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Home My WebLink About204-137CAUTION: 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: PWI S-11B (PTD 199053), WAG S-123 (PTD 204137) potential pressure interaction investigation Date:Tuesday, September 30, 2025 11:50:16 AM Attachments:S-11B S-123 TIO and Inj plots 250930.docx S-11B (PTD 1990530) S-123 (PTD 2041370) From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Tuesday, September 30, 2025 11:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: PWI S-11B (PTD 199053), WAG S-123 (PTD 204137) potential pressure interaction investigation Mr. Wallace, On 9/29/25, increasing IA pressure was noted in Not Operable PWI well S-11B (PTD 199053). The IA pressure was bled from 1470 psi to 600 psi in 15 minutes with 5 bbls of fluid returned. Based on the known production casing leak depth in S-11B at 7076' MD (6754’ TVD), offset Kuparuk injection wells in close proximity were reviewed as the potential pressure source. WAG injector S-123 (204137) was identified as the likely source of the resultant pressure increase in the S-11B IA and injection into S-123 was shut-in late on 9/29/25. We are currently monitoring the IA pressure in S-11B to see if there is a corresponding drop in pressure due to ceasing injection into S-123. Please respond with any questions. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. S-11B TIO Plot: S-123 TIO and Inj plot: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-123 PRUDHOE BAY UN AURO S-123 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/06/2023 S-123 50-029-23219-00-00 204-137-0 W SPT 6496 2041370 1624 2121 2122 2122 2121 380 662 660 657 4YRTST P Bob Noble 3/14/2023 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:PRUDHOE BAY UN AURO S-123 Inspection Date: Tubing OA Packer Depth 515 3002 2899 2884IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230315131241 BBL Pumped:3.3 BBL Returned:3 Thursday, April 6, 2023 Page 1 of 1           MEMORANDUM State of Alaska Pretest Initial 15 Min Alaska Oil and Gas Conservation Commission TO: Jim Regg pppp ��G G P.I. Supervisor/ 31 SII / I DATE: Tuesday, March 19, 2019 SUBJECT: Mechanical Integrity Tests 1 BP EXPLORATION (ALASKA) INC. Tabing 5-123 FROM: Guy Cook PRUDHOE BAY UN AURO S -I23 Petroleum Inspector 2041370 Type Test Sre: Inspector 624 Reviewed By: 282 2702 2634 - P.I. Supry -Ji3z— NON -CONFIDENTIAL Comm Well Name PRUDFIOE BAY UN AURO S-123" API Well Number 50-029-23219-00-00 Inspector Name: Guy Cook Insp Num: mitGDC190315154559 Permit Number: 204-137-0 Inspection Date: 3/15/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-123 Type lnj w -!TVD 6496 Tabing 1130 2132 - _'U' - '_1;i PTD 2041370 Type Test SPT ]Test psi 624 IA 282 2702 2634 - 2L•}0 BBL Pumped_ 2 BBL Returned: 2 OA 586 845 836 _ s,z �— Interval 41RTST !PIF P Notes: Well was shut in for it's four year cycle testing ti e. Testing was done with a triplex pump and bleed trailer. All gauges were current on calibration. Tuesday, March 19, 2019 Page 1 of 1 MEMORANDUM TO: Jim Regg p�9,G� P.I. Supervisor ( FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 25, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. S-123 PRUDHOE BAY UN AURO S-123 Ste: Inspector Well Name PRUDHOE BAY UN AURO S-123 API Well Number 50-029-23219-00-00 Inspector Name: Guy Cook Permit Number: 204-137-0 Inspection Date: 3/13/2019 InspNum: mi[GDC190315154559 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-123 Type [nj W •TVD 6496 Tubing 2130 132 2132 2131 - PTD — —2041370 Type Test) spr Test psi 6za IA zaz nox - z634 - z63o BBL Pumped: 2 - 'BBL Returned: 2 OA sa6 aas 836 - 832 Interval Four Year Cycle P/F Pass ..�. Notes: Well was shut in for it's four year cycle testing time. Testing was done with a triplex pump and bleed trailer. All gauges were current on calibration. Thursday, April 25, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,March 05,2015 TO: Jim Regg ., P.I.Supervisor 7��{/ 15 SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC S-123 FROM: John Crisp PRUDHOE BAY UN AURO S-123 Petroleum Inspector Src: Inspector Reviewed B, P.I.Supry Jv:--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-123 API Well Number 50-029-23219-00-00 Inspector Name: John Crisp Permit Number: 204-137-0 Inspection Date: 2/28/2015 Insp Num: mitJCr150303132703 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well, S-123 iType Inj W' TVD 6496 - Tubing 1 1957 , 1956 ' i 1955 ' 1954 - PTD 2041370 Type Tes SPT Test psil 1624 - IA 377 2503 - 2446 - 2434 Interval '4YRTST P/F I P ✓ OA 1 III 336 332 . 324 - Notes: 145 bbls pumped for test SEAMED " rd e;' 'J j Thursday,March 05,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re -- DATE: Thursday, April 28, 2011 gg j� 6 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -123 FROM: Jeff Jones PRUDHOE BAY UN AURO S -123 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv-ZI — NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN AURO S -123 API Well Number: 50- 029 - 23219 -00 -00 Inspector Name: JeffJones Insp Num: mitJJ1 104271 1 5539 Permit Number: 204 -137 -0 Inspection Date: 4/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 s -123 Type Inj. w TVD 6496 IA use — 2020 2000 2000 P.T.D 2 041370 T ypeTest 1._ SPT Test psi 1624 % OA 530 630 1 620 630 _ Interval 4YRTST P/F P / Tubing 2540 2520 2520 2550 Notes: 1BBL methanol pumped. 1 well inspected; no exceptions noted. a E Thursday, April 28, 2011 Page 1 of 1 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, • ~~~~- ~ ;~:~~e~~~~~~.,~ JUL ~ ~, 2009 ~.ra~~~P ~i! F~ ~~: ~~~e~ ~~~rrf;~~~~~°~ ~ n~~~r~ ~y~ ~~ ~.~. ~_ ~ ~ ~ ~ _ `a..3 Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well narne, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, , ~ -> ~ ?_~C~~ . , ~ ~+~~±~~ ~V~ t~ ~ ~'b iY Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-oH Report of Sundry Operations (10-404) S•patl ~~; ~ / owee R/25/2009 Well Name PTD N Initial rop ot cement Vol. of cement um ed Final top of cement Cement rop oif date Corrosion inhibitor Corrosion inhibirod sealant date h bbls it na al S-01B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1947090 025 NA 025 NA 1.7 5/25/2009 S-03 1871900 7325 NA 1325 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-05A 1951890 0 NA 0 NA 0.9 5/26l2009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/2fJ2009 S•OeB 2010520 0 NA 0 NA o.85 5/27I2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31l2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-118 1990530 025 NA 025 NA 1.7 5/27l2009 S-12A 1851930 025 NA 025 NA 7.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 0.25 NA 025 NA 3 6/2f2009 S-17C 2020070 025 NA 025 NA 2.8 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5l25/2009 S-22B Y9~0510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26I2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31I2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/37I2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27l2009 S-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26I2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/37/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 7921360 0.5 NA 0.5 NA 3.4 5/37/2009 5-35 ~ 1921480 0 NA 0 NA .85 in 5/31/2009 S36 1921160 0.75 NA OJS NA 425 5/27/2009 5-37 1920990 725 NA 125 NA 71.9 5/27/2009 5-38 7921270 025 NA 025 NA 10.2 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11,1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA t.7 5l28/2009 S-44 1970070 025 NA 0.25 NA 1.7 5/28/2009 S•t00 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 11.9 5/29/2009 5-702Lt 2031560 125 NA 125 NA 11.1 5/37/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/ZO/2009 S-106 2010120 16.25 NA 16.25 NA 174.3 6/2I2009 S-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-70e 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-709 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-ttt 2050510 2 NA 2 NA 79.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2027430 1.75 NA 1.75 NA 22.1 5/18/2009 5-~74A 2021980 125 NA 125 NA 102 5/30/'2009 S-tt5 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 73.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 75.3 5/29/2009 S-1i8 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 6)2 5/29/2009 5-~27 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-722 2050810 3 NA 3 NA 21.3 5/29/2009 S-t23 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-724 2061360 1.75 NA 7.75 NA 11.9 5/26/2009 5-125 2070830 2.25 NA 2.25 NA 20.4 5/28J2009 5-726 20710970 125 NA 125 NA 15.3 6l1/2009 S•200 1972390 125 NA 125 NA 14.5 5/28/2009 5-207 2001840 0 NA 0 NA 0,85 6/19/2009 S•213A 2042730 2 NA 2 NA 73.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/112009 S-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 0.25 NA 025 NA 1.7 6/1/2009 S-400 2070740 2 NA 2 NA 9.4 5/28/2009 Sd01 2060780 16 NA i6 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 • • • ,- ._~ ~° ,~ ~_~,„. ~-: MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFichelCvrPgs_Inserts~Microfilm_Marker. doc . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Auberl@admin.state.ak.us;Bob_Fleckenslein@admin.state.ak.us;Jim_Regg@admín.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I S pad 05113/07 Jack Winslow John Crisp ~olf'" ~3 7 Packer Depth Pretest Initial 15 Min. 30 Min. We1l1S-123 I Type Inj. 1 W TVD 1 6,496' Tubíng 24001 25001 25001 25001 Interval 1 0 P.T.D.12041370 I Typetest P Test psil 4000 Casíng 8501 40001 40001 40001 p/FI P Notes: AOGCC State witnessed MIT -IA pre-MI swap. OA 01 3801 4001 4001 Weill I Type Inj. I I TVD I Tubíng Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubíng Interval! P.T.D.I I Type test I I Test psil Casíng P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubíng Interval! P.T.D.I I Type test I I Test psi I Casíng P/FI Notes: OA Weill I Type Inj. I TVD I I Tubíng Interval! P.T.D.I I Type test 1 Test psi I Casíng P/FI Notes: I OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W= Water MIT Report Form BFL 9/1105 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Sul1leY A = Temperature Anomaly SU""'Y D = Differential Temperature Test INTERVAL Codes I = Initial Test 4= Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) SG.lttNNED JUN 1 2 2007 MIT PBU 5-123 05-13-07.xIs Â ~ FeI~ DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 ?P(.~ I). I,i '<Óùt API No. 50-029-23219-00-00 Permit to Drill 2041370 MD 7502_. ----_..._--~._----_._-_..--.._---_._--. Well Name/No. PRUDHOE BAY UN AURO S-123 Operator BP EXPLORATION (ALASKA) INC ND Current Status WAGIN .C;;~ ~) ~_.~---~...,,~~..........~._".~~-~._- 6927 Completion Date 1/23/2005 Completion Status WAGIN --"'~-----~-'-~~----~-'-'- ~--- ~--~"- ___________.______..____________..._.__....._.____._.,._.___".__._...____,._______._.~______~__~._____._"..___ _·_____.___M___~_____,._~__~__~________.._~ -,-~---~.---.--_._-----_._-------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~--,--_._~.--------,----~-~,----~- -"-_._--_._-_.~----_.. -_._--,-._._--,------ ------~-~._.._---_._-~----_._-_._-----,._._-----~------_._-",._._--_._~~-.._----_..._---_._------ -,---_.~---_.._~-_.__._-----"._--~-~ DATA INFORMATION Types Electric or Other Logs Run: MWD / GR / RES / DEN / NEU, MWD / GR / PWD, PEX / SHCS, USIT Well Log Information: Log/ Data Digital Type Med/Frmt ~D Asc þ£ I~ Lis i ~ ~. i ~ I ~og I I I I Log I I Log ! ~ C__~___14197~amma Ra~~_____~_~___. Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint Electr Dataset Number Interval . Log Log Run OH/ Scale Media No Start Stop CH Received Comments ------,~ -------------- ...--- . -- ---'1 0 7502 Open 10/5/2004 I I 0 7502 Open 10/5/2004 i 5 Col 7130 7370 Case 2/1112005 USIT/CEMENT i EV ALUA TION/GRlCCL i 2924 7507 Open 8/8/2006 NCNT, CAL 1, RHOB I w/graphics I 2 Slu 2924 7507 Open 8/8/2006 2" Quad Combo NO SS I Log PEX-BHC 20-Dec-2004i 5 Blu 2924 7507 Open 8/8/2006 5" Quad Combo NO SS i Log PEX-BHC 20-Dec-2004! I 2 Blu 2924 7507 Open 8/8/2006 2" Quad Combo MD PEX- I SHC 20-Dec-2004 I 5 Blu 2924 7507 Open 8/8/2006 5" Quad Combo MD PEX- I SHe 20-Dec-2004 I . 25 Blu 110 7502 Open 10/25/2006 MD Composit COR I I Resistivity 19-5ep-2004 ! w/Graphics I 25 Slu 110 7502 Open 10/25/2006 NO Composit COR i Resistivity 19-5ep-2004 w/Graphics í I 165 7500 Open 1 0/24/2006 FET, ROP, GR i --,------------- ___.~_._..__.___..__..___._..J Name Directional Survey Directional Survey Cement Evaluation 14010 Induction/Resistivity 14010 Induction/Resistivity 14010 Induction/Resistivity 14010 Induction/Resistivity 14010 Induction/Resistivity 14197 Induction/Resistivity 14197 Induction/Resistivity Interval Start Stop Sample Set Number Comments Sent Received DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2041370 Well Name/No. PRUDHOE BAY UN AURO S-123 API No. 50-029-23219-00-00 Operator BP EXPLORATION (ALASKA) INC MD 7502 Completion Date 1/23/2005 UIC Y Completion Status WAGIN Current Status WAGIN NO 6927 ADDITIONAL INFORMATION Well Cored? Y.Gì> Chips Received? "'T'7"I'r Analysis -¥1"f\J Received? Daily History Received? &/N (j)/ N Formation Tops _..~~~-,._-'.---~---,,-_._-.~-~---^~-~- --~-~~~.~--~._"--,_._._----,-- ---~-----"--'-'-- --~~-'~"----'--"- --_.~--~---- Comments: ~-~-._~--_.~_. . =~=Jk'- --~----- _.,_._._---_...~--,---,---------- ~._-~- Compliance Reviewed By: _ _______~____ ---_._-------_._._--,----..__._--~._----_.__._------_.._--~.._._----,----- --------------~~te:----(O---~-~-7- . . 10124106 Scldumbergel' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;); ,- ·f1\O)f." Qþ l!Jut) NO. 4013 (Jill!. Ct1m111Í$~m Company: Alaska Oil & Gas Cons Comm Altn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Well Job# log Description Date BL Color CD 5-123 40010951 OH EDIT OF MWD/LWD 09119/04 2 1 S-119 40010957 OH EDIT OF MWD/LWD 10111/04 2 1 L-216 40010478 OH EDIT OF MWD/LWD 05107/04 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2~ 1 900 E Benson Blvd. Anchorage AK 99508·4254 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth Date Delivered Received by . u .:c c- d6'--1- 13 '7 tt /'-/1 C] '9- 08/07/06 Scldumbel'ger NO. 3903 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth USC-.- (}6<.(-/37- .$ J~D{ 0 Company: Alaska Oil & Gas Cons Comm Altn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job# Log Description Date BL Color CD . S-118 10687665 OH EDIT OF WIRELlNE LOGS 01109/04 3 1 S·120 10621756 OH EDIT OF WIRELINE LOGS 12/28/03 4 1 S·123 10877787 OH EDIT OF WIRELINE LOGS 09/20/04 4 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2·1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambell SI. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: . RECEiVED AUG 0 i3 2006 Al<1ska Oil & Gas Coos. commission And10rage ~ ff/ct/ 0(" 1 ( ''� 2.09-- f3 1 1-3 `69 5 WELL LOG TRANSMITTAL To: State of Alaska April 27, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7°i Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs E -18B PBI, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 E -18B PBl: LAS Data & Digital Log Images: 50-029-20654-70 SC NEV MAY 18 2000 t$t-133 � 5/e5-l/of 0— _�1 �� 1 CD Rom _.J- , ," l _ STATE OF ALASKA . ALAS~L AND GAS CONSERVATION COM ",SiaN REC WELL COMPLETION OR RECOMPLETION REPORT AND LOG .'. EIVED Revised: OM.éM5~' ~~ectlon 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended 1m WAG 1 b. Wl¡al$f*t1ß: & G ~ 20AAC 25.105 20AAC25.110 o Developme~~ ~8f,r~SBi OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphi 'Gllårli:e 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/23/2005 204-137 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/12/2004 50- 029-23219-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/19/2004 PBU 5-123 3642' NSL, 3938' WEL, SEC. 35, T12N, R12E 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2977' NSL, 1825' WEL, SEC. 35, T12N, R12E, UM 60.45' Prudhoe Bay Field / Aurora Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2969' NSL, 1789' WEL, SEC. 35, T12N, R12E, UM 7385 + 6812 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 619504 y- 5979855 Zone- ASP4 7502 + 6927 Ft ADL 028257 -------- ---- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 621628 y- 5979224 Zone- ASP4 Total Depth: x- 621664 y- 5979217 Zone- ASP4 (Nipple) 2212' MD - ------ -- -- -- -- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 1m Yes ONo N/ A MSL 1900' (Approx.) 21. Logs Run: MWD / GR / RES / DEN / NEU, MWD / GR / PWD, PEX / BHCS, US IT 122. CASING, liNER AND CEMENTING RECORD CASING .' SETTING UEPTHMD . ::ïETTINGUEPTH TVO Hou: AMOUNT SIZE WT. PER FT. GRADE lOP I BOTTOM fOP BOTTOM Size PULU:D 20" 91.5# H-40 Surface 110' Surface 110' 42" 1260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 / K-55 27' 2926' 27' 2868' 12-1/4" 1440 sx AS Lite, 387 sx Class 'G' 7" 26# L·80 25' 7471' 25' 6896' 8-3/4" 332 sx Class 'G', 144 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUSING RECORD . Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 7125' 7064' MD TVD MD TVD 7278' - 7308' 6706' - 6736' 25. . ACID,. ....fV\v I i:-fÇ. 7314' - 7326' 6742' - 6753' -, ..... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 74 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 18, 2005 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Sub~.!t_por~.chip§; if none, state "none". ,,\:.,-,"'- " :¡J,.\.;;. None 'i_dr~ 't,¿Z"~ RBDMS 8FL MAR 3 1 2005 ¡, Vr""-""O . ....~'!. ~ _.1.' 0 ,..., (j¡:' 'j . ....-"_.3~ ~: ;". I. ~_._......,.¡,.",.-....\C - '. \...-. n Form 1 0 407 Revised 12/2003 CONTINUEO.ON REVERSE SIDE .,., " ~ l , 28. GEOLOGIC MARKE 29. ORMATION 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". Ugnu 3866' Ugnu M Sands 5230' Schrader Bluff N Sands 5445' Schrader Bluff 0 Sands 5573' Base Schrader Bluff 1 Top Colville 5897' HRZ 7232' Kalubik 7267' Kuparuk C 7272' Kuparuk A 7309' Miluveach 7371' 3630' 4769' None 4954' 5068' 5360' 6661' 6695' 6700' 6737' 6798' 30. List of Attachments: Summary of Daily Drilling Reports. Well Schematic Diagram. Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./ Terrie Hubble .r 1.0. Title Technical Assistant PBU S-123 Well Number 204-137 Permit No. I A roval No. 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Jim Smith, 564-5773 ITEM 18: 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 above 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, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only _ STATE OF ALASKA . ALAS~L AND GAS CONSERVATION COM. SiaN WELL COMPLETION OR RECOMPLETION REPORT AND LOG ¡ , ) C. 1 a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended Da WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic Da Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/23/2005 204-137 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/12/2004 50- 029-23219-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/19/2004 PBU 5-123 3642' NSL, 3938' WEL, SEC. 35, T12N, R12E 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2977' NSL, 1825' WEL, SEC. 35, T12N, R12E, UM 60.45' Prudhoe Bay Field I Aurora Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2969' NSL, 1789' WEL, SEC. 35, T12N, R12E, UM 7385 + 6812 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 619504 y- 5979855 Zone- ASP4 7502 + 6927 Ft ADL 028257 TPI: x- 621628 y- 5979224 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 621664 y- 5979217 Zone- ASP4 (Nipple) 2212' MD ------ ~--- -~ ---- --. -. ----- -- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey Da Yes DNo NI A MSL 1900' (Approx.) 21. Logs Run: MWD I GR I RES I DEN I NEU, MWD I GR I PWD, PEX I BHCS, USIT 22. CASING, LINER AND CEMENTING RECORD CASING . SETTING DEP"J'H MD :smlNG UEPTH TV!) HOLE ~OlJ.1'lf SIZE WT.PER Fr. GRADE SIZE '"" TOP BOTTOM TOP I BOTTOM . PULLED 20" 91.5# H-40 Surface 110' Surface 110' 42" 60 sx Arctic Set (Approx.) 9-5/8" 40# L-80 I K-55 27' 2926' 27' 2868' 12-1/4" 40 sx AS Lite, 387 sx Class 'G' 7" 26# L-80 25' 7471' 25' 6896' 8-3/4" 32 sx Class 'G', 144 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. ,. JBING . , Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 7125' 7064' MD TVD MD TVD 7278' - 7308' 6706' - 6736' 25. ACIj)¡., 0:+,.,. 7314' - 7326' 6742' - 6753' ......"'..~...., . . "'........ '.i,. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 74 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet NIA Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-MCF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED + Oil -BSl GAs-McF WATER-Bsl Oil GRAVITy-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). tQ.~~.~~:~:c;hiPS; if none, state "none". RBDMS BFL MAR 0 1 2005 co"" L.. Lt.",! " N°{d~~( f \ G \ N Þ\ L I ~ED ~ I': . ~ '~:.::.J Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE · 28. GEOLOGIC MARKERS 29. ORMATION 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". Ugnu 3866' Ugnu M Sands 5230' Schrader Bluff N Sands 5445' Schrader Bluff 0 Sands 5573' Base Schrader Bluff I Top Colville 5897' HRZ 7232' Kalubik 7267' Kuparuk C 7272' Kuparuk A 7309' Miluveach 7371' 3630' 4769' None 4954' 5068' 5360' 6661' 6695' 6700' 6737' 6798' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date O^j;l.g QS PBU S-123 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Jim Smith, 564-5773 204-137 Permit No. I A roval No. 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 above 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, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only Printed: 9/27/2004 9:58:16 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRlll+COMPlETE DOYON DRilLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/11/2004 9/24/2004 Spud Date: 9/12/2004 End: 9/24/2004 9/9/2004 20:00 - 00:00 4.00 MOB P PRE - Bridle up blocks, prepare rig floor for move, clean cellar, pull mats, remove derrick pins, lower derrick & move rig off of Z-23. 9/10/2004 00:00 - 02:00 2.00 MOB P PRE - Install rear booster & move rig to first corner on access road 102:00 - 08:00 approx. 100 yds from Z pad. Broke hinge on moving system. Traffic to & from Z Pad not affected. 6.00 MOB N RREP PRE - Air arc broken hinge on moving system & weld new hinge. 08:00 - 22:30 14.50 MOB P PRE - Move rig from Z Pad to S-123. Arrive on S-Pad @ 22:30 hrs. 22:30 - 00:00 1.50 MOB P PRE - Remove rear booster & gooseneck. 9/11/2004 00:00 - 03:00 3.00 MOB P PRE - Remove front booster & gooseneck. - Move & spot rig to raise derrick. - Inspect & grease sheaves in derrick. 03:00 - 04:30 1.50 MOB P PRE - Raise & pin derrick. i 04:30 - 08:00 - R/U tuggers & pin torque tube. 3.50 MOB P PRE - Move & spot rig over S-123. Shim & level rig 108:00 - 13:00 5.00 MOB P PRE - Spot & RIU pump, power & pit modules. - RIU floor manifold, raise cattle chute, unbridle & hang lines, RIU TD, trim excees pit liner & R/U floor. - Accept rig @ 13:00 hrs. 13:00 - 16:00 3.00 RIGU P PRE - Take on fresh water - circulate & test transfer lines, pumps, pits & valves. - Pull riser from cellar for mods. - Install bails & elevators 16:00 - 23:00 7.00 RIGU P PRE - Spot MWD & Mud Eng shacks. - Change shaker screens & prepare shakers. - Welder modifying riser. - Load 147 jts 5" DP & 20 jts HWDP in pipeshed & strap. - Load BHA in pipeshed & strap same 23:00 - 00:00 1.00 RIGU P PRE - P/U 5" DP 1 x 1 & rack back stands in derrick. 9/12/2004 00:00 - 04:00 4.00 RIGU P PRE - P/U 5" DP 1 x 1 & rack back stands in derrick. 04:00 - 07:30 3.50 RIGU P PRE - Install riser, flow line, turnbuckles, trip tank hoses & build berm for cellar box. 07:30 - 09:30 2.00 RIGU P PRE - Perform diverter & accumulator test. - Fill conductor & diverter riser wI fresh water & check for leaks. - Pressure test circulating system wI fresh water to 1000 psi. - Witness of diverter test waived by AOGCC Rep Chuck Scheve. 09:30 - 14:00 4.50 RIGU P PRE - P/U 5" DP & 5" HWDP 1 x 1 & rack back stands in derrick. 14:00 - 15:00 1.00 RIGU PRE - Service TO - Calibrate block height wI Anadrill. 15:00 - 16:00 1.00 RIGU P PRE - PJSM - Bring BHA components to floor. 16:00 - 17:30 1.50 RIGU P PRE - MIU BHA - 12 1/4" HTC MXC1 , 9 5/8" XP motor w/1.5 deg bent housing & 210' NMDC's. 17:30 - 19:30 2.00 DRILL P SURF - Clean out conductor & drill 12 1/4" surface hole to 234'. - Drill @ 8 - 10 BPM, 350 - 690 psi, 3 - 4 K WOB, 40 RPM Tq 2-3K ftIlbs on bottom. 19:30 - 22:00 2.50 DRILL P SURF - POH & rack back 2 stands 5" DP. - M/U BHA - NM stab, MWD, orienting sub, NM stab, 15' NMDC, NM XO, NM spiral DC, NM stab, NM spiral DC, saver sub, 6 1/4" jars & 2 jts HWDP. 22:00 - 00:00 2.00 DRILL P SURF - Drill 12 1/4" surface hole from 234' to 555'. Printed: 9/27/2004 9:58:28 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRlll+COMPlETE DOYON DRilLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/11/2004 9/24/2004 Spud Date: 9/12/2004 End: 9/24/2004 9/12/2004 22:00 - 00:00 2.00 DRILL P SURF - Drill @ 10- 11 BPM., 750 - 870 psi, 3-4 K WOB, 80 RPM Tq 4K Nibs on bottom - PIU wt 75K, S/O wt 75K, Rot wt 75K. - ART 1.12 hrs - ADT 1.12 hrs 9/13/2004 00:00 - 13:30 13.50 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 555' to 2,130'. WOB Sliding 20,000# - 25,000#, WOB Rotating 15,000# - 20,000# RPM 80, Motor RPM 121, Torque Off Bottom 3,000 ft I Ibs - On Bottom 5,000 ft /Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,400 psi, On Bottom 1,520 psi. String Weight Up 105,000#, String Weight Down 100,000#, String Weight Rotating 100,000#. ART = 5.26 hrs, AST = 2.37 hrs. Total Krevs = 80.6. 13:30 - 14:30 1.00 DRILL P SURF Pumped and Circulated Around 40 bbl Weighted Sweep. Pump Rate 650 gpm, SPP 1,770 psi. Reciprocated and Rotated Drill Pipe 100 RPM. Circulated 3 x Bottoms Up. Flow Checked Well, Well Static. Blew Down Top Drive. 14:30 - 17:00 2.50 DRILL P SURF POOH for Bit Trip from 2,130' to Surface. Maximum Overpull 20,000#, Worked Through Tight Spot at 1,850', 1,730' and 1,550'. 17:00 - 20:00 3.00 DRILL P SURF - Break out & LID MWD, NMLC's & bit. - Clear & clean floor. - M/U new MWD, LWD wI Res, & new 121/4" HTC MX-C1 bit. SIN 6026343. Old bit in good shape 1-1. 20:00 - 21 :00 1.00 DRILL P SURF - RIH w/ BHA # 2 to 2013' 21 :00 - 22:00 1.00 DRILL P SURF - Tag up @ 2013' - M/U TD, wash & ream from 2013' to 2035' @ 3.5 BPM 500 psi, 35 RPM. - Mad pass from 2035' to 2130' 22:00 - 23:00 1.00 DRILL P SURF - CBU @ 10 BPM 730 psi, 50 RPM. - Displace 290 bbls old mud to slop tank & replace w/290 bbls new 8.5 ppg mud. 6.5 BPM 420 psi, 50 RPM. 23:00 - 00:00 1.00 DRILL P SURF - Drill & slide in 12 1/4" hole from 2130' to 2194'. WOB 15-25K, 13BPM 1530 psi, 80 RPM, Tq on bottom 5K Nibs, Tq off bottom 3K Nibs. PIU wt 105K, S/O wt 100K, Rot wt 105K. ART .38 hrs, AST .62 hrs, ADT 1.00 hr 9/14/2004 00:00 - 08:30 8.50 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 2,194' to 2,874'. WOB Sliding 15,000# - 25,000#, WOB Rotating 15,000# - 25,000# RPM 80, Motor RPM 121, Torque Off Bottom 5,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,350 psi, On Bottom 1,500 psi. String Weight Up 125,000#, String Weight Down 115,000#, String Weight Rotating 120,000#. Note: Drilled from 2,820' to 2,874' w/1 Pump, 450 gpm, 650 psi, Rough Drilling from 2,820' to 2,860'. MWD had Trouble Acquiring Signal wI Noise from Rough Drilling and 1 Pump. 08:30 - 09:30 1.00 DRILL P SURF Second Pump Back on the Hole. Made MAD Pass and Took Surveys from 2,874' to 2,810'. 09:30 - 10:30 1.00 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 2,874' to 2,941'. WOB Sliding 15,000# - 20,000#, WOB Rotating 15,000# - 25,000# RPM 80, Motor RPM 121, Torque Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/11/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/12/2004 End: 9/24/2004 9/14/2004 09:30 - 10:30 1.00 DRILL P SURF Off Bottom 5,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,350 psi, On Bottom 1,500 psi. String Weight Up 125,000#, String Weight Down 115,000#, String Weight Rotating 120,000#. 10:30 - 11 :00 0.50 DRILL P SURF Circulated Bottoms Up 600 gpm, 1,650 psi. RPM 80. 11 :00 - 11 :30 0.50 DRILL P SURF POOH fl Wiper Trip from 2,941', Encountered 40,000# Overpull at 2,900'. M I U Top Drive to Backream, Engaged Pumps, Wash Pipe on Top Drive Failed. 11 :30 - 12:00 0.50 DRILL N RREP SURF L / D 2 Singles, M / U Circulating Head and Hose and Circulated Well While Replacing Wash Pipe. 12:00 - 12:30 0.50 DRILL P SURF Serviced Rig. 12:30 - 17:00 4.50 DRILL P SURF M I U Top Drive, Backreamed from 2,941' to 2,850'. Pump Rate 500 gpm, 1,200 psi. Broke Out Top Drive and POOH f/ Wiper Trip, Encountered Tight Spots at 2,825',2,700',2,630'. 40,000# Overpull at 2,630', RIH Stacked Out at 2,660', M / U Top Drive Attempted to Wash Past 2,660' w/ Varied Parameters, Oriented Tool to Original Toolface While Sliding Through This Section, Could Not Get Below 2,660'. Backreamed Several Times to Knock Off Ledge from 2,660' to 2,575', Pump Rate 550 gpm, 1,250 psi, RPM 80. RIH, Pump Rate 250 gpm, 300 psi, RPM 20, Worked Past 2,660' to 2,700'. Backreamed Several Times from 2,700' to 2,600', Pump Rate 550 gpm, 1,250 psi, RPM 80. Broke Out Top Drive and Blew Down, Continued to POOH fl Wiper Trip to 5" HWDP at 812'. 17:00 - 18:00 1.00 DRILL P SURF RIH from 812' to 2,880', Tight spots at 2,012',2,096' and 2,250'. Wiped through without Problem. Washed Down as a Precaution from 2,880' to 2,941'. Pump Rate 400 gpm, 1,000 psi. 18:00 - 20:00 2.00 DRILL P SURF Pumped Weighted Sweep and CBU X 3. Pump Rate 600 gpm, 1,370 psi, 100 RPM. Reciprocated Pipe. String Weight Up 130K, String Weight Down 115K, Rotating Weight 123K. Torque on Bottom 6,000 ft / Ibs. 20:00 - 22:30 2.50 DRILL P SURF POOH from 2,941' with DP. No Significant Overpull noted on Trip out. Hole in Good Condition. 22:30 - 00:00 1.50 DRILL P SURF POOH w/ BHA. Racked Back HWDP. L /0 BHA #2. 9/15/2004 00:00 - 01 :30 1.50 DRILL P SURF PJSM. Continued to L / D 12.25" BHA #2. LD bit, Hughes MXC1 SIN 6026343. Graded 1-1. 01 :30 - 02:00 0.50 DRILL P SURF Cleared and Cleaned Rig Floor. 02:00 - 03:00 1.00 CASE P SURF Held PJSM. R I U to Run 9-5/8" Surface Casing. P / U 9-5/8" Casing Hanger and Landing Joint. Made Dummy Run w/ Casing Hanger and Landed Out, Marked Landing Joint, LID 9-5/8" Casing Hanger and Landing Joint. R I U Casing Fill up Tool. 03:00 - 04:00 1.00 CASE P SURF M / U Float Shoe Joint, 1 Jt of 9-5/8" Casing and Float Collar Joint. Filled Casing and Checked Float Equipment, OK. Bakerloc'd All Connections on Shoe Track. 04:00 - 10:30 6.50 CASE P SURF M I U and RIH wI 70 Joints 9-5/8", 40.0#, L-80, BTC Casing. Average M I U Torque 10,000 ft / Ibs. M I U 9-5/8" Casing Hanger and Landing Joint. Landed Casing Mandrel Hanger. 9-5/8" Casing Set As Follows: Item Length Depth Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/11/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/12/2004 End: 9/24/2004 9/15/2004 04:00 - 10:30 6.50 CASE P SURF 10:30 - 11 :00 0.50 CASE P SURF 11:00 -14:00 3.00 CEMT P SURF 14:00 - 17:00 3.00 CEMT P SURF Float Shoe 2 Jts 9-5/8" 40.0# L-80 BTC Csg Float Collar 68 9-5/8" 40.0# L-80 BTC Csg 9-5/8" Casing Hanger 1.73' 84.70' 1.23' 2,809.57' 3.25' 2,926.20' 2,882.78' 2,841 .50' 30.70' 27.45' Centralizers on first 15 joints. Stop rings on joints #1 and #2. String weight down=110K String weight up=140K LD fillup tool. MU cement head. Loading of plugs witnessed by drilling supervisor. Circulated to Condition Hole. Lowered vis from 300 to 65. Staged pumps as follows: Rate ICP 2 BPM 330 psi 4 BPM 450 psi 6 BPM 600 psi 10 BPM 940 psi FCP 190 psi 390 psi 800 psi Pump Rate 10 bpm, SPP 800 psi. Reciprocated Casing while Circulating. String Weight Up 140,000#, String Weight Down 110,000#. NOTE: At 1230 hrs, Up Weight Increased to 155,000#. Landed Casing. Held PJSM w/Dowell crew, Rig Crew, Truck drivers. Switched over to Dowell. Pumped 5 bbls of water at 2.5 bpm, 150 psi. Shut in cement manifold and tested lines to 3,500 psi. OK. Pumped 75 bbls mud push at 4 bpm., 250 psi. Dropped bottom plug, pumped 335 bbls (446 sks) 10.7 ppg ArticSet Lite III Lead Cement, followed by 80 bbls (382 sks) 15.8 ppg Premium Tail cement wI 0.300% bwoc dispersant, 0.40% bwoc Fluid Loss, 0.20% bwoc Antifoam, and 0.40% bwoc UniFLAC-S. Pumped cement at the following rates: Pumped Rate Lead Cement 20.0 bbls 6.25 bpm 600 psi 100.0 bbls 6.00 bpm 545 psi 200.0 bbls 6.00 bpm 544 psi 300.0 bbls 6.00 bpm 650 psi NOTE: Mud Push back to surface with 319 bbls lead pumped. 335.0 bbls 4.00 bpm 475 psi Tail Cement 350.0 bbls 5.00 bpm 1000 psi 375.0 bbls 5.50 bpm 1035 psi 415.0 bbls 2.75 bpm 320 psi Dropped top plug, pumped 5bbls water at 5.7 bpm, 365 psi. Switched to rig pumps and displaced w/209 bbls mud at the following rates: Pumped 50.0 bbls 100.0 bbls 150.0 bbls Pressure Rate 8.00 bpm 8.00 bpm 8.00 bpm Pressure 590 psi 670 psi 910 psi Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/11/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/12/2004 End: 9/24/2004 9/15/2004 14:00 - 17:00 3.00 CEMT P SURF 200.0 bbls 8.00 bpm 1 ,170 psi Slowed pumps to 3 bpm 214.0 bbls 3.00 bpm 810 psi Wiper plug bumped w/214 bbls total displacement pumped. Pressured up to 3,000 psi, Floats held, OK. Approx. 200 bbls of lead cement to surface. Cement in place @ 16:50 hrs. 17:00 - 18:00 1.00 CEMT P SURF R / D Cement Head and Casing Equipment. Drained Stack. L / D Landing Joint. 18:00 - 19:30 1.50 CASE P SURF Cleared and Cleaned Rig Floor. Changed Out Bails. Installed TDS blower motor covers. 19:30 - 00:00 4.50 DIVRTR P SURF PJSM. R / U flushing tool and flushed stack with water at 7 bpm. PJSM. N / D diverter lines, diverter and starter head. 9/16/2004 00:00 - 02:00 2.00 DIVRTR P SURF Continue ND diverter and position in cellar. 02:00 - 04:00 2.00 WHSUR P SURF Nipple up Gen 5 S Slimhole 13-5/8" x 5,000 psi Split-Speed Wellhead. Tested to 1,000 psi f/ 10 minutes, OK. NU tubing spool. 04:00 - 10:30 6.50 BOPSU P SURF Install 11" X 13-3/8" XO. Remove bottom rams. Remove choke/kill valves and mud cross from BOP stack. 10:30 - 18:30 8.00 BOPSU P SURF NU BOP. Re-install bottom rams. Set stack on XO spool. RU and pick up BOP stack, rotate 90 degrees to position outlets for choke and kill line valves. RU choke and kill line valves and hoses. RU riser, flowlines, Koomey lines, drain lines. Add upper annulus valve. Function test all BOP controls. Clean cellar area. 18:30 - 19:30 1.00 BOPSU SURF R / U Test Equipment to Test BOPE. M I U Test Joint and Test Plug. RIH and Set Plug in Wellhead. Opened Annulus Valve. Filled BOP Stack. 19:30 - 00:00 4.50 BOPSU P SURF Held PJSM. Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 5,000 psi High /250 psi Low. Tested Annular Preventer to 3,500 psi High /250 psi Low. All Tests Held fl 5 Min. NOTE: IBOP failed initial test. Continue testing components while troubleshooting upper IBOP. Found trouble with IBOP control linkage, adjusted same. Witness Of BOP Test Waived By AOGCC Inspector Lou Grimaldi at 17:30 hrs 9/16/04 9/17/2004 00:00 - 01 :30 1.50 BOPSU P SURF Hold Pre-Job Safety Meeting. Complete Testing BOP And Related Equipment at 250 Psi Low and 5,000 Psi High. Upper IBOP passed re-testing. Witness Of BOP Test Waived By AOGCC Inspector Lou Grimaldi at 17:30 hrs 9/16/04 01 :30 - 02:00 0.50 BOPSU P SURF Blew Down All Lines, Closed Annular Valve, Pulled Test Plug, L /0 Test Joint. RID BOPE Test Equipment. Ran and Set Wear Bushing. 02:00 - 04:30 2.50 DRILL P PROD1 Held PJSM. M I U BHA #3.8-3/4" Hycalog DS-70 (Rebuilt) PDC Bit, Ser# 204643, dressed w/6x14 jets - 6-3/4" XP 4/5 7.0 stg Motor w/1.15 deg Bent Housing - XO (w/ported float) - NM 8-1/2" Stabilizer - COR - MWD - NM 8-3/4" Stabilizer - 2 x NM Spiral Drill Collars - NM 8-3/4" Stabilizer - NM 6-9/16" Spiral Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/11/2004 9/24/2004 Spud Date: 9/12/2004 End: 9/24/2004 9/17/2004 02:00 - 04:30 2.50 DRILL P PROD1 Drill Collar - Saver Sub· 6·1/4" Drilling Jars - 20 Jts 5" HWDP . 6·1/2" Straight Blade Reamer. Total BHA Length· 829.28'. Oriented to MWD. M I U Top Drive and Tested MWD Tools, OK. 04:30 - 05:30 1.00 DRILL P PROD1 Slip and cut Drill line. 05:30 - 06:00 0.50 DRILL P PROD1 Service TDS. 06:00 - 06:30 0.50 DRILL P PROD1 Shallow test MDW. Blow down surface lines. 06:30 . 10:00 3.50 DRILL P PROD1 RIH to 2,800' with 5" DP from pipe shed. 10:00 - 11 :00 1.00 DRILL P PROD1 Wash down from 2,800' and tag float equipment at 2,838'. Circulated Bottoms Up. String Weight Up 125,000, String Weight Down 115,000, Rotating Weight 120,000, RPM 40, Torque 5,000 ft /Ibs, Pump Rate 420 gpm, 1,000 psi. 11 :00 - 12:00 1.00 EVAL P PROD1 R 1 U Equipment, Pressure Tested 9·5/8" 40#, L-80, BTC Casing to 3,500 psi fl 30 minutes, OK. 12:00 - 12:30 0.50 DRILL P PROD1 R / 0 Test Equipment, Blew Down Lines. 12:30 - 14:00 1.50 DRILL P PROD1 Drilled Out Shoe Track from 2,838'·2,926'. WOB 2,000#- 5,000#, RPM 40, Torque 5,000 ft /Ibs, Pump Rate 420 gpm, 950 psi. 14:00· 14:30 0.50 DRILL P PROD1 Cleaned Out Rathole 2,926'-2,941'. Drilled 20' New 8·3/4" Hole 2,941'·2,961'. WOB 3,000#, RPM 45, Motor RPM 212, Torque 4,000 ft Ilbs, Pump Rate 425 gpm, 950 psi. 14:30 . 16:00 1.50 DRILL P PROD1 PJSM. Displaced Well bore to New 9.5 ppg LSND Mud. Pump Rate 420 bpm, 720 psi. 16:00 - 17:30 1.50 DRILL P PROD1 PJSM. Cleaned Pits #2 and #4, Change Over Flowline. 17:30 . 18:00 0.50 DRILL P PROD1 Circulated and Conditioned Mud fl LOT. Pump Rate 588 gpm, 1,200 psi, RPM 50. 18:00 . 18:30 0.50 DRILL P PROD1 R / U Circulating Head and Lines f/ LOT. Performed LOT, Pump Rate 0.5 bpm to Leak Off at 725 psi. Calculated EMW 14.37. Shoe at 2,926' MD, 2,868' TVD, Hole Depth 2,961', MW 9.5 ppg. Bled Off Pressure, Opened Rams, Blew Down and R 1 D Equipment. 18:30 . 19:00 0.50 DRILL P PROD1 RIH to 2,958'. Established Parameters, String Weight Up 125,000#, String Weight Down 115,000#, Rotating Weight 122,000#. Clean Hole ECD 10.35 ppg. SPR, Pump #1 30 spm·150 psi; 40 spm-200 psi; Pump #230 spm-150 psi; 40 spm·200 psi. 19:00 - 00:00 5.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 2,961' to 3,654'. WOB Sliding 5,000# - 7,000#, WOB Rotating 3,000# - 8,000#, RPM 120, Motor RPM 300, Torque Off Bottom 5,000 ft Ilbs . On Bottom 7,000 ft Ilbs, Pump Rate 600 gpm, SPP Off Bottom 1,400 psi, On Bottom 1,650 psi. String Weight Up 128,000#, String Weight Down 118,000#, String Weight Rotating 125,000#. Calculated ECD 10.56 ppg, Actual ECD 10.62.ppg. Pumped 30 bbl Hi-Vis Sweeps Every 300', Pumped 30 bbl Weighted Sweeps Every 900. AST = 0.65 hrs, ART = 1.32 hrs. 9/18/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drilled 8·3/4" Directional Hole by Rotating and Sliding from 3,654' to 5,470'. WOB Sliding 5,000# - 6,000#, WOB Rotating 3,000# - 8,000#, RPM 120, Motor RPM 300, Torque Off Bottom 9,000 ft /Ibs - On Bottom 11,000 ft Ilbs, Pump Rate 600 gpm, SPP Off Bottom 1,800 psi, On Bottom 2,020 psi. String Weight Up 175,000#, String Weight Down 135,000#, String Weight Rotating 154,000#. Calculated ECD 10.43 ppg, Acutal ECD Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/11/2004 9/24/2004 Spud Date: 9/12/2004 End: 9/24/2004 9/18/2004 00:00 - 12:00 12.00 DRILL P PROD1 10.90.ppg. Pumped 30 bbl Hi-Vis Sweeps Every 300', Pumped 30 bbl Weighted Sweeps Every 900'. AST=.76 ART=5.19 ADT =5.95 12:00 - 00:00 12.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 5,470' to 7,038'. WOB Sliding 9,000# - 10,000#, WOB Rotating 8,000# - 15,000#, RPM 120, Motor RPM 300, Torque Off Bottom 12,000 ft /Ibs - On Bottom 14,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,100 psi, On Bottom 2,500 psi. String Weight Up 225,000#, String Weight Down 155,000#, String Weight Rotating 180,000#. Calculated ECD 10.84 ppg, Acutal ECD 11.26.ppg. Pumped 30 bbl Hi-Vis Sweeps Every 300', Pumped 30 bbl Weighted Sweeps Every 900'. AST=2.25 ART=4.51 ADT =6.82 Note: Weight up mud from 9.5 ppg to 9.9 ppg prior to entering the HRZ at 7,220'. 9/19/2004 00:00 - 04:00 4.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating from 7,038' to 7,502'. WOB Rotating 20,000# - 25,000#, RPM 120, Motor RPM 300, Torque Off Bottom 11,000 ft Ilbs - On Bottom 13,000 ft / Ibs, Pump Rate 610 gpm, SPP Off Bottom 2,110 psi, On Bottom 2500 psi. String Weight Up 230,000#, String Weight Down 158,000#, String Weight Rotating 188,000#. Calculated ECD 10.72 ppg, Acutal ECD 11.34.ppg. AST=O ART =2.81 ADT=2.81 04:00 - 05:00 1.00 DRILL P PROD1 Pumped and Circulated Around 40 bbl Weighted Sweep. Pump Rate 600 gpm, SPP 2,210 psi. Rotated Drill String 130 RPM and Reciprocated Drill String While Circulating. 05:00 - 10:30 5.50 DRILL P PROD1 POOH w/5" DP fl Wiper Trip from 7,502' - 3,000'. Tight hole from 7,502' to 7,202'. 20,000# drag and overpull. Backream from 7,202' to 6,600'. 80 RPM, 378 GPM, SPP 1,240 psi. POOH from 6,600' to 3,000' without difficulty. 10:30 - 13:30 3.00 DRILL P PROD1 RIH from 3,000' to 7,210'. Tagged up at 7,210', washed down to 7,502'. 600 GPM, SPP 2,300 psi, 120 RPM, Torque 9,000 fVlbs. 13:30 - 14:30 1.00 DRILL P PROD1 Pumped and Circulated Bottoms Up. Pump Rate 600 gpm, SPP 2,100 psi. Rotated Drill String 130 RPM and Reciprocated Drill String While Circulating. Continued Circulation Until Returns Over Shaker Were Clean. 14:30 - 16:30 2.00 DRILL P PROD1 POOH For 2nd Wiper Trip. 15,000# - 20,000# Drag From 7,500' to 7,300'. Backreamed From 7,300' to 6,900'. 600 GPM, SPP 2,300 psi, 120 RPM. POOH 6,900' to 5,200'. 5,000# to 7,000# drag. 16:30 - 17:30 1.00 DRILL P PROD1 RIH from 5,200' to 7,502'. Precautionary wash down last stand. 600 GPM, SPP 2,300 psi. 17:30 - 20:00 2.50 DRILL P PROD1 Pumped and Circulated Around 40 bbl Weighted Sweep Followed By 3 Bottoms Up. Pump Rate 600 gpm, SPP 2,300 psi. Rotated Drill String and Reciprocated Drill String While Circulating. 120 RPM, Torque 12,000 ftllbs. 20:00 - 21 :30 1.50 DRILL P PROD1 Monitor Well, Static. POOH from 7,502' to 5,900'. String Weight Up 260,000#, String Weight Down 160,000#. Tight Spot From 7,388' to 7,360',40,000# overpull. Wiped through x 2, Then Pulled Through Without Difficulty, Drag 3,000# to 5,000#. Hole Taking Proper Amount of Fill While Tripping. Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/11/2004 9/24/2004 Spud Date: 9/12/2004 End: 9/24/2004 9/19/2004 20:00 - 21 :30 1.50 DRILL P PROD1 Mixed 250 bbl G-Seal Pill While POOH. 21 :30 - 22:00 0.50 DRILL P PROD1 Spot 225 bbl G-Seal Pill From 5,900' To 2,926' Over the Schrader I Ugnu / and SV Sands. 425 GPM, SPP 1,150 psi. Pump Dry Job. Blow Down Surface Equipment. 22:00 - 00:00 2.00 DRILL P PROD1 POOH from 5,900' to 2,235' Without Difficulty. String Weight Up 200,000#. Drag 2,000# to 3,000#. 9/20/2004 00:00 - 01 :30 1.50 DRILL P PROD1 POOH from 2,235'. Rack back DC, Jars and HWDP. 01 :30 - 03:00 1.50 DRILL P PROD1 POOH wi Directional BHA. Racked 5' HWDP, Jars and Drill Collars in Derrick. Flushed, Broke Down and L / D Directional BHA Components and Bit. Bit graded 5-4. 03:00 - 03:30 0.50 DRILL P PROD1 Clean and Clear Rig Floor. 03:30 - 04:00 0.50 EVAL P PROD1 PJSM With All Rig Crew And Schlumberger E-Line Crew Concerning RU of E-Line Equipment and Running Logs.. 04:00 - 05:30 1.50 EVAL P PROD1 RU Schlumberger E-Line Equipment, 7" Lubricator And Pressure Control Equipment. 05:30 - 08:30 3.00 EVAL P PROD1 Run PEXlBHCS Open Hole Logs on E-Line. E-Line TO 7,507'. 08:30 - 10:30 2.00 EVAL P PROD1 RD Schlumberger E-Line and Lubricator. Blow Down Choke and Kill Lines. 10:30 - 12:00 1.50 DRILL P PROD1 MU BHA #4 Clean Out Assy. Bit (Smith-8.75", FDS+VC, Jetted with 3-20's & 1-16, sIn MR2643), Collar stand wi 2 Stabilizers, Jars, 20 jts HWDP. RIH on 5" DP to 743'. 12:00 - 12:30 0.50 DRILL P PROD1 Service TDS, Crown and Blocks. 12:30 - 15:30 3.00 DRILL P PROD1 RIH from 743' to 7,502'. String Weight Up 235,000#, String Weight Down 155,000#. 15:30 - 18:00 2.50 DRILL P PROD1 Pump 40 bbl Hi-Vis Weighted Sweep.. Circulate 3 Bottoms Up at 600 GPM, SPP 1,800 psi, 120 RPM. Rotary Torque 12,000 ftllbs. String Weight Up (Pumps On) 200,000# String Weight Down (Pumps On) 175,000#. 18:00 - 18:30 0.50 DRILL P PROD1 POOH LD DP. String Weight Up 235,000#, String Weight Down 155,000#. Encountered Tight Hole At 7,412'. 40,000# Overpull. 18:30 - 19:00 0.50 DRILL P PROD1 Attempted To Work Through Tight Spot At 7,412', No Success. Backreamed from 7,412' to 7,319'. 3 BPM, SPP 140 psi, 40 RPM, Rotary Torque 13,000 ftllbs. Total Of 30 BBLS Pumped. 19:00 - 20:30 1.50 DRILL P PROD1 Shut Down Pumps And Rotary. POH LD DP from 7,319' to 5,900'. String Weight UP 230,000#, String Weight Down 155,000#. Drag 5,000# - 10,000#. 20:30 - 21 :30 1.00 DRILL P PROD1 Spot 225 bbl G-Seal Pill From 5,900' To 2,926' Over the Schrader / Ugnu I and SV Sands. 425 GPM, SPP 1,150 psi. Pump Dry Job. Blow Down Surface Equipment. 21 :30 - 00:00 2.50 DRILL P PROD1 POOH LD DP from 5,900' to 3,658'. Maximum String Weight Up 200,000#. 9/21/2004 00:00 - 03:00 3.00 DRILL P PROD1 POH LD 5" DP from 3,658' to 743". Maximum String Weight Up 140,000#. 03:00 - 04:00 1.00 DRILL P PROD1 LD HWDP 04:00 - 05:00 1.00 DRILL P PROD1 LD BHA #4 05:00 - 05:30 0.50 DRILL P PROD1 Clean and clear rig floor. 05:30 - 06:00 0.50 BOPSU P RUNPRD Pull wear bushing and install test plug. 06:00 - 07:30 1.50 BOPSU P RUNPRD Change top BOP rams to 4-1/2" X 7" VBR's 07:30 - 08:30 1.00 BOPSU P RUNPRD Test upper rams to 250/5000 psi. RD test equipment and pull test plug. 08:30 - 10:00 1.50 CASE P RUN PRO RU 7" csg equipment. 10:00 - 11 :00 1.00 CASE P RUN PRO MU 7" mandrel hanger and landing joint. Make dummy run. Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 9/11/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/12/2004 End: 9/24/2004 9/21/2004 11 :00 - 11 :30 0.50 CASE P RUNPRD PJSM with all rig personnel on running 7" csg. 11 :30 - 12:00 0.50 CASE P RUNPRD MU and check float equipment. 12:00 - 16:00 4.00 CASE P RUNPRD Run 7", 26#, L-80, BTC casing. Limit running speed to 30 seconds per joint. Break circulation every 20 jts. 16:00 - 16:30 0.50 CASE P RUNPRD Stage pumps to 6 bpm and CBU X 2 prior to entering open hole. 6 bpm @ 450 psi 16:30 - 23:00 6.50 CASE P RUN PRO Continue running 7" csg. Limit running speed to 1 minute per jt in OH. Fill every jt, break circ every 10 jts and wash down every 20th jt. PU 235k SO 155k @ 7462' 23:00 - 00:00 1.00 CASE P RUNPRD CBU while reciprocating csg at 7462'. 9/22/2004 00:00 - 00:30 0.50 CASE P RUNPRD Continue CBU while reciprocating csg at 7462'. 00:30 - 01 :00 0.50 CASE P RUNPRD Land Casing with shoe @ 7470.6'. RD Franks tool, blow down top drive and RU cement head. Ran 180 jts 7", 26#, L-80, BTC casing. Landed at 7470.6' 01:00 - 03:15 2.25 CEMT P RUN PRO Stage pumps to 6 bpm and CBU X 2 while reciprocating casing. 03: 15 - 03:45 0.50 CEMT P RUN PRO PJSM with Schlumberger, Veco, Peak and all rig personnel on cementing 7" casing. 03:45 - 04:30 0.75 CEMT P RUNPRD Air up & prime up. Pump 3 bbls water to fill cement lines. Pressure test lines to 4000 psi. Start batch mixing tail slurry. 04:30 - 04:45 0.25 CEMT P RUN PRO Pump 40 bbls 11 .0 ppg mud push XT spacer. 04:45 - 05:30 0.75 CEMT P RUNPRD Drop bottom plug. Mix and pump 116 bbls (333 sxs) 12.8 ppg lead cement. Switch to tail cement. Pump 28 bbls (134 sxs) 15.8 ppg class G cement. 05:30 - 06:30 1.00 CEMT P RUNPRD Wash up cement lines through a T on the rig floor. Drop the top plug and displace with sea water using Schlumberger pumps at 6 bpm. Reduce rate 10 bbl prior to bump & bump plug on calculated displacement. Bump plug with 1000 psi, bleed pressure and check floats. CIP @ 06:30 06:30 - 08:30 2.00 CEMT P RUNPRD RD cement head. Pull landing joint. Change out bails and elevators. RD casing equipment. Clear rig floor. 08:30 - 09:30 1.00 WHSUR P RUNPRD RIH with 7" packott assembly. RILDS and test metal to metal seal to 5000 psi. 09:30 - 13:30 4.00 RUNCO RUNPRD Load pipe shed with 4-1/2" tbg. Clean threads, drift and strap tbg. 13:30 - 15:00 1.50 CASE P RUN PRO RU up to pump down 9-5/8" X 7" annulus. test lines to 2500 psi. Inject 70 bbls of 10.1 ppg mud down 9-5/8" X 7" annulus, initial injection pressure 1190 psi @ 1 bpm, final injection pressure 900 psi @ 3 bpm 15:00 - 18:30 3.50 RUNCO RUNCMP Continue strap, drift and clean 4-1/2" tbg. 18:30 - 19:30 1.00 CASE RUNPRD Pressure test 7" csg to 4500 psi for 30 minutes. 19:30 - 20:30 1.00 CASE RUNCMP Slip and cut drilling line. 20:30 - 21 :00 0.50 RUNCO RUNCMP PJSM with BOT and all rig personnel on running 4-1/2" completion. 21 :00 - 00:00 RUNCMP Run 4-1/2",12.6#, L-80, TC-II completion torque turning each joint. Printed: 9/27/2004 9:58:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-123 S-123 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/11/2004 9/24/2004 Spud Date: 9/12/2004 End: 9/24/2004 Midnight depth 1000' 9/23/2004 00:00 - 10:00 RUNCMP Continue running 4-1/2", 12.6#, L-BO. TC-II completion. Ran 166 jts 4-1/2" tbg, landed @ 7125' 10:00 - 10:30 0.50 RUNCMP RU to reverse circulate 10:30 - 12:00 1.50 RUNCMP Reverse circulate 115 bbls seawater, followed by 90 bbls corrosion inhibited seawater. 3 bpm @ 250 psi 12:00 - 12:30 0.50 RUNCMP RD 4-1/2" tbg equipment and clear rig floor. 12:30 - 13:00 0.50 RUNCMP Drop ball and rod. Pull landing joint 13:00 - 15:30 2.50 RUNCMP Set packer and test tbg to 4500 psi for 30 minutes. Bleed tbg pressure to 1500 psi. Test annulus to 4500 psi for 30 minutes. Bleed annulus pressure and tbg pressure. Increase annulus pressure to 2500 psi and shear DCK valve in upper GLM. Pump both ways though sheared valve, 3 bpm @ 700 psi. RD and blow down lines. 15:30 - 16:00 0.50 RUNCO RUNCMP Set TWC and test from below to 1000 psi. 16:00 - 19:00 3.00 BOPSU P RUNCMP ND BOPE 19:00 - 21 :30 2.50 WHSUR P RUNCMP NU adapter flange and tree. Test tree to 5000 psi 21 :30 - 22:30 1.00 WHSUR P RUNCMP RU DSM and pull TWC through lubricator. RD DSM 22:30 - 23:30 1.00 WHSUR P RUNCMP PJSM then RU Little Red. test lines and reverse circulate 74 bbls diesel to freeze protect well to 2200' MD 3bpm @ 900 psi 23:30 - 00:00 0.50 WHSUR P RUNCMP Allow well to U-tube, initial annulus pressure 140 psi 9/24/2004 00:00 - 01 :00 1.00 WHSUR P RUNCMP Allow well to U-tube. 01 :00 - 03:00 2.00 RIGD P POST RD and blow down lines. Secure well. Rig released @ 03:00 Printed: 9/27/2004 9:58:28 AM . . Well: S-123 Accept: 09/11/04 Field: Prudhoe Bay Unit Spud: 09/12/04 API: 50-029-23219-00-00 Release: 09/24/04 POST RIG WORK 12/04/04 PULLED B&R, PULLED DCK SHEAR VLV FROM STA 2, SET OGLV IN STA 2, PULLED RHC-M PLUG BODY, DRIFTED W/3-3/8" DUMMY GUN TO 7366' CORR MD (SAMPLE BAILER EMPTY) BTM SHOT AT 7326. 12/22/04 RAN USI FROM NEAR WELL BOTTOM TO TUBING TAIL. CEMENT IS GOOD FROM 7270' UP TO TUBING TAIL. CEMENT IS POOR NEAR BOTTOM, LIKELY DUE TO TOO MUCH DISPLACEMENT MUD PUMPED AFTER CEMENT WAS PUMPED. 01/21/05 T/l/O=1240/137010. TEMP=SI. TBG & IA FL. (WOE). TBG FL AT 3900', IA FL AT 270'. UNSURE ABOUT IA FL, OR lAP. THERE IS A FLANGED CHECK VALVE BETWEEN THE ONLY AVAILABLE NEEDLE VALVE ON THE lA, AND THE IA CASING VALVE. WELL HAS A JUMPER FROM S-05 lA, AND S-123 lA, AND ANOTHER FROM S-123 TBG TO S-05 TBG. 01/23/05 RIH WITH 3-3/8" GUN LOAD 12 FT OF 6 SPF 3406 PJ HMX 60 DEG PHASE GUN. CORRELATING TO SWS OH LOG 5" QUAD COMBO MEASURED DEPTH, LOG DATED 20-SEP-04. LOG INTO POSITION WITH CCL AT 7298.5 FT AND SHOOT. WHP BEFORE SHOOTING WAS 1000 PSI. GOOD INDICATION AT SURFACE OF FIRING. WHP STILL 1000 PSI. POOH. ON SURFACE, WHP = 1000 PSI. RIG DOWN SPENT GUN AND MAKE UP 3-3/8" GUN LOAD 10 FT OF 6 SPF 3406 PJ HMX 60 DEG PHASE GUN. CCL TO TOP SHOT IS 7.7 FT. REQUIRED PERF INTERVAL IS 7298 - 7308 FT. RIH. LOG INTO POSITION AT 7290.3 FT CCL DEPTH AND SHOOT. WHP BEFORE SHOT WAS 1000 PSI. GOOD INDICATIONS OF FIRING. AFTER SHOOTING, WHP STILL AT 1000 PSI. POOH. ON SURFACE. ALL SHOTS FIRED. RIG DOWN SPENT GUN AND MAKE UP 3-3/8" GUN LOAD 20 FT OF 6 SPF 3406 PJ HMX 60 DEG PHASE GUN. CCL TO TOP SHOT IS 7.8 FT. REQUIRED PERF INTERVAL IS 7278 - 7298 FT. RIH. LOG INTO POSITION AND STOP WITH CCL AT 7270.2 FT. WHP BEFORE SHOT = 1000 PSI. SHOT GUNS. GOOD INDICATIONS OF FIRING. POOH. ON SURFACE. WHP = 1000 PSI. ALL SHOTS SPENT. RDMO. ADDED PERFS AT 7278 - 7308 FT AND 7314 - 7326 FT. ALL SHOTS FIRED SUCCESSFULLY. Schlumberuer S-123 Survey Report Survey / DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 107.340° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 60.45 ft relative to MSL Sea Bed / Ground Level Elevation: 34.30 ft relative to MSL Magnetic Declination: 24.923° Total Field Strength: 57602.861 nT Magnetic Dip: 80.842° Declination Date: September 15, 2004 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North .> True North: +24.923° Local Coordinates Referenced To: Well Head Report Date: 19-5ep-04 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure/Slot: S-PAD/8-123 Well: 8-123 Borehole: 8-123 UWIIAPI#: 500292321900 Survey Name / Date: S-123/ September 19, 2004 Tort / AHD / DDI/ ERD ratio: 94.507° /2358.63 ft /5.383/0.340 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70.35359100, W 149.02958239 Location Grid N/E YIX; N 5979855.200 ftUS, E 619504.240 ftUS Grid Convergence Angle: -+D.9139350r Grid Scale Factor: 0.99991622 . Comments Latitude Longitude RTE N 70.35359100 W 149.02958239 Inc Trend N 70.35359300 W 149.02957881 First MWD+IFR+MS N 70.35359300 W 149.02957537 N 70.35358991 W 149.02956723 N 70.35358616 W 149.02955620 464.98 1.36 144.21 404.47 464.92 5.37 6.91 5.67 -3.34 4.58 0.28 5979851.94 619508.87 N 70.35358188 W 149.02954520 555.23 1.36 139.76 494.69 555.14 7.13 9.05 7.75 -5.02 5.90 0.12 5979850.27 619510.22 N 70.35357727 W 149.02953449 646.06 1.31 140.72 585.50 645.95 8.91 11.17 9.84 -6.65 7.25 0.06 5979848.67 619511.60 N 70.35357283 W 149.02952350 736.04 1.31 138.50 675.45 735.90 10.64 13.23 11.88 -8.22 8.59 0.06 5979847.12 619512.95 N 70.35356855 W 149.02951268 829.84 1.29 137.39 769.23 829.68 12.48 15.35 14.01 -9.80 10.01 0.03 5979845.56 619514.40 N 70.35356423 W 149.02950111 921.74 1.30 136.86 861.11 921.56 14.28 17.43 16.08 -11.32 11.42 0.02 5979844.07 619515.84 N 70.35356007 W 149.02. 1016.52 1.37 137.42 955.86 1016.31 16.19 19.64 18.29 -12.94 12.93 0.08 5979842.47 619517.37 N 70.35355565 W 149.029 1110.26 1.32 133.83 1049.57 1110.02 18.13 21.84 20.49 -14.51 14.46 0.10 5979840.92 619518.93 N 70.35355135 W 149.02946496 1205.31 3.52 164.50 1144.54 1204.99 20.69 25.77 24.17 -18.08 16.03 2.61 5979837.38 619520.56 N 70.35354160 W 149.02945222 1299.81 4.92 162.93 1238.78 1299.23 24.56 32.73 30.60 -24.75 18.00 1.49 5979830.74 619522.63 N 70.35352338 W 149.02943626 1393.77 5.01 162.30 1332.39 1392.84 29.19 40.86 38.40 -32.51 20.43 0.11 5979823.02 619525.18 N 70.35350218 W 149.02941653 1484.92 4.22 175.05 1423.24 1483.69 32.75 48.16 45.30 -39.64 21.93 1.42 5979815.91 619526.79 N 70.35348269 W 149.02940436 1585.00 4.22 177.58 1523.05 1583.50 35.39 55.53 52.06 -46.99 22.40 0.19 5979808.58 619527.38 N 70.35346262 W 149.02940052 1680.14 6.66 176.55 1617.75 1678.20 38.53 64.54 60.49 -56.00 22.88 2.57 5979799.58 619528.01 N 70.35343802 W 149.02939662 1774.93 10.37 171.62 1711.48 1771.93 44.19 78.57 74.08 -69.93 24.45 3.99 5979785.68 619529.80 N 70.35339996 W 149.02938384 1869.40 13.75 167.46 1803.86 1864.31 53.4 7 98.30 93.63 -89.31 28.13 3.69 5979766.36 619533.79 N 70.35334702 W 149.02935398 1963.50 13.00 166.56 1895.40 1955.85 64.46 120.06 115.34 -110.52 33.02 0.83 5979745.23 619539.02 N 70.35328907 W 149.02931429 2058.29 13.59 162.42 1987.66 2048.11 76.29 141.85 137.13 -131.50 38.86 1.18 5979724.34 619545.19 N 70.35323174 W 149.02926686 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-123 \S-123\S-123\S-123 Generated 10/1/20043:50 PM Page 1 of 3 Comments Latitude Longitude N 70.35317593 W 149.02919884 N 70.35312180 W 149.02910951 2336.93 14.69 141.15 2257.91 2318.36 125.04 209.68 203.56 -190.59 71.49 2.13 5979665.79 619578.75 N 70.35307032 W 149.02900196 2432.10 15.44 135.92 2349.82 2410.27 146.20 234.40 226.80 -209.09 87.87 1.63 5979647.56 619595.43 N 70.35301978 W 149.02886894 2524.31 16.29 128.98 2438.52 2498.97 169.00 259.58 249.86 -226.04 106.4 7 2.25 5979630.90 619614.29 N 70.35297346 W 149.02871798 2619.19 18.98 122.30 2528.94 2589.39 196.28 288.29 275.23 -242.66 129.86 3.54 5979614.66 619637.94 N 70.35292806 W 149.02852805 2713.85 22.69 115.44 2617.41 2677.86 229.25 321.91 303.89 -258.74 159.37 4.68 5979599.06 619667.71 N 70.35288414 W 149.02828844 2807.97 27.31 108.60 2702.71 2763.16 268.83 361.64 336.58 -273.44 196.26 5.78 5979584.95 619704.82 N 70.35284399 W 149.02798898 2865.04 27.92 107.54 2753.28 2813.73 295.28 388.10 358.25 -281.64 221.41 1.37 5979577.15 619730.09 N 70.35282158 W 149.02778480 3011.96 29.61 109.50 2882.06 2942.51 365.96 458.79 419.14 -304.12 288.43 1.32 5979555.74 619797.45 N 70.35276015 W 149.02724069 3108.74 33.62 107.94 2964.47 3024.92 416.66 509.51 464.59 -320.36 336.4 7 4.23 5979540.27 619845.75 N 70.35271577 W 149.026. 3201.65 35.81 105.11 3040.84 3101.29 469.55 562.41 512.25 -335.37 387.19 2.93 5979526.07 619896.70 N 70.35267476 W 149.026 3297.71 37.36 103.21 3117.97 3178.42 526.71 619.66 563.95 -349.36 442.70 2.00 5979512.97 619952.42 N 70.35263654 W 149.02598813 3390.57 38.42 101.13 3191.26 3251.71 583.50 676.68 615.66 -361.37 498.45 1.79 5979501.86 620008.35 N 70.35260372 W 149.02553557 3485.18 38.16 100.08 3265.52 3325.97 641.72 735.31 669.12 -372.16 556.07 0.74 5979491.99 620066.13 N 70.35257423 W 149.02506776 3579.09 37.78 99.61 3339.55 3400.00 699.00 793.08 722.30 -382.04 613.00 0.51 5979483.02 620123.20 N 70.35254723 W 149.02460559 3674.28 37.09 99.31 3415.13 3475.58 756.32 850.95 776.08 -391.55 670.07 0.75 5979474.42 620180.41 N 70.35252123 W 149.02414222 3770.67 36.70 98.78 3492.22 3552.67 813.58 908.81 830.28 -400.65 727.22 0.52 5979466.23 620237.69 N 70.35249636 W 149.02367826 3864.58 35.89 98.67 3567.91 3628.36 868.54 964.40 882.68 -409.08 782.16 0.87 5979458.68 620292.76 N 70.35247331 W 149.02323217 3958.92 35.17 98.65 3644.68 3705.13 922.74 1019.22 934.70 -417.34 836.36 0.76 5979451.29 620347.08 N 70.35245074 W 149.02279216 4054.01 34.36 98.24 3722.80 3783.25 976.30 1073.45 986.39 -425.30 889.99 0.89 5979444.18 620400.83 N 70.35242896 W 149.02235673 4148.57 35.15 100.40 3800.49 3860.94 1029.68 1127.35 1038.26 -434.04 943.18 1.55 5979436.29 620454.14 N 70.35240507 W 149.02192495 4242.04 34.92 100.61 3877.02 3937.47 1082.95 1181.01 1090.35 -443.82 995.94 0.28 5979427.35 620507.04 N 70.35237833 W 149.02149662 4335.08 34.11 100.90 3953.69 4014.14 1135.32 1233.72 1141.73 -453.66 1047.73 0.89 5979418.35 620558.98 N 70.35235144 W 149.02107614 4429.93 34.74 101.10 4031.93 4092.38 1188.62 1287.34 1194.15 -463.89 1100.37 0.67 5979408.96 620611.77 N 70.35232346 W 149.02064882 4522.42 34.17 101.44 4108.19 4168.64 1240.65 1339.67 1245.46 -474.12 1151.68 0.65 5979399.55 620663.24 N 70.35229551 W 149.02023220 4617.65 33.60 101.30 4187.25 4247.70 1293.45 1392.76 1297.61 -484.59 1203.73 0.60 5979389.92 620715.45 N 70.35226689 W 149.01980962 4711.86 32.59 101.11 4266.17 4326.62 1344.60 1444.21 1348.19 -494.58 1254.19 1.08 5979380.73 620766.06 N 70.35223956 W 149.01_ 4805.42 32.22 100.79 4345.16 4405.61 1394.43 1494.34 1397.51 -504.11 1303.42 0.44 5979371.99 620815.42 N 70.35221351 W 149.01 4899.18 31.34 100.48 4424.86 4485.31 1443.47 1543.72 1446.09 -513.22 1351.95 0.95 5979363.65 620864.09 N 70.35218859 W 149.018 4 4994.12 31.56 100.92 4505.86 4566.31 1492.67 1593.26 1494.88 -522.42 1400.62 0.33 5979355.23 620912.90 N 70.35216344 W 149.01821119 5087.96 30.95 100.96 4586.08 4646.53 1541.06 1641.95 1542.92 -531.66 1448.43 0.65 5979346.76 620960.84 N 70.35213817 W 149.01782310 5182.49 30.38 100.16 4667.39 4727.84 1588.93 1690.16 1590.48 -540.50 1495.82 0.74 5979338.67 621008.36 N 70.35211400 W 149.01743834 5276.50 31.25 1 00.40 4748.13 4808.58 1636.72 1738.32 1637.98 -549.09 1543.21 0.93 5979330.84 621055.87 N 70.35209049 W 149.01705366 5370.61 30.26 98.24 4829.00 4889.45 1684.37 1786.44 1685.35 -556.90 1590.69 1.58 5979323.79 621103.47 N 70.35206914 W 149.01666820 5465.12 28.35 97.32 4911.41 4971.86 1729.99 1832.69 1730.70 -563.17 1636.51 2.08 5979318.25 621149.39 N 70.35205198 W 149.01629615 5557.75 26.86 97.53 4993.50 5053.95 1772.27 1875.61 1772.78 -568.72 1679.08 1.61 5979313.39 621192.03 N 70.35203681 W 149.01595062 5652.13 27.14 97.36 5077.59 5138.04 1814.48 1918.46 1814.82 -574.27 1721.56 0.31 5979308.51 621234.59 N 70.35202161 W 149.01560570 5746.65 25.59 97.79 5162.28 5222.73 1855.84 1960.43 1856.05 -579.80 1763.17 1.65 5979303.65 621276.28 N 70.35200648 W 149.01526792 5837.06 23.73 100.53 5244.44 5304.89 1893.16 1998.15 1893.30 -585.77 1800.40 2.41 5979298.27 621313.60 N 70.35199014 W 149.01496563 5931.10 21.32 101.49 5331.30 5391.75 1928.96 2034.17 1929.05 -592.63 1835.77 2.59 5979291.97 621349.07 N 70.35197137 W 149.01467856 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) 8-123 \S-123\8-123\8-123 Generated 10/1/20043:50 PM Page 2 of 3 Comments Latitude Longitude . N 70.35195478 W 149.01443120 6120.20 14.33 103.16 5511.58 5572.03 1985.35 2090.84 1985.39 -604.01 1891.28 2.97 5979281.49 621404.75 N 70.35194025 W 149.01422788 6214.80 12.91 107.66 5603.52 5663.97 2007.59 2113.11 2007.63 -609.88 1912.75 1.87 5979275.96 621426.31 N 70.35192420 W 149.01405358 6309.19 12.63 107.36 5695.58 5756.03 2028.46 2133.97 2028.49 -616.16 1932.65 0.30 5979270.00 621446.30 N 70.35190703 W 149.01389205 6405.75 12.20 107.06 5789.88 5850.33 2049.22 2154.73 2049.25 -622.30 1952.48 0.45 5979264.17 621466.23 N 70.35189024 W 149.01373108 6498.10 12.04 106.30 5880.17 5940.62 2068.60 2174.12 2068.64 -627.87 1971.05 0.24 5979258.90 621484.89 N 70.35187502 W 149.01358030 6590.55 11.84 106.86 5970.62 6031.07 2087.73 2193.25 2087.76 -633.32 1989.38 0.25 5979253.74 621503.30 N 70.35186009 W 149.01343149 6684.72 11.57 106.68 6062.83 6123.28 2106.83 2212.35 2106.86 -638.84 2007.68 0.29 5979248.52 621521.68 N 70.35184502 W 149.01328300 6775.39 11.40 105.75 6151.69 6212.14 2124.88 2230.40 2124.91 -643.88 2025.01 0.28 5979243.76 621539.09 N 70.35183123 W 149.01314228 6867.28 11.01 105.28 6241.83 6302.28 2142.73 2248.26 2142.75 -648.66 2042.21 0.44 5979239.25 621556.37 N 70.35181817 W 149.01300261 6962.37 10.59 104.70 6335.23 6395.68 2160.53 2266.08 2160.55 -653.27 2059.43 0.46 5979234.92 621573.65 N 70.35180556 W 149.01286289 7056.36 10.60 103.13 6427.62 6488.07 2177.78 2283.36 2177.80 -657.42 2076.20 0.31 5979231.03 621590.48 N 70.35179420 W 149.012. 7148.84 10.38 101.46 6518.55 6579.00 2194.55 2300.19 2194.56 -661.01 2092.65 0.41 5979227.71 621606.98 N 70.35178438 W 149.01259320 7242.44 10.06 100.37 6610.67 6671.12 2211.05 2316.80 2211.06 -664.16 2108.95 0.40 5979224.82 621623.34 N 70.35177577 W 149.01246083 7337.54 9.35 101.46 6704.41 6764.86 2226.98 2332.83 2226.99 -667.19 2124.69 0.77 5979222.04 621639.12 N 70.35176748 W 149.01233304 Last MWD+IFR+MS 7428.33 8.90 102.95 6794.05 6854.50 2241.32 2347.23 2241.32 -670.23 2138.77 0.56 5979219.23 621653.24 N 70.35175917 W 149.01221880 TD ( Projected) 7502.00 8.90 102.95 6866.83 6927.28 2252.69 2358.63 2252.69 -672.78 2149.88 0.00 5979216.85 621664.39 N 70.35175218 W 149.01212862 Survey Type: Definitive Survey MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) Leaal DescriDtion: Northina lYI rftUSl Eastina IX) rftUSl Surface : 3642 FSL 3938 FEL S35 T12N R12E UM 5979855.20 619504.24 BHL: 2969 FSL 1789 FEL S35 T12N R12E UM 5979216.85 621664.39 . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-123 \S-123\S-123\S-123 Generated 10/1/2004 3:50 PM Page 3 of 3 TREE = . WELLI-I¡:AD = ACTUA TOR = KB. ELEV = BF ELEV = KOP= 1300' Max Angle = 38 @ 3391' Datum MD = 7338' -14-1/2" HES X NIP, ID = 3.813" I I I 2212' Datum lV D = 6700'SS . 9-5/8" CSG, 40#, K-55, ID = 8.835" 2926' µ ~ Minimum ID = 3.725" @ 7113' 4-1/2" HES XN NIPPLE GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 2 4101 3822 35 KBG-2 SO BK 24 12/04/04 LJ 1 6933 6367 11 KBG-2 DMY BK 0 12/04/04 ÆRFORA TION SUMMARY REF LOG: PEX ON 09/20104 ANGLEATTOP ÆRF: 10 @ 7278' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 7278 - 7308 0 01/23/05 3-3/8" 6 7314 - 7326 0 01/23/05 · I I 7002' -14-112" HES X NIP, ID = 3.813" I :8: I.----.. 7064' -17" X 4-1/2" BKR PREMIER PKR, ID - 3.875" .<.::::: · I I 7092' -14-1/2" HES X NIP, ID = 3.813" I · -' 7113' -14-1/2" HES XN NIP, ID = 3.725" I I I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7125' I I 7125' -14-1/2" WLEG I I H ELMD TT NOT LOGGED I 4 1---1 7241' HMARKERJTW/RA TAG I ] ) I PBTD 7385' I 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" I xxx ~ 7471' I 4-1/16" CrN FMC NA 6004' 355' . 5-123 Lerv NOTES: DA TE REV BY COMMENTS 09/29/04 TM NITL ORIGINAL COM PLETION 12/04/04 RWLITLP GL V C/O 02/06/05 LDK/TLH ADPERF (01/23/05) DA TE REV BY COMMENTS AURORA UNIT WELL: S-123 PERMIT No: 2041370 API No: 50-029-23219-00 SEe 35, T12N, R12E, 3642' NSL & 3938' WEL BP Exploration (Alaska) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ken '5/'òf {o5' DATE: Wednesday, March 23, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-123 PRUDHOE BAY UN AURO S-123 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: Pol. Suprv,1Þß- 3(ãf./oq- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN AURO S-123 API Well Number: 50-029-23219-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050317141923 Permit Number: 204-137-0 Inspection Date: 3/17/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I S-123 Type Inj.! S TVD I 6496 ! IA I 420 i 3000 I 2920 ! 2900 I I ! P.T. I 2041370 TypeTest I SPT I Test psi I 1624 ! OA ! 300 ! 600 1 600 i 600 I I Interval INITAL P/F P Tubing! 1980 I 1980 i 1980 I 1980 I J Notes: Pre test pressures were observed and found stable. Well demonstrated good mechanical integrity. Wednesday, March 23, 2005 Page 1 of I e (DJ~ !Æ~L~~æ!Æ · ¿:i(rf<. ~fil·~, / FRANK H. MURKOWSKI, GOVERNOR / I 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI,ASIiA. ORAND GAS CONSERVATION COMMISSION Jim Young Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-123 Sundry Number: 305-043 Dear Mr. Young: 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 h liday or weekend. A person may not appeal a Commission decision to Superior unless rehearing has been requested. DATED this ~ay of February, 2005 Encl. e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Stratigraphic D Service Œ] 9. Well Name and Numb~: S-123 /' 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 7385 6751.3 Size MD TVD .... . 1. Type of Request 0 0 Abandon Suspend Alter Casing 0 Repair Well 0 Change Approved Program 0 Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 60.45 KB 8. Property Designation: ADL-Q28257 11. Presenl Total Depth MD (ft): 7502 Casing Total Depth TVD (ft): 6927.3 Conductor Production 80 7446 2897 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# K-55 Perforation Depth TVD (ft): 6706 - 6735.7 6742 - 6753.5 Surface Perforation Depth MD (ft): 7278 - 7308 7314 - 7326 Packers and SSSV Type: 4-1/2" Baker Premier Packer 12. Attachments: Description Summary of Proposal [!J Detailed Operations ProQram 0 BOP Sketch 0 14. Estimated Date for Commencin 0 eration: February 25, 2005 thJGÆ ~ /21-/2LOS IX! S 2-/ 2¿j S -. í.. Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD //. Waiver 0 StimulateŒ] Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 204-1370 ~ Other 0 Development D Exploratory D 6. API Number 50-029-23219-00-00 Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom 28 108 28.0 108.0 1490 470 25 7471 25.0 6896.7 3950 2570 27 2924 27.0 2865.7 7240 5410 Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2 " 12.6 # L-80 23 7125 Packers and SSSV MD (ft): 7064 13. Well Class after proposed work: Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD ./ Service ŒI Abandoned 0 GINJD WINJŒI .WDSPLD Prepared by Garry Catron 564-4657. Jim Young 16. Verbal Approval: Date: WAG D Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Title Phone Petroleum Engineer 564-5754 2/15/05 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness BOP TestD Other: Approv Form 10-403 Revised 11/2004 Mechanciallntegrity Test D Location Clearance D BY ORDER OF THE COMMISSION Date: RBDMS 8Ft MAR 0 1 2005 jL\ SUBMIT IN DUPLICATE .. bp ... ,\It.'II, -....~ ~ ~..,- ..~ ·'1'·1 " e e To: G ANC WELLWORK Date: February 14, 2005 From: Jim Young S-PAD Engineer Subject: S-123i HPBD (Kuparuk C Sands) AFE: AUD5M0081 Est. Cost: $100M lOR: 300 Priority: New Well Put On Injection A High Pressure Break Down using rock salt is proposed for S-123i to enhance injectivity and ...... ensure ensure operability of frac equipment prior to the S-119 frac. S-123 is currently SI awaiting WBL step#1 (DGLVs). Please call Jim Young (W:564-57543, H:248-0133, Cell 440-8007) with any questions. 2. 0 3. 0 Liquid pack/freeze protect IA. MITIA to 4000 psig. Treesaver, Pump HPBD/F, POI at max pressure. Wellbore Fluids: Perfs: BHT & BHP: Produced crude in tubing and gas-lift in IA. 7278-7308',7314-7326' (42', 6spf, 0.45" EHD). 145°F & 3000 psia @ 6700' TVDSS cc: w/a: Well File Steve Deckert ec: G Anc Wellwork TREE:; . WELLHEAD = CTUA TOil = KB. ELEV = BF ELEV 4-1/16" Cr-N FMC NA 60.4' 355' e 8-123 I S.NOTES: = KOP= 1300' Max Angle - 38 @ 3391' Datum MD = 7338' 1-14-1/2" HES X NIP, ID = 3.813" I Datum lVD = 6700' SS I · 2212' 9-5/8" CSG, 40#, K-55, ID = 8.835" 2926' 1-4 ~ Minimum ID = 3.725" @ 7113' 4-1/2" HES XN NIPPLE GAS LIFT MANDRElS ST MO lVO DEV 1YÆ VLV LATCH PORT DATE 2 4101 3822 35 KBG-2 SO BK 24 12/04/04 L.J 1 6933 6367 11 KBG-2 DMY BK 0 12/04/04 ÆRFORA TION SUMMARY REF LOG: ÆX ON 09/20/04 ANGLEATTOPÆRF: 10 @ 7278' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3- 3/8" 6 7278 - 7308 0 01/23/05 3-318" 6 7314 - 7326 0 01/23/05 I I 7002' 1-14-1/2" HES X NIP, ID = 3.813" I ß ~ 7064' 1-17" X 4-1/2" BKR PREMIER PKR, ID = 3.875" I · 7092' -14-1/2" HES X NIP, ID = 3.813" I I · 7113' 1-14-1/2" HES XN NIP, ID = 3.725" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7125' 7125' 1-14-1/2" WLEG I 1 H ELMD TT NOT LOGGED I ~~ 7241' HMARKERJTw/RA TAG I I ] I PBTD 7385' 17" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" I 7471' DA TE REV BY COMMENTS 09/29/04 TMN/TL ORIGINAL COMPLETION 12/04/04 RWLITLP GLV C/O 02/06/05 LDKlTLH ADÆRF (01/23/05) DA TE REV BY COMMENTS AURORA UNIT WELL: S-123 ÆRMIT No: 2041370 API No: 50-029-23219-00 SEC 35, T12N, R12E, 3642' NSL & 3938' WEL BP Exploration (Alaska) SCHLUMBERGER Survey report Client...... ..... ... .....: BP Exploration Alaska Inc. Field. . . . . . . . . . . . . . . . . . . .: Aurora Well.....................: S-123 API number. ..... .... .....: 50-029-23219-00 Engineer........ ..... ....: S. Moy RIG:....... ..... .........: DOYON 16 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...... .....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum. .... .....: MEAN SEA LEVEL Depth reference..... .....: Driller's Depth GL above permanent.. .....: 34.30 ft KB above permanent... ....: N/A Top Drive DF above permanent... ....: 60.45 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 107.34 degrees [(c)2004 IDEAL ID8 1C_02J Spud date. . . . . . . . . . . . . . . . : Last survey date.... .....: Total accepted surveys...: MD of first survey.......: MD of last survey........: 12-Sep-04 19-5ep-04 81 0.00 ft 7502.00 ft ----- Geomagnetic data ---------------------- Magnetic model.... .......: BGGM version 2003 Magnetic date...... ......: 15-Sep-2004 Magnetic field strength..: 1151.79 HCNT Magnetic dec (+E/W-).....: 24.97 degrees Magnetic dip.............: 80.87 degrees ----- MWD survey Reference Reference G..............: Reference H......... .....: Reference Dip...... ......: Tolerance of G...........: Tolerance of H..... ......: Tolerance of Dip... ......: Criteria --------- 1002.68 mGal 1151.79 HCNT 80.87 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 24.97 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.97 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction . . ;}tJ0¡-{)l SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 170.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 138.11 0.71 30.97 138.11 138.11 0.20 0.73 0.44 0.86 30.97 0.51 INC+TREND None 3 194.11 0.79 140.54 56.00 194.10 0.61 0.73 0.86 1.13 49.69 2.19 MWD IFR MS None - 4 283.89 1.14 136.98 89.78 283.87 1. 90 -0.40 1. 87 1. 91 102.02 0.40 MWD IFR MS None - 5 375.04 1. 29 133.81 91.15 375.00 3.61 -1.77 3.23 3.68 118.76 0.18 MWD IFR MS None 6 464.98 1. 36 144.21 89.94 464.92 5.37 -3.34 4.58 5.67 126.08 0.28 MWD IFR MS None . - 7 555.23 1. 36 139.76 90.25 555.14 7.13 -5.02 5.90 7.75 130.42 0.12 MWD IFR MS None - 8 646.06 1. 31 140.72 90.83 645.95 8.91 -6.65 7.25 9.84 132.52 0.06 MWD IFR MS None - 9 736.04 1. 31 138.50 89.98 735.90 10.64 -8.22 8.59 11. 88 133.74 0.06 MWD IFR MS None - 10 829.84 1. 29 137.39 93.80 829.68 12.48 -9.80 10.01 14.01 134.38 0.03 MWD IFR MS None 11 921.74 1. 30 136.86 91.90 921. 56 14.28 -11.32 11. 42 16.08 134.74 0.02 MWD IFR MS None - 12 1016.52 1. 37 137.42 94.78 1016.31 16.19 -12.94 12.93 18.29 135.03 0.08 MWD IFR MS None - 13 1110.26 1. 32 133.83 93.74 1110.02 18.13 -14.51 14.46 20.49 135.09 0.10 MWD IFR MS None - 14 1205.31 3.52 164.50 95.05 1204.99 20.69 -18.08 16.03 24.17 138.44 2.61 MWD IFR MS None - 15 1299.81 4.92 162.93 94.50 1299.23 24.56 -24.75 18.00 30.60 143.98 1.49 MWD IFR MS None 16 1393.77 5.01 162.30 93.96 1392.83 29.19 -32.51 20.43 38.40 147.86 0.11 MWD IFR MS None - 17 1484.92 4.22 175.05 91. 15 1483.69 32.75 -39.64 21.93 45.30 151.05 1.42 MWD IFR MS None - 18 1585.00 4.22 177.58 100.08 1583.50 35.39 -46.99 22.40 52.06 154.51 0.19 MWD IFR MS None - 19 1680.14 6.66 176.55 95.14 1678.20 38.53 -56.00 22.88 60.49 157.78 2.57 MWD IFR MS None 20 1774.93 10.37 171. 62 94.79 1771.93 44.19 -69.93 24.45 74.08 160.72 3.99 MWD IFR MS None 21 1869.40 13.75 167.46 94.47 1864.31 53.47 -89.31 28.13 93.63 162.51 3.69 MWD IFR MS None . - 22 1963.50 13.00 166.56 94.10 1955.85 64.46 -110.52 33.02 115.34 163.36 0.83 MWD IFR MS None - 23 2058.29 13.59 162.42 94.79 2048.11 76.29 -131.50 38.86 137.13 163.54 1.18 MWD IFR MS None - 24 2150.99 14.06 153.14 92.70 2138.13 90.38 -151.93 47.24 159.11 162.73 2.44 MWD IFR MS None - 25 2244.15 14.12 148.78 93.16 2228.49 106.78 -171.75 58.24 181.35 161. 27 1.14 MWD IFR MS None 26 2336.93 14.69 141. 15 92.78 2318.36 125.04 -190.59 71. 49 203.56 159.44 2.13 MWD IFR MS None - 27 2432.10 15.44 135.92 95.17 2410.26 146.20 -209.09 87.87 226.80 157.20 1. 63 MWD IFR MS None - 28 2524.31 16.29 128.98 92.21 2498.97 169.00 -226.04 106.47 249.86 154.78 2.25 MWD IFR MS None 29 2619.19 18.98 122.30 94.88 2589.39 196.28 -242.66 129.86 275.23 151.85 3.54 MWD IFR MS None - 30 2713.85 22.69 115.44 94.66 2677.86 229.25 -258.74 159.37 303.89 148.37 4.68 MWD IFR MS None [(c)2004 IDEAL ID8 lC_02] SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2807.97 27.31 108.60 94.12 2763.16 268.83 -273.44 196.26 336.58 144.33 5.78 MWD IFR MS None - 32 2865.04 27.92 107.54 57.07 2813.73 295.28 -281.64 221.41 358.25 141.83 1. 37 MWD IFR MS None - 33 3011.96 29.61 109.50 146.92 2942.51 365.96 -304.12 288.43 419.14 136.52 1. 32 MWD IFR MS None - 34 3108.74 33.62 107.94 96.78 3024.91 416.66 -320.36 336.47 464.59 133.60 4.23 MWD IFR MS None - 35 3201.65 35.81 105.11 92.91 3101.29 469.55 -335.37 387.19 512.25 130.90 2.93 MWD IFR MS None 36 3297.71 37.36 103.21 96.06 3178.42 526.71 -349.36 442.70 563.95 128.28 2.00 MWD IFR MS None . - 37 3390.57 38.42 101.13 92.86 3251.71 583.50 -361.37 498.45 615.66 125.94 1. 79 MWD IFR MS None - 38 3485.18 38.16 100.08 94.61 3325.97 641. 72 -372.16 556.07 669.12 123.79 0.74 MWD IFR MS None - 39 3579.09 37.78 99.61 93.91 3400.00 699.00 -382.04 613.00 722.30 121.93 0.51 MWD IFR MS None - 40 3674.28 37.09 99.31 95.19 3475.58 756.32 -391.55 670.07 776.08 120.30 0.75 MWD IFR MS None 41 3770.67 36.70 98.78 96.39 3552.67 813.58 -400.65 727.22 830.28 118.85 0.52 MWD IFR MS None - 42 3864.58 35.89 98.67 93.91 3628.36 868.54 -409.08 782.16 882.68 117.61 0.87 MWD IFR MS None 43 3958.92 35.17 98.65 94.34 3705.13 922.74 -417.34 836.36 934.70 116.52 0.76 MWD IFR MS None - 44 4054.01 34.36 98.24 95.09 3783.25 976.30 -425.30 889.99 986.39 115.54 0.89 MWD IFR MS None - 45 4148.57 35.15 100.40 94.56 3860.94 1029.68 -434.04 943.18 1038.26 114.71 1. 55 MWD IFR MS None 46 4242.04 34.92 100.61 93.47 3937.47 1082.95 -443.82 995.94 1090.35 114.02 0.28 MWD IFR MS None - 47 4335.08 34.11 100.90 93.04 4014 .14 1135.32 -453.66 1047.73 1141.73 113.41 0.89 MWD IFR MS None - 48 4429.93 34.74 101.10 94.85 4092.37 1188.62 -463.89 1100.37 1194.15 112.86 0.67 MWD IFR MS None - 49 4522.42 34.17 101. 44 92.49 4168.64 1240.65 -474.12 1151.68 1245.46 112.38 0.65 MWD IFR MS None - 50 4617.65 33.60 101.30 95.23 4247.69 1293.45 -484.59 1203.73 1297.61 111.93 0.60 MWD IFR MS None 51 4711.86 32.59 101. 11 94.21 4326.62 1344.60 -494.58 1254.19 1348.19 111.52 1. 08 MWD IFR MS None . - 52 4805.42 32.22 100.79 93.56 4405.61 1394.43 -504.11 1303.42 1397.51 111. 14 0.44 MWD IFR MS None - 53 4899.18 31.34 100.48 93.76 4485.31 1443.47 -513.22 1351.95 1446.09 110.79 0.95 MWD IFR MS None - 54 4994.12 31.56 100.92 94.94 4566.31 1492.67 -522.42 1400.62 1494.88 110.46 0.33 MWD IFR MS None - 55 5087.96 30.95 100.96 93.84 4646.53 1541. 06 -531.66 1448.43 1542.92 110.16 0.65 MWD IFR MS None 56 5182.49 30.38 100.16 94.53 4727.84 1588.93 -540.50 1495.82 1590.48 109.87 0.74 MWD IFR MS None - 57 5276.50 31.25 100.40 94.01 4808.57 1636.72 -549.09 1543.21 1637.98 109.59 0.93 MWD IFR MS None - 58 5370.61 30.26 98.24 94.11 4889.45 1684.37 -556.90 1590.69 1685.35 109.30 1. 58 MWD IFR MS None - 59 5465.12 28.35 97.32 94.51 4971. 86 1729.99 -563.17 1636.51 1730.70 108.99 2.08 MWD IFR MS None - 60 5557.75 26.86 97.53 92.63 5053.95 1772.27 -568.72 1679.08 1772.78 108.71 1. 61 MWD IFR MS None [(c)2004 IDEAL ID8 1C_02] SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +NjS- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5652.13 27.14 97.36 94.38 5138.04 1814.48 -574.27 1721.56 1814.82 108.45 0.31 MWD IFR MS None - 62 5746.65 25.59 97.79 94.52 5222.73 1855.84 -579.80 1763.17 1856.05 108.20 1. 65 MWD IFR MS None - 63 5837.06 23.73 100.53 90.41 5304.89 1893.16 -585.77 1800.40 1893.30 108.02 2.41 MWD IFR MS None 64 5931.10 21. 32 101.49 94.04 5391.75 1928.96 -592.63 1835.77 1929.05 107.89 2.59 MWD IFR MS None - 65 6025.59 17.08 100.97 94.49 5480.96 1959.86 -598.70 1866.24 1959.92 107.79 4.49 MWD IFR MS None 66 6120.20 14.33 103.16 94.61 5572.03 1985.35 -604.01 1891.28 1985.39 107.71 2.97 MWD IFR MS None . - 67 6214.80 12.91 107.66 94.60 5663.97 2007.59 -609.88 1912.75 2007.63 107.68 1. 87 MWD IFR MS None - 68 6309.19 12.63 107.36 94.39 5756.03 2028.46 -616.16 1932.65 2028.49 107.68 0.30 MWD IFR MS None - 69 6405.75 12.20 107.06 96.56 5850.33 2049.22 -622.30 1952.48 2049.25 107.68 0.45 MWD IFR MS None - 70 6498.10 12.04 106.30 92.35 5940.62 2068.60 -627.87 1971.05 2068.64 107.67 0.24 MWD IFR MS None - 71 6590.55 11.84 106.86 92.45 6031.07 2087.73 -633.32 1989.38 2087.76 107.66 0.25 MWD IFR MS None - - 72 6684.72 11.57 106.68 94.17 6123.28 2106.83 -638.84 2007.68 2106.86 107.65 0.29 MWD IFR MS None - - 73 6775.39 11.40 105.75 90.67 6212.14 2124.88 -643.88 2025.01 2124.91 107.64 0.28 MWD IFR MS None - 74 6867.28 11.01 105.28 91.89 6302.27 2142.73 -648.66 2042.21 2142.75 107.62 0.44 MWD IFR MS None - 75 6962.37 10.59 104.70 95.09 6395.68 2160.53 -653.27 2059.43 2160.55 107.60 0.46 MWD IFR MS None - 76 7056.36 10.60 103.13 93.99 6488.07 2177.78 -657.42 2076.20 2177.80 107.57 0.31 MWD IFR MS None - 77 7148.84 10.38 101.46 92.48 6579.00 2194.55 -661. 01 2092.65 2194.56 107.53 0.41 MWD IFR MS None - 78 7242.44 10.06 100.37 93.60 6671.12 2211.05 -664.16 2108.95 2211.06 107.48 0.40 MWD IFR MS None - 79 7337.54 9.35 101.46 95.10 6764.86 2226.98 -667.19 2124.69 2226.99 107.43 0.77 MWD IFR MS None 80 7428.33 8.90 102.95 90.79 6854.50 2241.32 -670.23 2138.77 2241.32 107.40 0.56 MWD IFR MS None 81 7502.00 8.90 102.95 73.67 6927.28 2252.69 -672.78 2149.88 2252.69 107.38 0.00 Projection to T. [(c)2004 IDEAL ID8 1C 02] - - . . Schlumberger Drilling & Measurements MWD/LWD Log Product Deliverv Customer BP Exploration (Alaskallnc. Dispatched To: Helen Warman Well No $-123 Date Dispatched: 2-$ep-04 Installation/Rig Doyon 16 Dispatched By: J.Bosse Data No Of Prints No of Floppies Surveys 2 1 J ~i¡w~l o UA-fJ Please sign and return to: James H. Johnson Received By: BP Exploration (Alaska) Inc. )- (j :t- ÀßtJ i Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com LWD Log Delivery V1.1, 10-02-03 Schlumberger Private ') Gt1 l-(::' ì F,r/J. o . . ::2." 3 - /9'8' ~Otf.;-l~' ., ~i' ..., ;;....0 J- --;7 Æ'> L/ (~c.:./¡ _ 1_37 02111/05 Scblumberger NO. 3335 Schlumberger-DCS 2525 Gambell S~ Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well BL CD Job# Log Description Date Color - S-120 10674426 US IT 4/16/04 1 -123 10900127 USIT 12/22/04 1 - S-116 10674425 USIT 04/15/04 1 _ S-118 10703986 SCMT 04/12/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 :l-þ !o j- , I Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ~/idu-a~ Date Delivered: . . rOI ~ ~!Æ Ü1 c \ Ü FRANK H. MURKOWSKI, GOVERNOR AI1.\SIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-123 BP Exploration (Alaska) Inc. Pennit No: 204-137 Surface Location: 3642' NSL, 3938' WEL, SEe. 35, T12N, R12E (As Staked) Bottomhole Location: 2975' NSL, 1806' WEL, SEC. 35, T12N, R12E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced service well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserv~s the right to withdraw the pennit 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 tenns and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 -3 7 (pager). BY ORDER JlF THE COMMISSION DATED thisjQ day of July, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. ~GÅ 7lz(;/zoc4 . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 aa Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3642' NSL, 3938' WEL, SEC. 35, T12N, R12E (As Staked) Top of Productive Horizon: 2983' NSL, 1843' WEL, SEC. 35, T12N, R12E, UM Total Depth: 2975' NSL, 1806' WEL, SEC. 35, T12N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 619504 y- 5979855 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 1300 feet Maximum Hole Angle: 35 dearees r1b. Current Well Class 0 Exploratory 0 Development Oil 0 Multiple Zone o Stratigraphic Test aa Service / 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: / Bond No. 2S100302630-277 PBU 8-123 6. Proposed Depth: 12. Field I Pool(s): MD 7465 TVD 6901 Prudhoe Bay Field I Aurora Pool 7. Property Designation: ADL 028257 8. Land Use Permit: 13. Approximate Spud Date: / August 15, 2004 14. Distance to Nearest Property: 2950' 9. Acres in Property: 2560 18. Casing Program: Size Casina 20" 9-5/8" Hole 42" 12-1/4" 8-314" Weiaht 91.5# 40# 26# Specificiitiol1s Grade CouplinQ H-40 Weld L-80 BTC L-80 BTC-M LenQth 80' 2914' 7441' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 58.3 feet S-109 is 1625' away 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3000 Surface: 2330 . T41:ett¡"9p~~t~~~ nM ~,'" MD TVD MD TVD lincludina staae data) Surface Surface 110' 110' 260 sx Arctic SetlADDrox.) Surface Surface 2938' 2868' 497 sx AS Lite, 221 sx Class 'G' Surface Surface 7465' 6901' 319 sx Class 'G', 131 sx Class 'G' 7" 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): I M....¡., Size I MD· TVD ';::tflll'tllr<>1 Conductor Surf::lc-P. Intermediate Proouctinn Liner 20. Attachments 181 Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program o Shallow Hazard Analysis 18120 MC 25.050 Requirements Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the f9"egoing is true and correct to the best of my knowledge. Printed Name Lowell9fane... Title Senior Drilling Engineer i.- ...ð // / .. j Prepared By Name/Number: Sianature / "\/'~~/ ,<---c.-1'~ Phone 564-4089 Date 7 -J.t-ÓY _ Terrie Hubble, 564-4628 /., '/...·.···.·.f..i~........;' .··i. .i" './..//!!.;. ......,.... ',····;../"·..·i./·)).;;;,·.;;'.)·..;; .,;...;;;;.;;..'..';;';;.';/ /...' .// Permit To Drill~ I API Number: Permit Approv9'. / See cover letter for Number: 2 ð št - / a 7 50- C>.2 9 - :::2 3 :2 /q Date: 7/ ¿þ / t?~ other requirements Conditions of Approval: Samples Required 0 Yes .JKN6 Mud Log Required 0 Yes ~No . _ HY~ Sulfide M,easures_ 0 Yes ~ No ~i~ectiona.1 Survey Requ!red ~Yes 0 No Other: Test gOp~~ ~?OO pSt, ¡"I/.J- T¡ ut1A"1?4A-f 17 (,{t:J( Ä IDC¡ ;.eát.«~d. 'ì<7~>- . ~~(/..)(¡J) <tlteorh4. Ie BoP! fed ~3".(à~ '5 "-fflro¡ft'J ADDroved\,./--;l'l., ~./ n c 'C ¡, , ,~I ~~~'b"J~'~~'ON Dale 'l;'$ð¡W ,...J/ Form 10-401 ~sed06/~4 V I \ i V I i \I r1 L s{¡bm¡(ln Duplicate Date: Contact Jim Smith, 564-5773 · . I Well Name: 18-123 Drill and Complete Plan Summary I Type of Well (service I producer I injector): Injector (water) Surface Location: X = 619,504.' Y = 5,979,855' As-Built 3642' FSL, 3938' FEL, Sec. 35, T12N, R12E ,/ Target Location: X = 621,610' Y = 5,979,230' Top Kuparuk 2983' FSL, 1843' FEL, Sec. 35, T12N, R12E / 6630'TVDss Bottom Hole Location: X = 621,647' Y = 5,979,223' / 2975'FSL, 1806'FEL,Sec.35, T12N,R12E I AFE Number: I AUD5M0080 I I Estimated Start Date: 18/15/04 / I Rig: I Doyon 16 / I Operating days to complete: 112.9 I I ~ 7465' I TVD: 16901' 1 RT/GL: 124.0 I I RKB/MSL: 158.3' I I Well Design (conventional, slimhole, etc.): I Ultra Slim hole (Iongstring) I Objective: I Single zone injector into the Kuparuk formation Mud Program: 12 "IA" Surface Hole (0-2938'): Fresh Water Surface Hole Mud Densitv Viscosity Yield Point API FL PH (ppg) (seconds) (lb/100ff) (mls/30min) Initial 8.5- 9.2 250-300 45 - 70 NC 9.0- 9.5 Base PF to top SV 9.0 - 9.5 200 35-45 <8 9.0- 9.5 SV to TD 9.5 max 150-200 25 -- 35 <8 9.0- 9.5 8 3,4" Production Hole 2938' -7465'): LSND Interval Density YP PV pH API 10' Gel (ppg) Filtrate Upper 9.5-9.7 25-30 1 0-15 9.0--9.5 6-8 10 Interval /---) Top of HRZ (~ 22-28 1 0-15 9.0-9.5 4-6 10 to TD S-123 Permit application Page 1 . . Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Nozzles TFA GPM Pipe (fpm) ppg-emw (in2) 0-1945' 550 5" 19.5# 10.0 18,18,18,16 .942 1945' -2938' 600 5" 19.5# 10.2 18,18,18,16 .942 Production Hole: 8 %" Interval Pump Drill Pipe AV Pump PSI ECD Nozzles TFA GPM (fpm) ppg-emw (in2) 2938' - 7465' 600 5" 19.5# 10.xx 6x14 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-2938' Surface 150- 80 Up to 9.5 Hole cleaning is most critical near TO of to SV-3 300 600 the section where hole angle is greatest and the mud has been thinned. Sweeps may be needed 2938'-7465' 9-5/8" to 150 100 600 9.9 Sweeps and fully reamed connections TD to maintain minimum hole cleaning requirements. Use extra caution of hole cleaning in the interval from surface casing to about 5000' where hole angle is highest. Hole cleaning potential is qood. Casi ng Criteria: Casing Description 20" insulated conductor 9-5/8" , 40#, L-80, STC 7", 26#, L-80, STCM 5750 7240 3090 5410 S-123 Permit application Page 2 . . Directional: Ver. Anadrill P4 KOP: 1300' Maximum Hole An Ie: Close Approach Wells: 34.9deg at 3226' MD All wells pass major risk criteria. he nearest wells are: 8-06 at 1590'MD on 8-123, 46' away center to center and 8-30 at 1595'MD on the 8-123, 39' away center to center. The two adjacent wells at surface are 8-30 and 8-06. IFR-M8 corrected surve s will be used for surve validation in this well. None liE Iqqos~" so<õA Iq~18r¡.,"/ $12.1\ Ig51~3· . s~7 1?209?¡( S 14 2.0 3 104 .,/ Intermediate/Production Hole Drilling: o en Hole: Drilling: o en Hole: MWD/GR/RE8/DEN/NEU (below permafrost) None Cased Hole: None MWD/GR/PWD PEXlBHCS Cased Hole: USIT Formation Markers: Formation Tops MD TVDss Estimated pore pressure, PPG KOP 1300 1235 SV6 1589 1530 Base Permafrost 1945 1880 SV5 2246 2170 8.6 ppg EMW SV4 2441 2355 8.6 ppg EMW SV3 2826 2710 8.6 ppg EMW 9-5/8" sfc casing 2938 2810 8.6 ppg EMW SV2 2995 2860 8.6 ppg EMW SV1 3427 3220 8.6 ppg EMW UG4A 3902 3610 9.0 ppg EMW expected, **potential to 10.1 ppg UG3 4262 3905 9.0 PPQ EMW --..-- .- UG1 4900 4430 9.0 PPQ EMW Uanu Ma 5193 4680 9.2 ppq EMW Top Schrader NA 5425 4885 8.8 PPQ EMW to 12.0 PPQ (local water injection) Schrader OA 5547 4995 8.8 ppg EMW to 12.0 ppg (local injection) Base OBf 5868 5290 8.8 ppg EMW to 12.0 ppg (localinjection) CM1 (Colville) 6903 6290 THRZ 7025 6410 BHRZ (Kalubik) 7247 6628 Target! Kuparuk C4 7249 6630 9.6 PPQ EMW Kuparuk C3/C2/C1 7264 6645 9.6 ppg EMW LCU Kuparuk B 7284 6665 9.6 ppg EMW Kuparuk A5 7292 6673 9.6 ppg EMW Kaparuk A5 Base 7315 6695 9.6 ppg EMW Miluveach 7355 6735 TD 7465 6843 crs q.q ** The S-200PB1 showed an RFT pressure of 1951psi(10.1 ppg) in an UGNU4A coal seam. This pressure is not expected on the S-123 well. 8-123 Permit application Page 3 . . C IT b- p aSing, u Ing rogram: Hole Csgl WtlFt Gra, cr Length Top Btm Size Tbg O.D. MDfTVD MDfTVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110' 12 '14" 9 5/8" 40# L-80 BTC 2914' GL 2938'/2868' 8%" 7" 26# L-80 BTC-M 7441' GL 7465'/6901 ' Tubing 41;2" 12.6# L-80 TC-II 7026' GL 7050'/6594' I nte rit Test Point Surface Casing Shoe Testin : Depth 20' min from surface shoe Test Type LOT EMW 11.8 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job. Casin Size 9-5/8" Surface at 2938' Basis: Lead: Based on conductor set at 80',1865' of annulus in the permafrost @ 225% excess and 448' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 545' MD(is 500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2393' MD,2310'TVD Total Cement Volume: Lead 393.1 bbl I 2207ft l 97~ks of Arctic Set Lite Permafrost cement at 10.7 '-:ãPet;4.44 cf/sk. 45.5 bbl I 255 ft 1,2·21/:..... sks of 'G' at 15.8 ppg and 1.16 cf/sk. &J Tail Casin Size 7" Production string at 7465' Basis: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' sh;>~::::~), Cement Placement: Tail from shoe at 7465' to 6745' MD, lead from 6745' t~hich is 500' above the UGNU 4A sand Ius 30% excess. Total Cement Volume: Lead 116.4 bbls I 654 ft I 1~-5ks of G filler slurry at 12.8 ppg and 2.05 cf/sk. / Tail 28 bbl 1157 ft 1'131 s of gasBLOK 'G' at 15.8 ppg and 1.2 cf/sk.k 8-123 Permit application Page 4 . . Well Control: / Surface hole will be drilled with a diverter. The production hole well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upop the planned 4500 psi CaSing~.. .. !Stf9r future fracture stimulation treatment, the BOP /' equipment will be tested tc(50gP'Psi. é.:7 Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. A nearby well (S-215) has been injecting water into the Schrader for enhanced recovery. This well has been shut in for about 7 months and any overpressure in the Schrader due to water injection should be dissipated. Expected pressure is in the 8.5 to 9.0 ppg range, maximum pressure while injecting was about 12.0 ppg EMW. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: required for fracture stimulation.) · Planned completion fluid: 3000 psi @ 6700' TVD/- worst case Kuparuk A5 Sands 2330 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) ,;o~Jjd6A- ..' I ~$Si (The casing and tubing will be tested to 4500 psi as (~" ;.,,- 8.6 ppg filtered seawater / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. $-123 Permit application Page 5 . . DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: 1. Install 20" conductor. (Staked 6/22/04) 2. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. Rig Operations: / 1. MIRU Doyon 16 drilling rig / 2. Nipple up diverter. PU 5" DP as required and stand back in derrick. 3. MU 12 14" drilling assembly with MWD/GR to kick off at 1300' and directionally drill surface hole to below the permafrost, make a trip to pick up a new bit and MWD/GR/RES/DEN/NEU then drill to approximately 100' TVD below the SV3 Sands. (Surface interval logs are desired to evaluate the Prince Creek water). 4. Run and cement the 9-5/8",40# surface casing. Cement to su~. ) 5. ND diverter and NU casing 1 tubing head. NU BOPE and test ..50QOPsi. 6. MU 8-3/4" drilling assembly with MWD/GR/PWD and RIH t 'ft6ât collar. Test the 9-5/8" casing to /' 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 9-5/8'/ shoe and perform Leak Off Test. Be prepared for 10.1 ppg mud weight in UG4A should it be needed (this is not expected). Exercise caution as local overpressure may exist from Schrader water injection (well S-215 is shut in more than 7 months, pressure should be fully bled off in the Schrader). 8. Drill to +/-100' above the HRZ, ensure mud is conditioned at 9.9 ppg and perform 10 stand short trip with weight up. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to / entering HRZ. 9. Drill ahead to TD at -150' MD below Kuparuk AS. POOH and rack DP. 10. Condition hole for PEX/BHCS e-Iogging. 11. Run PEX/BHCS, perform a wiper trip and condition hole for running 7" 26# long-string casing after logging. 12. POOH and lay down drillpipe. / 13. Run and cement the 7" production casing in a single stage. (To be reviewed based on log/operational results.) Displace the cement with 8.5 ppg filtered seawater. 14. Freeze protect the 7" x 9-5/8" annulus as required with weighted mud followed by dead crude. Record formation breakdown pressure on the Morning Report. 15. Test casing to 4500 psi for 30 minutes. 16. If the cementing job went well, run tubing, otherwise run the USIT log then run the 4-1/2", 12.6#, L-80 TC-II completion assembly with 2-GLM's. Set packer at ñë>more than 200'MD above the top of / Kuparuk. Test the tubing to 4500 psi and annulus to 4500 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below TWC to 1000 psi. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 19. Rig down and move off. Post-Ria Work: MIRU e-line. Run USIT through 4-1/2" tubing to evaluate cement across and above Kuparuk in the interval from top Kuparuk to the tubing tailpipe. Perforate Kuparuk as required, all under drilling AFE. Perform high pressure breakdown stimulation of the Kuparuk and perform cleanout as required under a separate AFE. USIT logging will be performed post-rig as will perforating. The USIT will need to be run prior to tubing only / if the 7" cementing job goes poorly. 8-123 Permit application Page 6 . . 8-123 Drilling Program Job 1: MIRU Hazards and Contingencies ~ 8-Pad is not designated as an H28 site. Recent well tests indicate near 8ppm H28 concentrations as typical but 8-40 had 70 ppm in Jan. 2000. Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest well locations are: 8-30, 30' to the east; 8-06, 30' to the west. ~ Two wells (8-30 and 8-06, both producers at 30' away on either side) will require removal of the well house and surface shut in during move in and move out. þ> Check the landing ring height on 8-123 prior to rig mobilization. The BOP nipple up program may need review to ensure proper space out, this should be done prior to MIRU. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drillina Surface Hole þ> There are two nearby wells in the surface hole, these wells do pass the JORP8 drilling risk guidelines. Those are the 8-06 and the 8-30 which are still 46' and 39' away respectively in the interval of 1590' to 1595'MD. There will be no gyro surveys required for this well, standard MWD tools are adequate, start the IFR as soon as a good MWD survey is obtained without magnetic interfenence (expect this at about 100'-200'). þ> Gas hydrates have been observed in wells drilled on 8-Pad. These were encountered near the base of permafrost to as deep as the 8V1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation þ> 8-123 is not expected to cross any faults in the surface hole. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" Job 3: Install Surface Casina Hazards and Contingencies þ> It is critical that cement is circulated to surface. Planned cement amount is: 225% excess cement through the permafrost zone and 30% excess below the permafrost. A 9-5/8" port collar will only be placed at ±1 OOO'MD if hole conditions indicate excessive washout. This collar will allow remedial cementing should cement not reach the surface on the primary cementing job. It will be necessary to make a judgment call on whether the hole is washed out more than normal based on time in the interval and cuttings generation. Reference RPs .:. "Casing and Liner Running Procedure" 8-123 Permit application Page 7 . . .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" 9-5/8", 40#, L-80, BTC Collapse Burst Tensile ID Make-up Torque 100% 3090 psi 5750 psi 916,000 Ib 8.835" To Position 80% 2472 psi 4600 psi 732,800 Ib 8.679" drift Note: Check surface cement level prior to leaving well to establish if cement has slumped. Record depth tagged on Morning Report. If TOC is more than 20' below the top of conductor, notify AOGCC and perform top job at an opportune time. Note: In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Review the "Surface Casing and Port Collar RP" Job 7: Drillina Production Hole Hazards and Contingencies ~ S-123 will cross one fault - in the Ugnu at - 4590'TVDss, 5089' MD (+/- 250'). Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERAN ~: In the scenario of 9.6 ppg pore pressure at the Kuparuk target depth, gauge hole, a fractur gra 'ent of 11.8 ppg at the surface casing shoe, 9.9 ppg mud in the hole the kick tolerance i 25. bls. An accurate LOT will be required as well as heightened awareness for kick de Ion. Contact Drilling Manager if LOT is less than 11.8 ppg. ~ Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time nineteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. ~ Caution should be exercised when crossing the Schrader interval. Nearby water injection on the S-215 Schrader well was halted in December, 2004 for other well work on the pad. The well will remain shut in until the S-123i has set 7" casing. Expected pressure is 8.5-9.0 ppg but the pressure during injection was a maximum of 12.0 ppg. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" Job 8: Loa Production Hole Hazards and Contingencies ~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Place a "G-Seal" pill at 1 O#/bbl across SV sands on last trip out prior to logging. The log run will be PEX with sonic. ~ Perform a clean out run prior to running the 7" longstring casing, POOH and LD DP. Reference RPs .:. Follow Schlumberger logging practices and recommendations. S-123 Pêrmit application Page 8 . . Job 9: Case & Cement Production Hole Hazards and Contingencies » The interval is planned to be cemented in a single stage with a 12.8 ppg lead ( to 500'MD above the UGNU MA) and a 15.8 ppg tail (top at 500' above the Kuparuk). If a single stage cement job is deemed too risky while drilling, then a 2 stage cement job may be performed. >- Ensure the upper production cement has reached at least a 70BC thickening value prior to freeze protecting. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. >- Pump approximately Y2 the volume of the casing by casing annulus prior to its freezing. After freeze protecting the 7" x 9-5/8" casing outer annulus with dead crude (estimated at 7.5 ppg) to 2215' MD, 2200'TVD, the hydrostatic pressure will be less than the formation pressure immediately below the shoe. To prevent pressure on the annulus pump 19 bbl of 11.8 ppg mud ahead of the 65 bbl of dead crude, this should balance formation pressure at the shoe. >- Cement is being placed from TD to 500' above the UGNU MA (top at 3902'MD/3668'TVD). Planned TOC is 3402'MD which is less than 500' below the 9-5/8" casing shoe. It may be prudent to insure the 9-5/8" x 7" annulus is clear if there is a delay in cement reaching adequate thickening/compressive strength development. » Ensure a minimum hydrostatic equivalent of 9.9 ppg on the Kuparuk formation during pumping of cement pre-flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. » Instability of the Kalubik has been observed on some previous wells. Stage up pumps carefully to minimize surge on the Kalubik. » Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition, a LCM pill composed of "G Seal" should be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" 7",26#, L-BO, BTC-mod Collapse Burst Tensile ID Make-up Torque 100% 5410 psi 7240 psi 604,000 Ib 6.276" To Position 80% 4328 psi 5792 psi 483,200 Ib 6.151" drift Job 12: Run Completion Hazards and Contingencies » Watch hole fill closely and verify proper safety valves are on the rig floor while running the completion. » When testing annulus maintain no more than a 1500 psi differential: 3000 psi tubing pressure, 4500 psi annulus pressure to avoid premature shear of the DCK valve. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus S-123 Permit application Page 9 . . Job 13: ND/NUlRelease Ria Hazards and Conüngencœs ).> No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus 8-123 Permit application Page 10 . . S-123 Well Summary of Drillinr.) Hazards POST THIS NOTICE IN THE DOGHOUSE Suriace Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1945' MD and near the hole section TD as well. · S-30 and S-25 located on the Southern portion of the pad, reported outer annulus pressures in the past. In December 2002 S-25 was shut in. S-30 is on production however and is being monitored. The pressure does not appear to have charged up any shallow sands in the wells drilled since that time. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · The production section will be drilled with a recommended mud weight of 9.9 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk's 9.5 ppg (maximum) pore pressure. · Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1-10.3 were required to contain the pressure. Several S-Pad wells drilled in 2000 used 10.5 ppg to drill this interval as a precaution. Since that time nineteen wells have been drilled on S Pad without encountering the overpressure. Gas cut mud, mud flow and oil in the returns may indicate that the overpressure is still present at which point the mud should be weighted up. · Maintain caution for potential inflow while drilling the Schrader which could retain some overpressure for water injection. · S-123 will cross a fault at -4590' TVDss, 5089' MD (+/-250') in the Ugnu. Lost circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGENSULHDE-H2S . This drill-site is j!Q1.,designated as an H2S drill site. Recent wells tests indicate 8 ppm H2S concentration in Kuparuk wells. Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 8-123 Permit application Page 11 . . 4-1/16" erN FMC NA 64.7 36.2 1300 35 TREE = W8...LH D = ACTUA TOR = KB. 8...EV = BF. 8...EV = KOP= Max Angle = Datum MD = Datum lVD = S-123i contingent 9-5/8" TAM PORT COLLAR 4-1/2" HES X NIP, ID = 3.813" 1000' 2200' XXX' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" I (;l\S LIFT fv\ð..!\Œ8...S lVD ŒV TYÆ VLV LATCH RJRf 3800' 6975 2 jts above the packer ST MJ 2 1 DA.TE Minimum ID = 3.725" 4·112" HES XN NIPPLE 4-1/2" TBG, 12.6#, L-80, TG-II 7049· H 7" X 4-1/2" BKR Premier PKR within 200' of Kuparuk top 4-112' X riWæ 4-1/2" XN nipple ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE AT TOP ÆRF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE ----- Short marker jt w/RA tag just above top Kuparuk 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 7465' GPB AURORA W8...L: S-123i ÆRMfT No: API No: DA TE REV BY COMMENTS OS/20/04 JES PROPOSED COMPLETION DA TE REV BY COMMENTS BP Exploration (Alaska) 5-123 (P4) Proposal Schlumberger Report Date: July 20. 2004 Survey I DlS Computation Method; Minimum Curvature I Lubinski Client; BP Exploration Alaska Vertical Section Azimuth; 107.340' Field; Prudhoe Bay Unit· WOA Vertical Section Origin; N 0.000 ft. E 0.000 ft Structure I Slot; S-PAD I S-123 1/2 TVD Reference Datum; Rotary Table Well: Plan S-123 TVD Reference Elevation; 58.30 It relative to MSL Borehole; Plan S-123 Sea Bed I Ground level Elevation: 34.30 It relative to MSL UWVAPI#; 50029 Magnetic Declination: 24.984' Survey Name I Date; S-123 (P4) 1 July 20, 2004 Total Field Strength; 57587.796 nT Tort I AHD I DOli ERD ratio: 72.001" 1 2324.72 ft /5.258/ 0.337 Magnetic Dip: 80.865· Grid Coordinate System; NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 05. 2004 location lat/Long; N 70.35359064, W 149.02958208 Magnetic Declination Model; BGGM 2003 . location Grid NIE Y!X: N 5979855.070 ItUS, E 619504.280 ItUS North Reference; True North Grid Convergence Angle; ;{).91393536· Total Corr Mag North·> True North: +24.984· Grid Scale Factor: 0.99991622 local Coordinates Referenced To; Well Head Comments RTE G1 KOP Bid 1.5/100 Bid 2.51100 SV6 1588. 79 6.22 170.00 1530.00 1588.30 6.44 14.01 -13.80 2.43 2.50 O.OOG 2.50 0.00 5979841.31 619506.93 N 70.35355294 W 149.02956232 1600.00 6.50 170.00 1541.14 1599.44 7.01 15.26 -15.02 2.65 2.50 O.OOG 2.50 0.00 5979840.09 619507.17 N 70.35354960 W 149.02956057 1700.00 9.00 170.00 1640.22 1698.52 13.20 28.74 -28.30 4.99 2.50 O.OOG 2.50 0.00 5979826.85 619509.72 N 70.35351332 W 149.02954156 1800.00 11.50 170.00 1738.61 1796.91 21.37 46.53 -45.83 8.08 2.50 O.OOG 2.50 0.00 5979809.38 619513.09 N 70.35346545 W 149.02951648 1900.00 14.00 170.00 1836.14 1894.44 31.51 68.60 -67.56 11.91 2.50 O.OOG 2.50 0.00 5979787.72 619517.27 N 70.35340608 W 149.02948536 Cry 2.5/100 1940.00 15.00 170.00 1874.86 1933.16 36.11 78.62 -77.42 13.65 2.50 -91.22G 2.50 0.00 5979777.88 619519.16 N 70.35337913 W 149.02947124 Base Perm 1945.32 15.00 169.49 1880.00 1938.30 36.74 79.99 -78.78 13.90 2.50 -90.72G -0.04 -9.66 5979776.53 619519.43 N 70.35337543 W 149.02946925 2000.00 15.04 164.21 1932.82 1991.12 43.93 94.15 -92.56 17.12 2.50 -85.62G 0.08 -9.65 5979762.80 619522.87 N 70.35333777 W 149.029. 2100.00 15.43 154.80 2029.32 2087.62 60.01 120.38 -117.09 26.31 2.50 -76.55G 0.39 -9.41 5979738.43 619532.46 N 70.35327076 W 149.029 £OCU 2147.42 15.75 150.55 2075.00 2133.30 68.97 133.12 -128.40 32.16 2.50 -72.45G 0.67 -8.97 5979727.21 619538.48 N 70.35323986 W 149.029 2200.00 16.19 146.05 2125.55 2183.85 79.89 147.57 -140.70 39.76 2.50 -68.12G 0.84 -8.56 5979715.04 619546.28 N 70.35320627 W 149.02925923 SV5 2246.34 16.66 142.30 2170.00 2228.30 90.38 160.67 -151.31 47.43 2.50 -64.52G 1.00 -8.10 5979704.55 619554.12 N 70.35317727 W 149.02919696 2300.00 17.27 138.22 2221.32 2279.62 103.52 176.32 -163.34 57.45 2.50 -60.62G 1.15 -7.61 5979692.68 619564.32 N 70.35314442 W 149.02911568 2400.00 18.63 131.38 2316.47 2374.77 130.85 207.11 -184.97 79.32 2.50 -54.12G 1.35 -6.84 5979671.41 619586.54 N 70.35308532 W 149.02893805 SV4 2440.74 19.24 128.88 2355.00 2413.30 143.03 220.32 -193.48 89.43 2.50 -51.75G 1.51 -6.15 5979663.06 619596.78 N 70.35306206 W 149.02885600 2500.00 20.19 125.51 2410.79 2469.09 161.83 240.31 -205.55 105.36 2.50 -48.57G 1.60 -5.69 5979651.24 619612.89 N 70.35302909 W 149.02872670 2600.00 21.92 120.48 2504.12 2562.42 196.41 276.21 -225.04 135.49 2.50 -43.88G 1.73 -5.03 5979632.24 619643.33 N 70.35297584 W 149.02848201 2700.00 23.78 116.18 2596.27 2654.57 234.51 315.03 -243.41 169.68 2.50 -39.92G 1.86 -4.30 5979614.42 619677.81 N 70.35292566 W 149.02820446 2800.00 25.75 112.49 2687.08 2745.38 276.08 356.90 -260.61 207.85 2.50 -36.56G 1.96 -3.69 5979597.83 619716.24 N 70.35287866 W 149.02789457 SV3 2825.50 26.26 111.63 2710.00 2768.30 287.22 368.08 -264,81 218.21 2.50 -35.79G 2.02 -3.37 5979593.80 619726.67 N 70.35286719 W 149.02781044 WellDesign Ver 3.1 RT-SP3.03-HF4.00 Bld( d031rt-546 ) S-123 \Plan S-123\Plan S-123\S-123 (P4) Generated 7/20/2004 4:35 PM Page 1 of 3 Comments 9-5/8" esg PI SV2 3200.00 34.26 101.90 3033.39 3091.69 475.20 556.33 -317.20 398.79 2.50 -27.36G 2.20 -2.16 5979544.30 619908.04 N 70.35272406 W 149.02634437 End Cry 3226.18 34.85 101.37 3054.95 3113.25 489.98 571.18 -320.19 413.33 2.50 O.OOG 2.22 -2.01 5979541.54 619922.63 N 70.35271587 W 149.02622630 SV1 3427.28 34.85 101.37 3220.00 3278.30 604.26 686.08 -342.85 525.98 0.00 O.OOG 0.00 0.00 5979520.68 620035.62 N 70.35265396 W 149.02531171 UG4 3847.66 34.85 101.37 3565.00 3623.30 843.15 926.27 -390.21 761.46 0.00 O,OOG 0.00 0.00 5979477.09 620271.80 N 70.35252452 W 149.02339994 UG4A 3902.49 34.85 101.37 3610,00 3668.30 874.31 957.60 -396.39 792.17 0.00 O.OOG 0.00 0.00 5979471.40 620302.61 N 70.35250764 W 149.02315058 UG3 4261.95 34.85 101.37 3905.00 3963.30 1078.58 1162.99 -436.88 993.52 0.00 O.OOG 0.00 0.00 5979434.13 620504.56 N 70.35239694 W 149.02_ Drp 1.25/100 4760.99 34.85 101.37 4314.56 4372.86 1362.17 1448.12 -493.10 1273,06 0.00 180.00G 0.00 0.00 5979382.38 620784.94 N 70.35224323 W 149.01 4800.00 34.36 101.37 4346.67 4404.97 1384.21 1470.28 -497.47 1294.78 1.25 180.00G -1.25 0.00 5979378.36 620806.72 N 70.35223129 W 149.0190 3 4900.00 33.11 101.37 4429.83 4488.13 1439.44 1525.81 -508.42 1349.23 1.25 180.00G -1.25 0.00 5979368.28 620861,33 N 70.35220135 W 149.01862815 UG1 4900.20 33.11 101.37 4430.00 4488.30 1439.55 1525.92 -508.44 1349.33 1.25 180. DOG -1.25 0.00 5979368.26 620861.44 N 70.35220129 W 149.01862727 5000.00 31.86 101.37 4514.18 4572.48 1492.85 1579.52 -519.01 1401.88 1.25 180.00G -1.25 0.00 5979358.53 620914.13 N 70.35217239 W 149.01820072 Fault Crossing 5088.74 30.75 101.37 4590.00 4648.30 1538.71 1625.62 -528.10 1447.07 1.25 180.00G -1.25 0.00 5979350.16 620959.47 N 70.35214753 W 149.01783377 5100.00 30.61 101.37 4599.69 4657.99 1544.42 1631.37 -529.24 1452.71 1.25 180.00G -1.25 0.00 5979349.12 620965.12 N 70.35214443 W 149.01778803 Ma 5192.77 29.45 101.37 4680.00 4738.30 1590.59 1677.79 -538.39 1498.22 1.25 180. DOG -1.25 0.00 5979340.69 621010.77 N 70.35211940 W 149.01741856 5200.00 29.36 101,37 4686.30 4744.60 1594.12 1681.34 -539.09 1501.70 1.25 180.00G -1.25 0.00 5979340.05 621014.26 N 70.35211749 W 149,01739030 5300.00 28.11 101.37 4773.99 4832.29 1641.94 1729.41 -548.57 1548.83 1.25 180.00G -1.25 0.00 5979331.32 621061.53 N 70,35209156 W 149.01700769 5400.00 26.86 101.37 4862.70 4921.00 1687.84 1775.56 -557.67 1594.07 1.25 180.00G -1.25 0.00 5979322.94 621106.91 N 70.35206667 W 149.01664040 Na 5424.96 26.55 101.37 4885.00 4943.30 1698.99 1786.78 -559.88 1605.07 1.25 180.00G -1.25 0.00 5979320.91 621117.94 N 70.35206062 W 149.01655113 5500.00 25.61 101.37 4952.40 5010.70 1731.80 1819.76 -566.39 1637.41 1.25 180.00G -1.25 0.00 5979314.92 621150.37 N 70.35204283 W 149.01628861 OA 5547.13 25.02 101.37 4995.00 5053.30 1751.84 1839.91 -570.36 1657.16 1.25 180.00G ·1.25 0.00 5979311.26 621170.18 N 70.35203196 W 149.01612824 5600.00 24.36 101.38 5043.04 5101.34 1773.80 1862.00 -574.72 1678.81 1.25 180.00G -1.25 0.00 5979307.25 621191.90 N 70.35202005 W 149.01595247 5700.00 23.11 101.38 5134.58 5192.88 1813.83 1902.25 -582.66 1718.27 1.25 180.00G -1.25 0.00 5979299.94 621231.47 N 70.35199834 W 149.01563215 OBd 5727.60 22.76 101.38 5160.00 5218.30 1824.53 1913.00 -584.78 1728.81 1.25 180.00G -1.25 0.00 5979297.99 621242.05 N 70.35199254 W 149.01554654 5800.00 21.86 101.38 5226.98 5285.28 1851.87 1940.49 -590.20 1755.76 1.25 180.00G -1.25 0.00 5979293.00 621269.08 N 70.35197771 W 149.01532780 Base Oar 5867.71 21.01 101.38 5290.00 5348.30 1876.48 1965.23 -595.08 1780.01 1.25 180.00G -1.25 0.00 5979288.51 621293.41 N 70.35196436 W 149.01513088 5900.00 20.61 101.38 5320.19 5378.49 1887.89 1976.70 -597.34 1791.26 1.25 180.00G -1.25 0.00 5979286.42 621304.69 N 70.35195817 W 149.015. 6000.00 19.36 101.38 5414.16 5472.46 1921.88 2010.88 -604.08 1824.76 1.25 180.00G -1.25 0.00 5979280.22 621338.29 N 70.35193973 W 149.014 6100.00 18.11 101.38 5508.86 5567.16 1953,82 2042.99 -61M2 1856.25 1.25 180.00G -1.25 0.00 5979274.39 621369.87 N 70.35192240 W 149.01451199 6200.00 16.86 101.38 5604.24 5662.54 1983.70 2073.04 -616.35 1885.70 1.25 180.00G -1.25 0.00 5979268.93 621399.41 N 70.35190619 W 149.01427290 6300.00 15.61 101.38 5700.25 5758.55 2011.50 2100.99 -621.86 1913.11 1.25 180.00G -1.25 0.00 5979263.85 621426.90 N 70,35189110 W 149.01405042 6400.00 14.36 101.38 5796.85 5855.15 2037.22 2126.84 -626.97 1938.45 1.25 180.00G -1.25 0.00 5979259.15 621452.32 N 70.35187714 W 149.01384467 6500.00 13.11 101.38 5893.99 5952.29 2060.83 2150.58 -631.65 1961.72 1,25 180.00G -1.25 0.00 5979254.84 621475.66 N 70.35186433 W 149.01365573 6600.00 11.86 101.39 5991.63 6049.93 2082.33 2172,20 -635.92 1982.91 1.25 180,00G -1.25 0.00 5979250.91 621496.91 N 70.35185266 W 149.01348371 6700.00 10.61 101.39 6089.71 6148.01 2101.70 2191.68 -639.76 2002.01 1.25 180.00G -1.25 0.00 5979247.37 621516.07 N 70.35184213 W 149.01332868 End Drp 6748.67 10.00 101.39 6137.60 6195.90 2110.36 2200.39 -641.48 2010.55 1.25 O.OOG -1.25 0.00 5979245.79 621524.63 N 70.35183743 W 149.01325939 eM1 6903.43 10.00 101.39 6290.00 6348.30 2137.09 2227.26 -646. 79 2036.89 0.00 O.OOG 0.00 0.00 5979240.90 621551.05 N 70.35182291 W 149.01304553 Top HRZ 7025.28 10.00 101.39 6410.00 6468.30 2158,13 2248.42 -650.97 2057.63 0.00 O.OOG 0.00 0.00 5979237.06 621571.86 N 70.35181148 W 149.01287714 Kalubik 7246.64 10.00 101.39 6628.00 6686.30 2196.37 2286.86 -658.56 2095.31 0.00 O.OOG 0.00 0.00 5979230.07 621609.65 N 70.35179071 W 149.01257124 Target 7248.67 10.00 101.39 6630.00 6688.30 2196.72 2287.21 -658.63 2095.66 0.00 O.OOG 0.00 0.00 5979230.00 621610.00 N 70.35179052 W 149.01256843 WellDesign Ver 3,1RT-8P3.03-HF4.00 Bld( do31rt-546) 8-123 \Plan S-123\Plan 8-123\S-123 (P4) Generated 7/20/20044:35 PM Page 2 of 3 Comments Kup C31C21C1 7263.90 10.00 101.39 6645.00 6703.30 2199.35 2289.85 -659. 15 2098.25 0.00 O.OOG 0.00 0.00 5979229.52 621612.60 N 70.35178910 W 149.01254738 LCU 1 Kup B 7284.21 10.00 101.39 6665.00 6723.30 2202.86 2293.38 -659.85 2101.71 0.00 O.OOG 0.00 0.00 5979228.88 621616.07 N 70.35178719 W 149.01251932 Kup A5 7292.34 10.00 101.39 6673.00 6731.30 2204.26 2294.79 -660.13 2103.09 0.00 O.OOG 0.00 0.00 5979228.63 621617.45 N 70.35178643 W 149.01250809 7314.68 10.00 101.39 6695.00 6753.30 2208.12 2298.67 -660.89 2106.90 0.00 O.OOG 0.00 0.00 5979227.92 621621.27 N 70.35178433 W 149.01247722 Kup Base A5 7314.69 10.00 101.39 6695.01 6753.31 2208.12 2298.67 -660.89 2106.90 0.00 O.OOG 0.00 0.00 5979227.92 621621.27 N 70.35178433 W 149.01247721 TMLV 7355.29 10.00 101.39 6735.00 6793.30 2215.13 2305.72 -662.29 2113.81 0.00 O.OOG 0.00 0.00 5979226.64 621628.20 N 70.35178052 W 149.01242109 TO 1 7" Lnr 7464.68 10.00 101.39 6842.72 6901.02 2234.02 2324.72 -666.04 2132.43 0.00 O.OOG 0.00 0.00 5979223.18 621646.88 N 70.35177026 W 149.01226993 LeQal Description: NorthinQ IYI IftUSJ EastinQ IXI IftUSJ . Surface: 3642 FSL 3938 FEL S35 T12N R12E UM 5979855.07 619504.28 Target: 2983 FSL 1843 FEL S35 T12N R12E UM 5979230.00 621610.00 BHL: 2975 FSL 1806 FEL S35 T12N R12E UM 5979223.18 621646.88 . Well Design Ver 3.1RT-SP3.03-HF4.00 Bld( do31rt-546) S-123 IPlan S-123\Plan S-123\S-123 (P4) Generated 7/20/2004 4:35 PM Page 3 of 3 WELL 5-123 (P4) MagneticParameters Model' 6GGM2003 Dip' 80.865' MagDec +24.984' £ 3000 0 0 0 ~ '2 = ~ II Q) ro 0 (/) 0 4000 > I- . . Schlumbepuer FIELD Prudhoe Bay Unit - WOA STRUCTURE 5-PAD Surface Locatiorl Date' September 05, 2004 Lat: N702112.926 FS' 57587.8 rlT Lon W149146.495 NAD27 Alaska Slate Planes, Zona 04, US Feet Northing 5919855.07 nus Grid Conv: +0.91393536' Easting 619504.28 nUs Scale Fo'Ict: 0.9999162231 Mi$Cellarloous Sial" S-123 Plan: S-123 (P4) o 1000 3000 2000 o , ",,'" ..·..R·Tè ..~<v......"_^^_H~" .."""<-,....,,,..,,., _KOP Bid 1.5/100 _Bid 2.5/100 U....HW.".... ......,."".. "VO ^'~"_"=O^_"_" __CN 2.5/100 \ ~UC;U r" \ _9-5/8" C '9 pt }.~ SV2 Fn" "\ \ ~}A \---~'" ;100 V \. '\ ,\~a \ 'VOl \ \--End Drp ¥Ml r':~Target MC~ TD/7"L, 5-123 (P4) 1000 2000 5000 6000 7000 o 1000 2000 3000 Vertical Section (ft) Azim = 107.34°, Scale = 1 (in): 1 OOO(ft) Origin = 0 N/-S, 0 E/-W TVDRøf; RoIaryTable (58.JOftaboveMSl) Sl'vyDate; July 20. 2004 o 1000 2000 3000 4000 5000 6000 7000 300 . 0 -300 -600 . -900 Schlumberger WEll 5-123 (P4) FIELD Prudhoe Bay Unit - WOA 5TRue7URE S-P AD - - - - M;eticPara.met-=- - ~locarlOl1 NAD27 Alaska state Planas, ZOfIEI 04, US Feel MiscelIa08OU8 Modet BGGM 200: Dip: 80.865" Dale: SeplemberQJL<II.: N702112.926 Northing: 5979855,Olf1US GridConv; +0.91393536" S\ct.: 5_123 TVD Ref; Rotary Table (58.3D ft abovQ MSL\ ~ FS: 57587.8n1 Lon W1491 46A95 EaSlÎng: 619504.28ftUS Scala Fact: 0.9999162231 PI~ S-123 (P4) ~ - - - 0 300 600 900 1200 1500 1800 2100 · . · . · . · . · . · . · . · . · . · . · . · . . '- · . . · . . · . . · . . · . . · . . <""<-'^^^'''''''' .,,,......', ,,,.,,,",,,,, ",,,,,,.,,,,,,,,.,<,,,,, .",....."". · . . ~ · . · . · . · . · . · . · . · . '"'''''''' , """",^,, ."".""". "H"'''''' '"'' '" · . · . · . · . · . · . · . · . · . . 'M' ". .~......., ..." '" '«' H'" '"<''''' "~H ......."..,,, """ ..""....., ...-..',.- · . . , . · . · . · . · . · . · . · . · . · . · . · . """" 0 300 600 900 1200 1500 1800 2100 «< W Scale = 1(in):300(ft) E »> 300 o -300 -600 -900 ^ ^ ^ z £' Õ o ~ ~ ,- II Q) (ij () C/) C/) v v v . . Oilfield Services, Alaska Schlumberger Drilling & Measurements SchlllllJ8PIl8P 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Tuesday, July 20, 2004 Jim Smith Prudhoe Bay S-123 (P4) SP Exploration Alaska Doyon 16 Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the SPA Directional Survey handbook (SPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for everyone thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (SP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survev Program: Instrument Type MWD MWD + IFR + MS Start Depth 24.00'md 1,400.00'md End Depth 1,400.00'md 7,464.68'md Close Approach Analvsis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillinq Aids to be provided: A drilling map and a traveling cylinder, will be provided. Checked by: Scott Delapp 07/20/04 Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB S Pad Plan 8-123 Plan S-123 . . Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 31.70 to 7464.68 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 4/9/2004 Validated: No Planned From To Survey ft ft 31.70 1400.00 Planned: Plan #4 V1 31.70 7464.68 Planned: Plan #4 V1 Casing Points MD Hole Size Name ft in 2946.94 2876.00 9.625 12.250 95/8" 7464.68 6901.02 7.000 8.750 7" Summary <-------------- Offset Well path ----------------> Site Well Wellpath PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 5 Pad PB 5 Pad PB 5 Pad PB 5 Pad PB 5 Pad PB 8 Pad PB S Pad PB 5 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB S Pad PB 8 Pad PB 8 Pad PB 8 Pad PB S Pad PB 8 Pad PB 8 Pad PB S Pad PB S Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB S Pad PB 5 Pad PB 8 Pad Plan S-111 Plan 5-119 Plan 5-119 Plan S-203 Plan 8-208 Plan 8-214 8-01A 8-01 B 8-01 8-02APB1 8-02A 8-02 8-03 8-04 8-05APB 1 8-05A 8-05 8-06 8-07A 8-07 8-08 8-08 8-08 8-09 8-100 S-101 S-101 8-102 8-102 8-102 8-102 8-103 S-104 8-105 8-106 8-106 8-107 8-108 8-109 8-109 8-10APB1 8-10A 8-10 Plan 8-111 V5 Plan: PI Plan 8-119 V2 Plan: PI Plan 8-119A V1 Plan: P Plan 8-203 (West) V5 P Plan 8-208 VO Plan: S- Plan 8-214 V1 Plan: 8- 8-01A V1 8-01 B V1 8-01 V1 8-02APB1 V1 8-02A V1 8-02 V1 8-03 V1 8-04 V1 8-05APB1 V1 8-05A V1 8-05 V1 8-06 V1 8-07A V1 8-07 V1 8-08 V1 8-08A V2 8-08B V3 8-09 V1 8-100 V10 8-101 V3 8-101PB1 V9 8-102 V11 8-102L 1 V5 8-102L1PB1 V7 8-102PB1 V14 8-103 V6 8-104 V1 8-105 V5 8-106 V2 8-106PB1 V12 8-107 V36 8-108 V6 8-109 V8 8-109PB1 V2 8-10APB1 V1 8-10A V1 8-10 V1 Date: 7/21/2004 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Reference: Error Model: Scan Method: Error Surface: Db: 8ybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 5 Toolcode Tool Name MWD MWD+IFR+M8 MWD - 8tandard MWD + IFR + Multi 8tation Reference Offset MD MD Warning ft ft 444.20 450.00 1047.00 7.85 1039.15 Pass: Major Risk 393.59 400.00 1022.70 7.01 1015.69 Pass: Major Risk 393.59 400.00 1022.70 7.01 1015.69 Pass: Major Risk 2855.17 3000.00 280.46 47.03 233.43 Pass: Major Risk 1041.91 1050.00 798.35 18.42 779.93 Pass: Major Risk 1285.09 1300.00 905.26 22.84 882.42 Pass: Major Risk 1722.76 1750.00 585.68 31.23 554.45 Pass: Major Risk 1719.13 1750.00 585.53 31.17 554.36 Pass: Major Risk 1484.86 1500.00 594.28 34.12 560.16 Pass: Major Risk 1534.08 1550.00 466.34 24.78 441.56 Pass: Major Risk 1534.08 1550.00 466.34 24.78 441.56 Pass: Major Risk 1532.88 1550.00 466.32 24.76 441.56 Pass: Major Risk 1340.50 1350.00 361.23 21.98 339.25 Pass: Major Risk 1528.71 1550.00 257.46 25.95 231.51 Pass: Major Risk 1488.57 1500.00 145.87 25.49 120.38 Pass: Major Risk 1488.57 1500.00 145.87 25.49 120.38 Pass: Major Risk 1482.29 1500.00 145.80 25.38 120.42 Pass: Major Risk 1589.78 1600.00 46.01 26.94 19.07 Pass: Major Risk 2410.92 2400.00 97.16 49.58 47.59 Pass: Major Risk 2410.92 2400.00 97.16 49.58 47.59 Pass: Major Risk 1841.14 1850.00 183.16 30.18 152.98 Pass: Major Risk 1841.14 1850.00 183.16 30.18 152.98 Pass: Major Risk 1841.14 1850.00 183.16 30.18 152.98 Pass: Major Risk 2792.33 2750.00 267.12 43.19 223.93 Pass: Major Risk 343.64 350.00 974.71 5.86 968.85 Pass: Major Risk 643.30 650.00 956.99 12.23 944.76 Pass: Major Risk 643.30 650.00 956.99 12.28 944.71 Pass: Major Risk 993.26 1000.00 992.18 15.88 976.30 Pass: Major Risk 993.26 1000.00 992.18 15.88 976.30 Pass: Major Risk 993.26 1000.00 992.18 15.83 976.35 Pass: Major Risk 993.26 1000.00 992.18 15.88 976.30 Pass: Major Risk 693.66 700.00 1084.75 10.51 1074.23 Pass: Major Risk 343.80 350.00 1149.14 6.52 1142.62 Pass: Major Risk 1143.07 1150.00 1137.38 17.10 1120.27 Pass: Major Risk 188.15 200.00 1111.12 4.27 1106.85 Pass: Major Risk 188.15 200.00 1111.12 4.27 1106.85 Pass: Major Risk 338.34 350.00 1073.46 6.78 1066.68 Pass: Major Risk 1408.38 1450.00 1007.31 20.47 986.83 Pass: Major Risk 1600.00 1750.00 864.70 27.56 837.13 Pass: Major Risk 1600.00 1750.00 864.70 27.56 837.13 Pass: Major Risk 2980.29 2899.96 311.08 49.77 261.30 Pass: Major Risk 2980.21 2900.00 310.13 49.71 260.42 Pass: Major Risk 2980.29 2899.96 311.08 49.77 261.30 Pass: Major Risk . Schlumberger Anticollision Report . Company: BP Arnoco Date: 7/21/2004 TilDe:.. 09:06:49 Page: 2 Field: Prudl10e Bay Reference Site: PB S Pad Co-ordimlte(NE) Reference: Wéll:Plan $-12$, True North Reference Well: PlanS-123 Vertiéal (TVD) Reference: $..123 Plan5R3 Reference WellpatlJ: P/åi1$·123 Db: $ybase Summary <---------------Off~et WellpatlJ. ......--------------> Reference Offset Ctr-Ctr .. No-Go Allowable Site Well WellpatlJ MD MD Distance Area Deviâtiön Warning ft ft ft ft ft PB $ Pad $-110 $-110V18 1344.44 1400.00 926.63 23.54 903.09 Pass: Major Risk PB $ Pad $-112 $-112V20 1700.00 1850.00 746.94 28.00 718.95 Pass: Major Risk PB $ Pad $-113 $-113V14 287.95 300.00 1059.59 5.94 1053.66 Pass: Major Risk PB $ Pad $-113 $-113AV3 287.95 300.00 1059.59 5.78 1053.81 Pass: Major Risk PB $ Pad $-113 $-113BV6 287.95 300.00 1059.59 5.78 1053.81 Pass: Major Risk PB $ Pad $-114 $-114 V13 288.09 300.00 1124.70 5.92 1118.78 Pass: Major Risk PB $ Pad $-114 $-114A V6 288.09 300.00 1124.70 5.76 1118.94 Pass: Major Risk PB $ Pad $-115 $-115 $T V1 Plan: Plan 643.98 650.00 937.25 10.58 926.68 Pass: Major Risk PB $ Pad $-115 $-115 V7 643.98 650.00 937.25 10.48 926.77 Pass: Major Risk PB $ Pad $-116 $-116 V6 493.84 500.00 847.88 8.16 839.72 Pass: Major Risk PB $ Pad $-117 $-117V4 893.74 900.00 926.49 15.44 911.05 Pass: Major Risk PB $ Pad $-118 $-118V5 1411.12 1450.00 758.75 21.30 737.45 Pass: Major Risk PB $ Pad $-11 $-11 V4 7449.99 7300.00 497.41 230.31 267.10 Pass: Major Risk PB $ Pad $-11 $-11AV1 7450.86 7300.00 497.39 230.40 266.99 Pass: Major Risk PB $ Pad $-11 S-11B V1 7451.34 7300.00 497.37 230.45 266.92 Pass: Major Risk PB $ Pad $-120 $-120 V4 393.90 400.00 915.20 7.18 90R03 Pass: Major Risk PB $ Pad $-12A $-12A V1 4628.79 4550.00 266.49 67.46 199.03 Pass: Major Risk PB $ Pad $-12 $-12 V1 3411.08 3200.00 403.13 54.89 348.25 Pass: Major Risk PB $ Pad $-13 $-13 V1 4539.14 4400.00 129.40 94.12 35.29 Pass: Major Risk PB $ Pad $-14 P/an#3 $-14A VO Plan: 3834.47 3550.00 475.04 104.70 370.34 Pass: Major Risk PB $ Pad $-14 $-14 V5 3834.47 3550.00 475.04 104.59 370.45 Pass: Major Risk PB $ Pad S-15 $-15 V2 2089.03 2100.04 685.54 35.62 649.92 Pass: Major Risk PB $ Pad $-16 $-16 V1 2146.41 2150.00 737.04 34.79 702.25 Pass: Major Risk PB $ Pad $-17 $-17 V1 2236.93 2250.00 791.19 34.04 757.15 Pass: Major Risk PB $ Pad $-17 $-17A V1 2236.93 2250.00 791.19 34.04 757.15 Pass: Major Risk PB $ Pad $-17 $-17AL1 V1 2236.93 2250.00 791.19 34.04 757.15 Pass: Major Risk PB $ Pad $-17 $-17APB1 V1 2236.93 2250.00 791.19 34.04 757.15 Pass: Major Risk PB $ Pad $-17 $-17B V1 2236.93 2250.00 791.19 34.04 757.15 Pass: Major Risk PB $ Pad $-17 $-17C V1 2236.93 2250.00 791.19 33.88 757.31 Pass: Major Risk PB $ Pad $-17 $-17CPB1 V2 2236.93 2250.00 791.19 33.88 757.31 Pass: Major Risk PB $ Pad $-17 $-17CPB2 V1 2236.93 2250.00 791.19 33.88 757.31 Pass: Major Risk PB $ Pad $-18 $-18 V1 632.99 650.00 927.10 12.07 915.03 Pass: Major Risk PB $ Pad $-18 $-18A V16 635.98 650.00 927.19 12.04 915.15 Pass: Major Risk PB $ Pad $-19 $-19 V1 1481.19 1500.01 511.78 25.45 486.33 Pass: Major Risk PB $ Pad $-200PB1 $-200PB1 V4 492.80 500.00 866.54 7.57 858.97 Pass: Major Risk PB $ Pad $-200 $-200 V2 492.80 500.00 866.54 7.68 858.86 Pass: Major Risk PB $ Pad $-201 $-201 V2 293.87 300.00 1098.43 5.14 1093.30 Pass: Major Risk PB $ Pad $-201 $-201PB1 V11 293.87 300.00 1098.43 5.14 1093.30 Pass: Major Risk PB $ Pad $-20 $-20 V4 1867.01 1899.99 419.57 31.67 387.90 Pass: Major Risk PB $ Pad $-20 $-20A V2 1867.01 1899.99 419.57 31.67 387.90 Pass: Major Risk PB $ Pad $-213 Plan $-213A V1 Plan: P 1417.21 1450.00 897.26 21.17 876.08 Pass: Major Risk PB $ Pad $-213 Plan S-213AL 1 V1 Plan: 1417.21 1450.00 897.26 21.17 876.08 Pass: Major Risk PB $ Pad $-213 Plan $-213AL2 V1 Plan: 1417.21 1450.00 897.26 21.17 876.08 Pass: Major Risk PB $ Pad $-213 Plan S-213AL3 VO Plan: 1417.21 1450.00 897.26 21.17 876.08 Pass: Major Risk PB $ Pad $-213 Plan $-213AL4 V1 Plan: 1417.21 1450.00 897.26 21.17 876.08 Pass: Major Risk PB $ Pad $-213 $-213 V6 1416.10 1450.00 897.23 21.16 876.07 Pass: Major Risk PB $ Pad $-215 $-215 V9 2112.19 2100.00 600.15 32.17 567.99 Pass: Major Risk PB $ Pad $-216 $-216 V2 2355.69 2800.00 910.20 52.75 857.45 Pass: Major Risk PB S Pad $-21 $-21 V1 1489.55 1500.00 330.11 25.39 304.72 Pass: Major Risk PB $ Pad $-22A $-22A V1 1439.21 1450.00 549.46 21.90 527.56 Pass: Major Risk PB $ Pad $-22B $-22B V2 1439.21 1450.00 549.46 22.06 527.40 Pass: Major Risk PB S Pad $-22 $-22 V1 1439.21 1450.00 549.47 21.92 527.55 Pass: Major Risk PB $ Pad $-23 S-23 V1 1489.68 1500.00 399.12 22.29 376.83 Pass: Major Risk PB $ Pad $-24 $-24 V5 1681.16 1700.00 291.11 26.88 264.24 Pass: Major Risk PB $ Pad $-24 $-24A V1 1683.53 1700.00 291.18 26.93 264.25 Pass: Major Risk PB $ Pad $-24 $-24B V2 1683.53 1700.00 291.18 26.93 264.25 Pass: Major Risk PB $ Pad $-25APB1 $-25APB1 V2 1484.35 1500.00 208.47 37.15 171.31 Pass: Major Risk PB $ Pad $-25A $-25A V1 1489.58 1500.00 219.08 23.57 195.51 Pass: Major Risk PB $ Pad S-25 $-25 V1 1489.58 1500.00 219.08 23.57 195.51 Pass: Major Risk PB $ Pad $-26 $-26 V1 1539.75 1550.00 185.41 22.95 162.46 Pass: Major Risk PB $ Pad $-27 $-27 V1 1393.33 1400.00 110.24 22.41 87.83 Pass: Major Risk PB $ Pad $-27 $-27 A V3 1393.33 1400.00 110.24 22.25 87.98 Pass: Major Risk PB S Pad $-27 $-27B V7 1392.51 1400.00 110.23 22.14 88.09 Pass: Major Risk Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB 8 Pad Plan S-123 Plan 8-123 . . Schlumberger Anticollision Report Summary <--------------- Offset Wellpath -----------> Site Well Well path PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB 8 Pad PB S Pad PB 8 Pad PB 8 Pad PB 8 Pad 8-28 8-28 8-28 8-28 8-29AL 1 8-29A 8-29A 8-29 8-29 8-30 8-31A 8-31 8-32 8-33 8-34 8-35 8-36 8-37 S-38 8-40A 8-40 8-41 L 1 8-41PB1 8-41 8-42PB1 8-42 8-43L 1 8-43 8-44L 1 PB 1 8-44L 1 8-44 8-28 V4 8-28A V1 S-288 V2 8-28BP81 V7 S-29AL 1 V1 Plan 8-29AL2 VO Plan: S-29A V1 Plan 8-298 V1 Plan: 8- 8-29 V1 8-30 V1 S-31A V3 S-31 V1 8-32 V1 8-33 V1 8-34 V1 8-35 V1 8-36 V1 S-37 V1 S-38 V1 8-40A V1 8-40 V1 8-41L 1 V1 8-41P81 V1 8-41 V1 S-42PB1 V1 8-42 V2 S-43L 1 V2 8-43 V3 S-44L 1PB1 V3 S-44L 1 V5 S-44 V10 Date: 7/21/2004 Time: 09:06:49 3 Co-ordinate(NE) Reference: Vertical (TVD) Reference: 8ybase Reference Offset Ctr-Ctr No-Go MD MD Distance Area ft ft ft ft 1492.37 1500.00 70.73 23.40 47.34 Pass: Major Risk 1492.37 1500.00 70.73 23.40 47.34 Pass: Major Risk 1493.56 1500.00 70.75 23.42 47.33 Pass: Major Risk 1493.56 1500.00 70.75 23.42 47.33 Pass: Major Risk 2557.74 2550.00 80.27 48.59 31.67 Pass: Major Risk 2561 .28 2550.00 80.10 48.54 31.56 Pass: Major Risk 2557.74 2550.00 80.27 48.59 31.67 Pass: Major Risk 2561.28 2550.00 80.10 48.64 31.46 Pass: Major Risk 2557.74 2550.00 80.27 48.59 31.67 Pass: Major Risk 1594.21 1600.00 39.10 26.10 13.00 Pass: Major Risk 1741.17 1750.00 103.58 28.01 75.57 Pass: Major Risk 1741.17 1750.00 103.58 28.01 75.57 Pass: Major Risk 2972.86 2900.00 303.94 48.75 255.19 Pass: Major Risk 1693.33 1700.00 154.97 26.98 128.00 Pass: Major Risk 3254.63 3150.00 251.85 46.67 205.18 Pass: Major Risk 1888.78 1900.00 467.63 28.10 439.53 Pass: Major Risk 3375.86 3250.00 459.25 48.22 411.02 Pass: Major Risk 3495.54 3350.00 491.04 50.40 440.64 Pass: Major Risk 2849.83 2800.00 287.89 39.22 248.68 Pass: Major Risk 2441.44 2500.00 792.69 37.64 755.04 Pass: Major Risk 2441.44 2500.00 792.69 37.64 755.04 Pass: Major Risk 1405.78 1450.00 740.92 25.91 715.01 Pass: Major Risk 1405.78 1450.00 740.92 25.91 715.01 Pass: Major Risk 1405.78 1450.00 740.92 25.91 715.01 Pass: Major Risk 284.89 300.00 782.34 4.85 777.49 Pass: Major Risk 284.89 300.00 782.34 4.85 777.49 Pass: Major Risk 1761.99 1900.00 800.82 27.42 773.40 Pass: Major Risk 1761.99 1900.00 800.82 27.42 773.40 Pass: Major Risk 1192.02 1200.00 830.17 17.99 812.18 Pass: Major Risk 1192.02 1200.00 830.17 17.99 812.18 Pass: Major Risk 1192.02 1200.00 830.17 17.99 812.18 Pass: Major Risk . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME lðt1 5- /¿3 PTD# 2-otJ-~/3 7 Development X Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing well . Permit No, API No. . (If API num ber Production. sbould continue 10 be reported as last two (2) digits a function ·of tbe original API number. stated are between 66-69) above. PILOT HOLE In accordance witb 2.0 AAC 25.665(f), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated 'in botb name (name on permit plus PH) .' and API Dumber (56 - 76/86) from records, data and logs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuU EXCEPTION compliance with 26 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e]: ception. (Companv Name) assumes tbe liability of any protest to the spacing . exception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 3D' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 16' sample intervals tbrougb target zones. Field & Pool PRUDHOE BAY. AURORA OIL - 640120 Well Name: PRUDHOE BAY UN AURO S-123 Program SER PTD#: 2041370 Company BP EXPLORATION (ALASKA) INC Initial ClasslType SER /1 WINJ GeoArea Unit On/Off Shore On 1 Pßrmitfe~ attached_ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . . 2Leasß.numb~r _apRropriate _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ YßS _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 3 _UJ1iqu~ welt n_amß _a!:ld oumb_er _ _ _ _ _ _ . _ _ _ _ . . . . . . . . . . . . . . . . . . . . . . .Y.es . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 W~IIJQcat~d in a_d.efined pool . _ _ _ _ _ _ . . _ _ Yßs _ _ . . . . _ _ . . . _ 5 WeJUQcated prpper .distance from driJling unitb_ound.ary_ _ _ _ _ . . . _ _ . _ Yes _ _ _ . .. _ _ . _ . _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ 6 W~IUQcat~d pr_op~rdistance_ from Qtb~r wells _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ Yßs . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ .. _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ . _ 7 .Sufficient acrea~e_aYail<lble in.drilliog unjL . _ _ _ . . . _ _ Yes _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ . . _ 8 Jtdßviated, js. weJlbQr~ platincJu_ded _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ _ YßS _ _ _ _ _ . _ . _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ 90J)er.ator onl)' affected party _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ Yes _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ . .. _ _ _ _ . . 10 .0J)erator bas.appropr[ateJ20nd inJorce . . . . . . . _ . . . . . . _ _ _ . . . . . . _ . . . . . . . . . YßS. . . . . . . . . . _ _ . . . . . . . . . . . . _ . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . _ . . . . . . . _ _ . . . . . . 11 P~rmitca!:lbeissuedwitbQutco_ns~rvationord~r. _ _ _ _.... _ _ _ _.... _ _ _ _. _. _ _ _ Yes_ _ _ _.._ Appr Date 12 P~rmit ~a!:l be issued wjtbQut ad.ministrati\(e.apprpvaJ _ _ . . . _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _ _ Yßs . _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ RPC 7/26/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUQcat~d within area and_strata .authorized by_lojectioo Ordßr # (puIlOt¡! in.cpmmeotsHFor. Yßs 22_B_ _ _ . . _ . _ _ . _ _ _ _ _ . _ . _ . _ 15 .AJI wells. wit]liJ1.1l4JlJite.area.of reyiew jdßot[fied (Fpr servjc.ewell onl)'). . . . . . . . . . . . _ . . Yß'L . . . . . . $-J 1 a,$-.oM..S_-12A, $-.37,.AND.5-14 . . . . . . . _ _ . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pr~-produ_cedi!:ljector; dvr<ltiQn.ofpre-J)ro.dvctionIßss.tha/13montbs.(For_servicewelI QnJy) .. .NA _ _... _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _..... _ _ _... _ _ _ _.. _. _ _ _. _. _ _ _. _ _. _ _ _ _.... _ _ _.. 17 ACMFFJndjng ofCOllsistency has b~e.njssu~dJorJhis project. . . _ _ _ . _ . _ _ . _ _ _ NA . _ _ 18 .Conductor s!(ingprQvided . _ _ _ _ _ _ . . . _ _ . YßS 19 .S_urfac~_casingpJote~ts alLknown U5DWs _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ YßS. . _ 20 .CMTvoladequateJocirc.ulateon_cond.uctor8.sUJtC$g _ _ _... _ _. _ Yßs.. _8de~vat~excess,_ 21 .CMT vol adequateJo ti~-inJQng _string to_surf csg_ _ _ _ . . . No _ _ . . _ _ . _ _ _ _ _ . . _ _ _ _ _ _ . . _ 22 _CMTwill coyeraJl koowJ1productiye bQri;zon_s_ _ _ _ _ _ _. _ _ _ _ . . . _ Yßs _ _ _ 23 _C_asing designs adequa.te fpr C,_T" B .&_ permafrost _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ . _ _ _ _ _ Yes _ _ _ _ _ _ . 24 Adequ<ltetankage.or re_serye pit _ _ _ _ _ . . . _ _ YßS _ _ _ _ . _ _ Doyon 16. . _ _ _ _ _ _ _ _ . _ _ _ . . . _ _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ _ _ 25 Jtare-drilLhasat0:403fQr<lbandonme.ntbeßoapPJoved_ _ _ _ _ _.. _ _ _ _ _. _ _ _ _ NA _ _ _ _ _ _ _~eww~lI, _ _ _ _.. _ _ _ _ _ _ _ _ . _ _ _.. 26 .Mequate.wellbore separatio.n.proJ)osed. . . . . _ . . . . . . . _ _ . . . . . . . . . . . _ . . . . . . Yes. . . . . _ . . . . . . . _ _ . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . 27 Jtdivert~r required, dQes iLmeet reguJations. _ _ _ . . .. _ _ _ _ .. _ _ _ . . . Yßs _ . . . . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ . . . _ Appr Date 28 _DJilIi(lgfJujdprog.rams~hematic_&~quipJistadequatß_ _ _. _.. _ _ _.. _ YßS_.... _ _MaxMW.9,9ppg._... _ _ _ _...' _ _ _... _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _.. _ _ _ _ _._ WGA 7/26/2004 29 .BOPEs,d_o.they meetreguJatioo _ _ _ _ _ _ . . . _ _ _ _ _ . _ _ _ Yes. . _ _ _ _ _ _ _ _ _ 30 _BOPE-PJess ratiog apJ)ropriate;J~stto-<put psig in.comments). . _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _Yßs _ _ _ _ _ _ T~stto_5DQO.psi.M5~ 23.3D psi. . . _ _ _ _ . . . _ _ _ _ . _ . . _ _ _ _ . . . _ 31 _CMkemanifold cQmpJies w/APtR~-53(May 84) _ _ . . Yßs _ _ _ _ _ . . . _ _ _ _ . . . _ _ _ _ _ _ _ . _ _ _ _ . . . _ _ _ . . . _ . 32 WQrk will occur withOy!operat]oJ1.shutdown _ _ _ _ _ . . _ _ _ _. _ _ _ _ _ . _ . _ _ _ _ Yes _ . _ _ _ _ _ _ . . _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ . . . _ _ _ _ . . . . _ _ _ _ _ . . _ _ _ _ _ . 33 Js Rresence Qf H2S gas. prob_able. _ . . . _ _ _ _ _ _ . _ _ _ _ . . _ _ _ _ _ _ No. _ _ _ _ _ . . ~ota!:l H2S pad. _ . _ _ . . . . . _ _ _ . . _ _ _ _ _ _ _ _ . . _ 34 Mecba.nicaLcoodjt[o!:l pf wells within 80B. y~rified (Forß.ervice w~1I only) _ _ _ . _ . _ _ . Yßs . . _ Cmt reCOJdsindj~ate_m~ch int of.aJI AORweJls. _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ Well bore seg Annular Disposal Administration ~ - - - - - - - - - - - - - - - - - - - - - -- Engineering .20" @ 110' 1\[D.. . - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 P~rmit ca!:l be issued w/Q hydrogen s_ulfid~ meas_ures _ _ _ .. _ _ . . _ . 36 .D.atapr~seoted on pote_ntial overpressure .zones_ 37Sßismic.aJ1alysjs Qf sbaJlow gas_z.o(l~s. _ 38SßabedcondjtjOo survey.(if off-shore) _ _ . . 39 _ CQnta.ct namelp]loneJorwe~kly progress reports [exploratory .only]. _ - - - - - - - - - - - - - - Yßs_ . _ __ _ NA.___ .NA. _ . _ .__ NA.._ . .NA.... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr RPC Date 7/26/2004 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- ~ ~ I Engineering ,;.;~ ;~1 Commissioner: Date o o . .