27. BOPEpress rating appropriate; test to $ (? 00 psig. 28', Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. , , . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . , . . . , . . 31, Mechanical condition of wells within AOR ve~ified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. , . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . ~ ., "..., 36. Contact namelphone for weekly progress reports. ..,.., GEOL AREA <67~ PROGRAM: Exp _ Dev _ Redrll _ Re-Enter _ Serv X Well bore seg _ O~CJ;..<"6 ON/OFF SHORE ~ \,'. ./ *"*" ''?9 ' () 'ItI- CL) 1- 7'0 ) -* I~' -oL/~ CO~ ~.!5 ..) GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR SFD_ WGA /' MJW UNIT# ~~ 199-101 G j) /.. t..j..J ((~ \ ') COMMISSIONER: COT DTS 0/ It ~(] ~ MLB '/ /11fÞ/Ø"; ( I Commentsllnstructions: '* Ap r y-o u ed ' ( tt -; ð,- - ~6o') J;c~... CL.bcv!l'- ð111~«.-t- ¡tA. P r.tf. .Ço~, ÇiJRf-vtl.<./ë. 11 ("Z-CtJI'2-ð 0 '-.. ¥~ A-p y)~\Lt cl ~,.. AD C~ ~~9 - î 0 t) &111 (¡9~~, ~+ v--R~úv d t?l(.. ¥)L-* Åp f roVq J C, / A-\) Lit '5 q q ,- "l. ~.~) ~ \ ( , 111 q"'-}q. S~0 ¡"c...e. cJCtSç. G:\geology\perm its\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennilting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, infomlation of this nature is accumulated at the end of the file under APPENDIX, No special effort has been made to chronologically organize this category of infonnation. Sperry-Sun Dri_lg Services LIS Scan Utility ') :2Þ ;t - :LLf q 1\8(b $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 13:50:42 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments.",...,."..... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments"....,..,...... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-51 501032044100 ConocoPhillips Alaska, Inc. Sperry Sun 22-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 K-MW-2323383 M. HANIK G. WHITLOCK MWD RUN 3 K-MW-2323383 M. HANIK D. MICKEY MWD RUN 4 K-MW-2323383 M. HANIK D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 7 IIN 4E 2575 2304 .00 51.90 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 8.500 6.125 CASING SIZE (IN) 9.625 9.625 7.000 DRILLERS DEPTH (FT) 3120.0 3120.0 13246.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). ) ) 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL AND DUAL GAMMA RAY (DGR). 4. MWD RUNS 2 - 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) I UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 4 WAS DIRECTIONAL WITH DGR¡ EWR4¡ AND PWD. 6. MWD IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 9/26/01. ALL MWD LOG HEADER DATA RETAIN ORIGINAL DRILLERS DEPTH REFERENCE. 7. MWD RUNS 1 - 4 REPRESENT WELL CD2-51 WITH API#: 50-029-20441-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17320'MD / 7108'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 3089.0 3089.0 3089.0 3089.0 3089.0 3097.5 3131.5 STOP DEPTH 17262.5 17262.5 17262.5 17262.5 17262.5 17255.5 17319.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO 2 3 4 MERGE TOP 3089.0 11208.5 13199.0 MERGE BASE 11251.0 13256.0 17319.5 $ ') ') ) # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point,............ . Undefined Frame Spacing...............,.... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3089 17319.5 10204.3 28462 3089 17319.5 ROP MWD FT/H 0.39 449.5 121.63 28377 3131.5 17319.5 GR MWD API 28,8 434.25 100.558 28317 3097.5 17255.5 RPX MWD OHMM 0.23 1649.18 7.34034 28348 3089 17262.5 RPS MWD OHMM 0.07 1638.4 7.79444 28348 3089 17262.5 RPM MWD OHMM 0.07 2000 9.70999 28348 3089 17262.5 RPD MWD OHMM 0.04 2000 15.6104 28348 3089 17262.5 FET MWD HOUR 0.19 847.52 3.82594 28348 3089 17262.5 First Reading For Entire File......... .3089 Last Reading For Entire File.......... .17319.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ ') 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 3089.0 3089.0 3089.0 3089.0 3089.0 3097.5 3131.5 STOP DEPTH 11208.0 11208,0 11208.0 11208.0 11208.0 11216.0 11251.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 22-APR-03 Insite 66.37 Memory 11251.0 3090.0 11251.0 59.2 64.0 TOOL NUMBER 126027 145654 8.500 3120.0 LSND 9.70 54.0 8.9 800 6.8 1.980 1.020 2.500 1.950 70.0 141.8 70.0 70.0 Data Specification Block __)e.....o Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3089 11251 7170 16325 3089 11251 ROP MWD020 FT/H 1.38 449.5 142.564 16240 3131.5 11251 GR MWD020 API 28.8 206.56 106.982 16238 3097.5 11216 RPX MWD020 OHMM 0.37 1638.09 5.85925 16239 3089 11208 RPS MWD020 OHMM 0.07 1638.4 5.95533 16239 3089 11208 RPM MWD020 OHMM 0.17 2000 7.27454 16239 3089 11208 RPD MWD020 OHMM 0.04 2000 13.5013 16239 3089 11208 FET MWD020 HOUR 0.19 847.52 5.26411 16239 3089 11208 First Reading For Entire File......... .3089 Last Reading For Entire File.......... .11251 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 3 .5000 FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ ) START DEPTH 11208.5 11208.5 11208.5 11208.5 11208.5 11216.5 11251.5 STOP DEPTH 13208.5 13208.5 13208.5 13208.5 13208.5 13216.5 13256.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB!G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 ) 24-APR-03 Insite 66.37 Memory 13256.0 11254.0 13256.0 59.9 76.8 TOOL NUMBER 126027 145654 8.500 3120.0 LSND 10.00 59.0 8.8 800 4.4 2.800 1.340 3.200 3.400 68.0 149.0 68.0 68.0 Depth . ') ) UnJ. ts . . . . . . . , . . . . . . . .'; . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 0 30 FT/H 4 1 68 4 2 GR MWD 0 30 API 4 1 68 8 3 RPX MWD 0 30 OHMM 4 1 68 12 4 RPS MWD 0 30 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11208.5 13256 12232.3 4096 11208.5 13256 ROP MWD030 FT/H 0.58 413.55 134.801 4010 11251.5 13256 GR MWD030 API 45.26 434.25 148.139 4001 11216.5 13216.5 RPX MWD030 OHMM 1.88 18.63 5.23335 4001 11208.5 13208.5 RPS MWD030 OHMM 2.02 18.65 5.38356 4001 11208.5 13208.5 RPM MWD030 OHMM 2.24 20 5.96877 4001 11208.5 13208.5 RPD MWD030 OHMM 2.31 20.9 6.21605 4001 11208.5 13208.5 FET MWD030 HOUR 0.21 35.79 1.28484 4001 11208.5 13208.5 First Reading For Entire File......... .11208.5 Last Reading For Entire File.......... .13256 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number........., .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX 4 header data for each bit run in separate files. 4 .5000 START DEPTH 13199.0 13200.0 13200.0 13200.0 13200.0 STOP DEPTH 17255.5 17262.5 17262.5 17262.5 17262.5 FET ROP $ 13200.0 13256.5 ) 17262.5 17319.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame spacing.................... .60 .1IN Max frames per record..... . . . . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 01-MAY-03 Insite 66.37 Memory 17320.0 13256.0 17320.0 84.1 100.8 TOOL NUMBER 151107 156401 6.125 13246.0 Flo Pro 8.90 49.0 8.7 17000 10.8 .200 .090 .210 .170 67.0 160.0 67.0 67.0 Name Service Order DEPT Rap MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 RPX MWD040 OHMM ) 1 68 12 4 ) RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13199 17319.5 15259.3 8242 13199 17319.5 ROP MWD040 FT/H 0.39 241.39 73.3001 8127 13256.5 17319.5 GR MWD040 API 29.88 150.61 63.9512 8114 13199 17255,5 RPX MWD040 OHMM 0.23 1649.18 11.3257 8126 13200 17262.5 RPS MWD040 OHMM 0.27 24.58 12.6472 8126 13200 17262.5 RPM MWD040 OHMM 0.07 1861.69 18.7317 8126 13200 17262.5 RPD MWD040 OHMM 0.22 2000 27.3206 8126 13200 17262.5 FET MWD040 HOUR 0.45 80.16 2.35938 8126 13200 17262.5 First Reading For Entire File......... .13199 Last Reading For Entire File.......... .17319.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/06/02 Maximum Physical Record..65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . , , . . . . . . . . . . . . . , . .03/06/02 origin. . . . . . . . . . . . . . . . . . . STS Tape Name......,......,. .UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments....",...",... .STS LIS Writing Library, Scientific Technical Services Reel Trailer Service name... . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments,.............. .,STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File