Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
205-051
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, November 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-111 PRUDHOE BAY UN AURO S-111 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/25/2025 S-111 50-029-23257-00-00 205-051-0 W SPT 6777 2050510 1694 1800 1799 1803 1801 217 466 466 465 4YRTST P Kam StJohn 10/7/2025 4 Year MIT-IA 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-111 Inspection Date: Tubing OA Packer Depth 234 2549 2522 2513IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS251007132324 BBL Pumped:2.1 BBL Returned:2.6 Tuesday, November 25, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg - _ 1� 6, ' P.I. Supervisor ��t FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, October 29, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-111 PRUDHOE BAY UN AURO S-111 Src: Inspector Reviewed By: P.I. Supry BJP r, -- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-111 API Well Number 50-029-23257-00-00 Inspector Name: Lou Laubenstein Permit Number: 205-051-0 Inspection Date: 10/16/2021 Insp Num: mitl.oL211016122804 Rel Insp Num: Notes: 4 year MIT -IA Friday, October 29, 2021 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ! S-111 T e In W TVDp YP J _ — 6777 Tubing1885 lass 1885 s1 ss i --- PTD 2050510 — _ BBL Pumped: -Type Test SPT Test sl 2 BBL Returned: 1694 IA 381 2 OA 166 18 2655 2634 - 1 407 — 2626 a03 Interval, 4YRTST- P/F P Notes: 4 year MIT -IA Friday, October 29, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg > o DATE: Thursday,October 12,2017 P.I.Supervisor ( � l I 1 )C SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-Ill FROM: Lou Laubenstein PRUDHOE BAY UN AURO S-I l l Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv7,.:f42.— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-111 API Well Number 50-029-23257-00-00 Inspector Name: Lou Laubenstein Permit Number: 205-051-0 Inspection Date: 10/12/2017 Insp Num: mitLOL171012140808 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-H1 Type Inj W TVD 6777 Tubing i 2181 2182 " 2156 ' 2151 - 2148 - 2147 PTD 20505.10 Type Test SPT 1Test psi 1694 IA i 383 3002 - 2981 _I 2960 - 2942 " 2929 - BBL Pumped: 2.6 BBL Returned: 2.6 OA 158 438 434 426 - 418 412 • Interval 4YRTST P/F P ✓ Notes: SCANNED ' Thursday,October 12,2017 Page 1 of 1 STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMMIS ON ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Milled CIBP m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-051 • 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 • AK 99519-6612 Stratigraphic 0 Service IRf 6. API Number: 50-029-23257-00-00 7. Property Designation(Lease Number): ADL 0028256 • 8. Well Name and Number: AURA S-111 • 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL • 11.Present Well Condition Summary: f RECEIVED Total Depth: measured 18090 feet Plugs measured feet true vertical 6884 • feet Junk measured 17745 feet N 0 V 0 9 2015 Effective Depth: measured 17955 feet Packer measured 11341 feet true vertical 6895 feet Packer true vertical 11398.23 feet y� �""^y�'`°e CC Casing: Length: Size: MD: TVD: Burst: $ Collapse: Structural Conductor 78 20"91.5#H-40 30-109 30-109 1490 470 Surface 4679 10-3/4"45.5#L-80 30-4708 30-3349 5210 2480 Intermediate 11510 7-5/8"29.7#L-80 26-11536 26-6836 6890 4790 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet M MAR": 0 236 True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 11272-11398 6717-6777 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3746 100 2370 Subsequent to operation: 4987 0 1839 14.Attachments:(required per 20 AAC 25.070.25 071,&25.283) 15.Well Class after work: 9 Daily Report of Well Operations RI Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 • Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ® GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-113 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ). (I. 1 Phone +1 907 564 4424 Date 11/9/15 Form 10-404 Revised 5/2015 VrL 1 /G //GRBDMSOV 13 2015 Submit Original Only • • CI) 0.000000 p N CD r- C.) y 0 0 0 0 0 0 1- O) — O) co co N CO ti m (f) CO r- 00 0o CA co CO CD 0 CF M CO CO N- s"' - M CO f` 00 N- c) (D CO 0 CO N (D N- CD O CO N- CO M Cr) N CO CO CO 40/ (X) CAO CO O M0 CA O O� O M co .— = r r r — V Ci co I Q r N- d) N �U) M M N M N � � r r r — g O OO \ J CX) O co C10 i J I J J N *kLN *k ((D (o N (0 CA N N N (/� C) O M 'CB (V CV N ' U) O N- NI- CO CO N- I-COON N N N- Mco c`i cc CD '— w CO Q U w w O 0 fc c c Z ZWWWWE O Z Z O U) Z J J I- • • a) H ai T- _ m O Tr r O 0- d' O Tr O c T' CD O CO CO N. 4 Ln U) m Tt TrTr00OCAONCOI- OMCD p CO CO 0 (0 OD OD OD CD CD 00 a0 CD O a CO CO CO CO CO CO CO CO CO CO CO CO 0. 0 00 N- C'r) Co — M Tr N- N M CO C'r) S CD O c}' CD U) . M C'r) 0D O CO a0 CO a 4 4 O Ci f- U) O co CA ❑ 0 C'r) Tr Tr a) 00 CD CA N CD N- OD M N W 0 00 CO a) a) a) a) a) a) a) a0 a) a) O > (0 CO Co Co a) CO CO CO CO a) CO CD a) 0 cc W ❑ 0 W Z W W 00 W ❑ 55U c; 0 > O m 0 0 w Y Y 1— g t 0 C D U) N- N- O U) N 0 0 0 0 0 coN J U U W w W ++ LO LC) CO N C D C D — CO LC) U) C D O In J J J Q Q Cd) m ♦+ G LO U() U) CO CO a) N LC) N 4 U) co O Q Q Q W a a Z a N C') 4co co CO N- N U U U J J w = J t• ya Q Q Q EEEi ❑ ❑ a W a U U U W w Z p Z C� 2 2 2 O co co co co co I fl. Q (I) H • s T O CD N N C'r) O N- O O O O O CD CV O N LO LC) U) CD CO CDNLn . MLLt NUI a NMT' 00000I N- L Q d O 2 o a J a a 2 O co co v) u) co a. 0 U c Raaaaan. aawwwaa • < < < < < < QQaaamm 0. 0 t a) O. °' o 00 00 O a0 a0 CO CO Ln U) C] 0 0 0 0 0 0 0 0 0 0 0T- T- ❑ O O o 0 0 0 0 0 o W O N N N N N N N N N N CV N N Z a Q W 03 mmcoL0 � °° � vvv `� � o w� v w w a) a) a) CA CA CA O N- N- Na) a) Q ❑ J I- J J J ❑ tl J J O coaaccoo � L� u_ cOnace a) E co z m a a a O J 0 0 w d u• s ch c) us 6 6 U) U) U) U) U) U) Q Q m LL_ Li co co o_ m • • Packers and SSV's Attachment AURA S-111 SW Name Type MD TVD Depscription S-111 TBG PACKER 11340.75 6750.12 4-1/2" Baker S-3 Perm Packer S-111 PACKER 11398.23 6776.86 5-1/2" BAKER ZXP PACKER ID • > W c o "- Na) oo Ecn- -0c7-13 -00w rica LL m LL O O _cm C Y J m O m ` > > L m ,- m LL. N Q) �ow O y0 .Oo C `w 3 O a) CD 7 C p -op N >O * cum C t N o 4_ C C) c O L �C O c m c 3 Y c 0 0 0 _I „ N---- - 0N0 = 0_ -m -0 U O - 0 a ca 0) U CO Q Q `n m > m 13 m o }`= c O0 U c a) > H c _c c co m �. , Ern 0) o > � O mc E w O c >; a) . o Q . u) aI— E 0 co co .: 'CO ' .c .=, v m oO i- 1 1a CU OM 2 �t0a30 � c o3 O - O 0 _ �' 3 U ' r O m- m m 0: 0 2 0 0 _,Ta w D O •C -o m L L v) > U — 0 N c c g 2 >- o 2 7.62g175 - = 0 %-de„ - 3 E C O D2 p — 0 � _ - c Z > mm (0 N U r O C o f0 Q CO U N C "2 U • j E 't co Q `� N2N- �• cu c0i Inrn 02 m •� QM = 1— * (Oct- a. o 0 o2-- c`') o 0 .� ON M m . 3 `m2LO.. oO75 �-C, a 0 O DE E Nu) N O co C cOQ 3 N m Q o O CU m m M U 0 7 m W I o o ° off> N 0 -10 -0E,cnY (9 � 0) mL coc 0 m-, E m e 1— c v a 0 mc LCL m- m- *nl m � > mm mm O (n 'y O O m a) _ .-- 0 as m 'F- *Y #Y N0) 2 cawo . m- II i • • ai Q„ = c a) L 2 c 0' m 3 Ems cu E mcas -c a) (13 -aa 0 30 - o) o O N a) i E a) :.=. .i.,- Q a) o_ a a) a) T.) 3 = a a) s2 = - o >+ nE c o = 4k 0- c a .°'m E .0 as - E -c c a) , O N a) N - c a) U ,, 3 vin 3 4- a c E c c`- cu E _ m a � c"a 2 m ' as - � N O E O n C a) � 0-a) c a T. 0_-1-, •J � rn 3 E - N n a) c : o c = o o _cN0@� a 0 as o(0 � H co a) nim or)-c E rn n F- o a) L a .= 3_ c • a) 0_ ° oCU U v' _c n... aa co a) M �, v' U a -a c -c 2 3c,) was a) � � 8,13 '5. •3 © 2a) o •0 — rrn � rn ` Eo a) CL co co u) 02 3 .c = f0 -°)o ao cY b '5 r- Q my 2 � ~_ o a) c o , co C co o o m a 1 LL E = a) a) c N Cco 0c0 cd 0032 E c C oy O E a) 4_ o ai = .o2a U rno as 0 � 3a a) 1:1 0 0 .c O o � a) 2 E CO CL an-, oE � m c3aNmo 'co Ci �- Em Q = c`ua) c oI- aa) U cce0 > ncaa) 0co UH a) a) s ... U h v, o U _ f0 o cn cn o - a `- -a _ �. a O r m O 0 = o p N T O = a) 0_ aoo n Lu c .- Cn j LL N E m1- p 34- E w �mM• ob .o 1,-- ,i- _c * a) , a - o � * ca EU cu °' man a ; ., � °° 0g (n Cr) N O - * ~ C s u) in 3 o c fu •- C'L_ * m in rn O azo cn * 3 3 � � ocn a O < ' v �� � Y -o .o •- Y -8 ° cz E n ,- - a) m Zs) 0 P o C > o 0 2 as o m 2 a) _ a) °' m 3 � nmv, rn N EE n rn_ rn > � F- � � co A a) 5 E 0c Cl) m5 Ce 0 3 c E c u) a) 5 � F- o . -a o * a U a c •as p E F- O rn > 0 .4-C) (5)) p E 3 n= ° o ELL c 0. a) 0 24., ON c w 1- O z � E � +. .0 0 � cp O O O N o a) U '� .3 o +� Ca Oa vim U `~ 3 � Qp rnV ems- OU '_ � � � * fnc to aa) 2 a) 3 � aa) 7 _o0 to aaiaa -c ca m 4`:-!.)= iu aa) - aai � 7Li °? _ 3 aa) c � u) u) c -0 -.4- c Qo 3 � 3 a �_Ne c cN Lo c2 C)2a O � o c O O - 0 J O U N O 1001 o O its .0 Cl) O .0 a) a) 0 3 0 O y as Y 3 4- rnU = co (n0wa Ncno0 = a c a) CO 0 � Uo0 0 Cl)= a0 a) __I c• DMO , - -' •O E cc� = D o C U E� O •5 o � o C a) « o � c/) Y a F- * o +- NU * * . c.(8 , 0 cu a) a '- O * F- * Ot cu * a) \ \ o U : 0 .a? 3Y : : a_ NLLU : Uo .0E- n?'o E : U « U 3 E : � z .- .- Lo U) to to 10 r e- r c- O o O o CO i) i) mC\I CV CV (NI Zs e COTs- O r r r rnm � � ao O) ..... O) TREE= CAN VVELLHE D= FMC • S_ RAGE 125 ppm ACTUATOR= HES LEO WHEN ON MI"'"WELL REQUIRES A SSSV WHEN ON INMAL KB.ELE 64.40' MI"'"WELL ANGLE>70"@ 116W BF.ELEV= 35.60' KOP= 620 —I 988' Hr TAM PORT COLLAR Max Angle= 98°@ 12270 ' ' 2124' --14-1/2-HES X ISP,D=3.813" Datum MD= 11371' Datum ND= 6700'SS 10-3/4"CSG,45.5#,L-80 BTC,D=9.95" --I 4708' 11124' H4-112"HESXMP,D=3.813" Minimum ID =3"813" @ 2124' 4-1/2" HES X NIPPLE 11160' —{7-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 4-1/2"TBG,12.6#,L-80 TC-1, 11261' 1 11111188' 4 112"HES X NP,D=3.813" .0152 bpf,D=3.958" 4-112'TUBING STUB(05/28/13) — 11271' 1 1,i 11274' —17-518'X 4-1/2"uM0UE OVERSHOT ' 11320' —14-1/2*HES X NP,ID=3.813"X 11341' 7-518"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' 11364' H4-1/2"HES X MP,D=3.813" ' ' 11385' H 4-1/2"HES X NIP,D=3.813" 11387' —17-5/8"X 5-1/2'BKR HRD ZXP LTP,D=5.580' 4-1/2"TBG,12.6#,L-80 TC-1, H 11398' 7,4' 11398' H4-1/2"%VLEG,D=3.958" .0152 bpf,D=3.958" \ 11409' —17-518-X 5-1/2"BKR FLEX LOCK HGR,D=4.830" 11419' —15-1/2"X4-1/2"X0,D=3.93" YVHPSTOCK(05/31/05) —{ 11535' 7-5/8'CSG,29.7#,L-80 BTC-M, — —11535 .0459 bpf,D=6.875" MLLO JF VVPDOW/(S-111)11535'-11545' PERORATION SUMMARY RIF LOG:SLB MWD 10/12/04 ANGLE AT TOP FERE:66°@ 11534' Note:Refer to Production(B for historical pert data 11792' —{RA TAG(PADDLE OF PUP JONT) SIZE SPF MERVAL Opn/Sqz SHOT SOZ SEE PAGE 2 FOR PERFORATION DATA I I I I I 16791' —IRA TAG(MIDDLE OF PUP JON1) 17100' —+4-1/2"BKR C:BP(09/14/08) PBTD H 17956' \ , 4-1/2"LNR,12.6#,L-80,HYD 521, --I 18040' %�v .0152 bpf,D=3.958" DATE F€J BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 07/08/05 N7ES ORIGINAL COMPLETION 08/15/13 JTG/JMD BAILED SLUGGITS/PULLED PLUG( V11ELL: S-111 06126/13 D-16 RENO PERMT No: 2050510 06/28/13 ?/JMD DRLG HO CORRECTIONS AR No: 50-029-23257-00 06/30/13 PJC TBG D CORRECTIONS SEC 35,T12N,R12E,753'FNL&783'RM. 07/03/13 NW PJC FINAL ODE APPROVAL 08/15/13 JTG/JMD JUNK CATCHER PULL BY R BP Exploration(Alaska) s-111 . . U . . . �r a • 1 PERFORATION SUMMIARY REF LOG:SLB MWD 10/12/04 ANGLE AT TOP PERF:66°Q 11534' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 6 11534-11559 0 09/16/08 3-3/8" 6 11550-11565 0 10/18/05 3-3/8" 6 11602-11627 0 09/16/08 3-3/8" 6 11672-11697 0 09/16/08 3-3/8" 6 12973-12998 0 09/15/08 3-3/8" 6 13200-13215 0 10/18/05 3-3/8" 6 14537-14562 0 09/15/08 3-3/8" 6 16180-16250 0 07/04/05 3-3/8" 6 16330-16450 0 07/04/05 33/8" 6 16550-16590 0 07/04/05 3-38" 6 17200-17300 C 07/04/05 3-38" 6 17520-17950 C 07/04/05 ■ 1.1-4111 * _.• h 4.4 A.Y M DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 07108/05 N7E5 ORIGINAL COMPLETION 08/15/13 JTG/JM) BAILED SLUGGITS/FULLB)PLUG( WELL S-111 06/26/13 D-16 RWO PERMIT No: 2050510 06/28/13 ?LIME) DRLG HO CORRECTIONS AR No: 50-029-23257-00 06/30/13 PJC TBG()CORRECTIONS SEC 35,T12N,R12E,753'FAL&783'FWL 07/03/13 NW PJC FINAL ODE APPROVAL 08/15/13 JTG/JM? JUNK CATCHER PULL BY R BP Exploration(Alas ka) v " Tkt yw\�����y�,s? THE STATE Alaska Oil and Gas �w - '� of Conservation Commission , _: ALASIc:A • ti Pt- _-4-:_ 333 West Seventh Avenue '" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T1 " Moro. 907.279.1433 �F ALAS"- Fax 907 276 7542 www.aogcc.olaska.gov Satl Eric Zoesch Petroleum Engineer c),?t j3 - 0�jl BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, AURA S-111 Sundry Number: 315-113 Dear Mr. Zoesch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Z16P29-e- (11--.._ Cathy P.1 . oerster Chair DATED this u day of March, 2015 Encl. RECEIVED STATE OF ALASKA FEB 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 0.-73' S /5 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown El Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Mill CIBP 0 • 2.Operator Name 4.Current Well Class: 5 Permit to Drill Number BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 205-051-0 • 3.Address. Stratigraphic ❑ Service 0 • 6.API Number P.O Box 196612,Anchorage,AK 99519-6612 50-029-23257-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? AURA S-111 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028256 • PRUDHOE BAY,AURORA OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 18090 . 6884 ' 17100 6935 17100 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91 5#H-40 30.04-108.5 30.04-108.5 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 11510 7-5/8"29.7#L-80 26 35-11536 26.35-6835.71 6890 4790 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 11272.4-11397.67 ' Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft) See Attachment for Packer Depths No SSSV Installed I No SSSV Installed 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work. Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG 0 - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Eric Zoesch Email Eric.Zoesch@BP.Com Printed Name Eric Zoesch Title Aurora&Polaris Field PE Signature of Phone 564-4695 Date 2.7-2_Cr/1 S Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: j I15- i I" Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Br Spacing Exception Required? Yes ❑ No Subsequent Form Required: ,d — 4 ()4 ae? APPROVED BY Approved by: P..9)...t_t_44, COMMISSIONER THE COMMISSION Date 3 -6 -Ls— ,';'-z_ (S— ';L 3/5-//5" RIG !YI � 3-L�/5 0end A h s /S'"-- Form S� Form 10-403 Revised 10/2012 IU3LNMAL lid for 12 months from the ate of approval. Submit Form and Attach e sin Duplicate RBDMSLc APR - 2 2015 g- 0 0 0 0 0 0 0 (6 Cr 0D CO CO 00 00 00 = J J J J J J a) Q O 0 00 0 0 0 (6 r O co co 00 O N- O N V V p NI- V I— O N N N- U 16 0 0 0 0 0 0 0 L O O 01 Cr c- c- M V co V N- N N 00 O 00 N- O O O a) (/) m• O M 00 00 V V Is O CO 00 N- co co N- CD 0 0 0 M co co H co_ E O N N E- O CO 00 N- O O c- r- >, CD 01 00 . O CO CO F-- c NN cO O CD O 0 00 pOm(13 rnr) v '- CD CD rn CD 1.0 CD Nr co U) Ovv '- p J , U) p O N N F O co N N O O 0 O c r r r G O O o O • CO• i CO co .11 CO J JJ 4t 4t 4tr- CO 4t O tr). O OO (Ni O) - - N 00 V N � N p i •— co M • C` O O V O 6) O) CD 00 N N N- N- O C N CO 00 OO J co V w 2 E- CD CDH O .( Uw UJ LU cci j 0 (D O O cC cC w w z w w w m O Hz_ z_ 0 Z J J (/) (/) H Perforation Attachment ADL0028256 Well Date Perf Code MD Top MD Base TVD Top TVD Base S-111 9/16/08 APF 11534 11550 6835 6841 S-111 9/16/08 APF 11550 11559 6841 6844 S-111 9/16/08 APF 11559 11565 6844 6847 S-111 9/16/08 APF 11602 11627 6861 6870 S-111 9/15/08 APF 11672 11697 6885 6892 S-111 9/15/08 APF 12973 12998 6899 6899 S-111 10/18/05 APF 13200 13215 6897 6897 S-111 9/15/08 APF 14537 14562 6925 6926 5-111 7/4/05 PER 16180 16250 6865 6866 S-111 7/4/05 PER 16330 16450 6870 6878 S-111 7/4/05 PER 16550 16590 6889 6894 S-111 9/14/08 BPS 17200 17300 6935 6935 5-111 9/14/08 BPS 17520 17950 6930 6895 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028256 Well Facility Type MD Top Description TVD Top S-111 PACKER 11341 4-1/2" Baker S-3 Perm Packer 6750 S-111 PACKER 11398 5-1/2" BAKER ZXP PACKER 6777 TREE= CNV — ' ' AD FMC -111 TY NOTES:H2S READINGS W„ON MI WELL RREQUIR S AAV�SSGE 125 ppm SVWHEN ON ACTUATOR= FES LEO MI'""WELL ANGLE>70°@ 11635' NTIAL KB.ELE 64.40' 1 BF.ELEV= 35.60' KOP= 620 H 988' H 7"TAM FORT COLLAR Max Angle= 98°@ 12270 , 2124' —14-1/2'FES X NP,D=3.813" Datum ND= 11371' Datum TVD= 6700'SS 10-3/4"CSG,45.5#,L-80 BTC,D=9.95" 1-1 4708' 11124' —14-1/2"FES X M3,D=3.813' Minimum ID = 3.813" @ 2124' 4-1/2" HES X NIPPLE 11160' —17-5/8"X 4-1/2"BKR S-3 PKR,D=3.875' 4-1/2"TBG,12.6#,L-80 TC-H, H 11261' ' 11188' —14-1/2'FES X NP,D=3.873" .0152 bpf,D=3.958" 4-1/2'TUBING STUB(05/28/13) — 11271' r 11274' —17-5/8"X 4-1/2"UnaQUE OVERSHOT 11320' H4-1/2-FESS X NP,D=3.813' 11341' --{7-5/8'X 4-1/2'BKR S-3 PKR,D=3.875" ' 11364' --14-1/2"FES X NP,D=3.813" 11385' —14-1/2'FES X NP,D=3.813" 1138T —17-5/8"X 5-1/2"BKR HRD ZXP ITP,D=5.580' 4-1/2"TBG, 12.6#,L-80 TC-fl, -{ 11398' ' 11398' —14-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 11409' —{7-5/8"X 5 1/2"BKR FLIX LOCK FIGR D=4.830" 11419' —5-1/2'X4-1/2'XO,D=3.93" WHPSTOCK(05/31/05) H 11636' 7-5/8'CSG,29.7#,L-80 BTC-M, —{ —11535 .0459 bpf,D=6.875' MLLOUT VVNDOW(S-111)11535'-11545' PERFORATION SUMMARY REE LOG:SLB MWD 10/12/04 ANGLE AT TOP PERF:66°@ 11534' H Note:Refer to Production DB for historical pert data 11792' RA TAG(MIDDLE OF PUP JOINT) SIZE SPF INTERVAL Opn/Sqz SHOT SOZ SEE PAGE 2 FOR PERFORATION DATA I II I 16791' HRA TAG(MIDDLE OF PUP JONI) 1 17100' H4-1/2"BKR CSP(09/14/08) PBTD H 17956' 4-1/2"LNR, 12.6#,L-80,HYD521, —1 18040' .0152 bpf,ID=3.958" av DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 07/08/05 N7E5 ORIGINAL COMPLETION 08/15/13 JTG/JMD BALED SLUGGffS/PULLED RUG( WELL: S-111 06/26/13 D-16 RWO PERMIT No: 2050510 06/28/13 ?IJM) DRLG HO CORRECTIONS AR No: 50-029-23257-00 06/30/13 PJC TBG D CORRECTIONS SEC 35,T12N,R12E,753'FNL&783'FWL 07/03/13 NPM PJC FNAL ODE APFROVAL 08/15/13 JTG/JMD JUNK CATCHER PULL BY R BP Exploration(Alaska) S-111 II II II II II II PERFORA TION SUMMARY REF LOG:SLB MWD 10/12/04 ANGLE AT TOP PERF 660 @ 11534' Note.Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 11534-11559 0 09/16/08 3-3/8" 6 11550-11565 0 10/18/05 3-3/8" 6 11602- 11627 0 09/16/08 3-3/8" 6 11672- 11697 0 09/16/08 3-3/8" 6 12973- 12998 0 09/15/08 3-3/8" 6 13200- 13215 0 10/18/05 3-3/8" 6 14537- 14562 0 09/15/08 3-3/8" 6 16180- 16250 0 07/04/05 3-3/8" 6 16330- 16450 0 07/04/05 3-3/8" 6 16550- 16590 0 07/04/05 3-3/8" 6 17200- 17300 C 07/04/05 3-3/8" 6 17520- 17950 C 07/04/05 ■ A DATE REV BY COMMENTS DATE REV BY COMMUNIS AURORA UNfT 07108/05 N7ES ORIGINAL COMPLETION 08/15/13 JTG/JMD BAILED SLUGG[TS/PULLED RUG( WE1L S-111 06126/13 D-16 RWO FERMI No 2050510 06/28/13 ?/JM) DRLG HO CORRECTIONS AR No 50-029-23257-00 06/30/13 PJC TBG ID CORRECTIONS SEC 35,T12N,R12E,753'Rst..&783'FWL 07/03/13 NAY PJC FNAL ODE APPROVAL 08/15/13 JTG/JM) JUN(CATCHER PULL BY R BP Exploration(Alaska) ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,UdR,LHD,EAZ01/15/15) General Information Well Name: S-111 Well Type: WAG Injection Well API Number: 50-029-23257-00 Well Activity Conventional 4 Classification: Activity Description: Mill CIBP Cost Code/AFE: APBINJEC Field/Reservoir: AURORA 12 Month Avg IOR, bopd: Job Type: Milling Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory requirements? Sundry Form 10-403 Required? Yes — Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Eric Zoesch Contact numbers: (907) 564-4695 (406)270-983 Well Intervention Engineer: Michael Hibbert Contact numbers: (907)564-4351 (907)903-599 Lead Engineer: Laurie Derrick Contact numbers: (907)564-5952 (720)308-338 Date Created: February 24, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injectic Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) (psi) Cut(%) (Mscf/Day) 2/23/2015 5,000 0 2,345 Current Status: Operable Flowing Inclination>70°at Depth(ft) 11,635' MD Maximum Deviation(Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 98° 12,270' MD — Datum depth,ft TVDss 6,700'TVDss Dogleg Severity(Angle and Depth) 16° 13,481' MD Reservoir pressure(date, 5/26/2013 3,628 psi Minimum ID and Depth 3.813"(2124' psig) Reservoir Temp,F 128° F Shut-in Wellhead Pressure 500 psi Known mech.integrity None problems(specifics) Last downhole operation(date, operation) 4/19/2014 SL set MCX Most recent TD tag(date,depth, None toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, S-111 is a horizontal injector in the Aurora field.An IPROF was performed in April 2006, but it only logged background information, the two heel-most perforations&showed minimal flow into either perf.A FCO was performed shortly after etc: the IPROF, although there are no notes on the IPROF encountering fill.That could explain the shallow stop depth of the log, however. In 2008, a CIBP was set to isolate 1000' of the toe of the well,and perfs were aaaea in nee!at the same time. i ne nistory oT wny the p. /as set is unclear, out Lne lacK OT neei injection in the 2006 IPROF is thought to be the rationale for plugging the toe and adding heel perfs.This increased support of S-122 but reduced support of S-119. Injection performance didn't change significantly post-CIBP&adperf, but a follow-up IPROF in 2010 showed all the injection going into a small adperf interval in the heel. In order to improve reservoir sweep and better support S-119,the plan is to re-open the toe of S-111. Reservoir modelling shows an incremental benefit of 50 mbo over the next 10 years for this v toe CIBP milling job,or—15 bopd.An (PROF will likely be planned after the toe has been back on injection for some time,as there is a large amount of uncertainty around where the water will go once the entire horizontal is open. Well Intervention Details Suspected Well Problem: None Specific Intervention or Well Objectives: 1 Remove CIBP at 17,100'MD 2 3 Key risks,critical issues: Mitigation plan: 1 Insufficient WOB Use metal-metal friction reducers 2 3 Summary Service Line Activity Step# 1 S Pull MCX from 2124', drift to deviation for milling job. 2 C Remove CIBP from 17,100' 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Pull MCX from 2124', drift to deviation for milling job. 1 -Recover the CIBP from 17,100'. MU the following BHA: MHA, up jars,3-1/8"tempress agitator,2-7/8" motor,venturi, -2' barrel(w/3.5"wash pipe and 'v'teeth on the inside. Discuss with Michael Hibbert/Carl/Bob if you have questions),3.8"burn shoe. RIH as deep as well allows.The well will likely 2 C need to be swapped completely over to Safelube to perform this job. Cerberus modeling shows that with the well swapped over to Safelube that there will be-216 Ibf weight on bit @17,100'.Tag CIBP and then PU and begin pumping. Burn over CIBP.When CIBP begins to move down hole RIH pumping an additional 25'then POOH pumping at-1 bpm to try and keep CIBP in BHA. Stop pumping after swab is closed. 3 2-If venturi comes out of hole w/o CIBP then make-up 3.8"junk mill and attempt to push CIBP as deep as possible. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 800 Expected Production Rates: FTP(psi): 1600 Choke setting: Post job POP instructions: POI after CIBP is milled. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~t~S - Q ~~_ Wefl History File Identifier Organizing (done) ^ Two-sided I~) II'lII II11I I~ III ^ Rescan Needed I)f (f~1~~ It I(III (It RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. 3 ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ /s/ Scanning Preparation ~ x 30 = ~ _ + ~~ =TOTAL PAGES TT p t I (Count does not include cover sheet) ~ f ~ f BY: _ Maria Date: l I ~ In I /'S ~ /s/ Y Y V Production Scanning Stage 7 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date:' ~ ~~' D~ /s/ r 1~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III IIIIII IIIN II III ReScanned III IIIIII IIIII II III BY: Maria Date: /s! Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc w \� \) THE STATE Alaska Oil and Gas ti �-�� „ALAS Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue °FALAS� Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 SINNED MAY 0 6 2013 David Bjork Q,�1 Engineering Team Leader O- 0.2 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -111 Sundry Number: 313 -205 Dear Mr. Bjork: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /. Daniel T. Seamount, Jr. Commissioner r DATED this day of May, 2013. Encl. , STATE OF ALASKA RECEIVED ALASOPOIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVAL APR 2 9 2013 20 AAC 25.280 � �'`�j 1. Type of Request: NIN" (ti e�C ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool 011 Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate - ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 205 -051 3. Address: ❑ Development ® Service - 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 23257 -00 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU S -111 " Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior , 10. Field / Pool(s): ADL 028257 & 028256 Prudhoe Bay Field / Aurora Pool « 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18090' • 6884' .17956' , 6895' 17100' • None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 29' - 109' 29' - 109' 1490 470 Surface 4678' 10 -3/4" 30' - 4708' 30' - 3348' 5210 2480 Intermediate 11509' 7 -5/8" 26' - 11535' 26' - 6835' 6890 4790 Production Liner 6653' 4 11387' - 18040' 6772' - 6887' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 11534' - 17950' 6835' - 6895' 5 -1/2 ", 17# x 4 -1/2 ", 12.6# L -80 11398' Packers and SSSV Type: 7 -5/8" x 4 -1/2" BKR S -3 Packer . Packers and SSSV 11341' / 6750' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: • ® Description Summary of Proposal _. BOP Sketch ' ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ❑ Development Service 14. Estimated Date for 15. Well Status aft r propoe o rk: Commencing Operation: June 5, 2013 ❑ Oil fE+ WINJ - al WD PL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned +WAG ❑ SPLUG ❑ Suspended Commission Representative: VLF' SjZ /f 3 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Noel Nocas, 564 -4667 Printed Name: David Bjork Title: Engineering Team Leader Email: Noel.Nocas @bp.com Signature::�,/,# Phone: 564 - 5683 Date: G/�a�% Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 513--20s Sundry Number: s , ,, �! ❑ Plug Integrity LOP Test Ea Mechanical Integrity Test ❑ Location Clearance Other: b'Cp )'ci k'U ' fr -L . Ai 1 T /14 j 1 / YCc,2 4 Ffc' fr-t b 11‘,5 cf / J c i1 C--" (W a. >ErK) & a5 1yvreI 015S6ctafid I.v' th UNAU -e- ui - .5 0-vvvi w1155 Approval. Spacing Exception Required? ❑Yes 12 N o Subsequent Form Required: i O — d69-1. RBDMS MAY — 3 201 Approved By' APPROVED BY COMMISSIONER THE COMMISSION Date'/3 /j.,3 Form 10 -403 Revised 10/2012 vt-r Submit In Duplicate "6 r App o • on is valid for 12 months from the date of approval S j!,� —Du \`� �a` " • • ilomik %O S -111 i Expense Rig Workover Well Objective: Repair TxIA communication by: 1) Pull current 5 -1/2" completion 2) Run 4 -1/2" Well History: S 11i is a horizontal Kuparuk injector drilled and completed in July 2005. It was designed as a WAG injector with access out to the northern periphery of the reservoir in support of S -119, S -102 and S -122. It was put on water injection in September 2005. The first MI cycle for S -111 i was started 12/30/2006. Tubing by inner annulus communication was noted by the Drillsite Operator shortly after the cycle started. The inner annulus pressure was not manageable while on MI injection and the well was swapped back to PWI. An MIT -IA passed to water and an AA was granted for PWI only service. In November 2008 a TecWel noise log showed a definitive leak signature at 3' below the tree - in the first 2' long tubing pup joint. The intent of this workover is to repair TxIA leak by replacing 5 -1/2" Tubing with a 4- 1/2" Stacker Packer Completion to allow the well to be returned to injection service MASP: 2,877 psi Well Type: Injector Estimated Start Date: June 5 2013 Pad Engineer: Tim Lee 564 4904 Intervention Engineer: Noel Nocas 564 -4667 Pre -Riq Work Request: 1 Perform SBHP —30 days prior to rig move 2 PPPOT -T (test to 5000psi), PPPOT -IC (testing to 3500psi), Check LDS one at a time for free movement. 3 Set PX plug in 4 -1/2" Tubing Tail 4 CMIT -TxIA to 4000 -psi. MIT -OA to 2000 -psi 5 Dump 10 sluggits above PX plug. Set 4 -1/2" junk catcher above sluggits. 6 Power Jet Cut tubing loft down first full joint above X Nipple at 11,320' 7 Circulate well with KWF CMIT -TxIA to 1000 -psi 8 Set TWC and Test to 500 -psi from below, 4000 -psi from above • • Proposed Procedure 1. MIRU Doyon 16. ND tree. NU and test BOPE with three preventers configured top down (annular, blind shears, mud cross and 3- 1/2 "x6" VBR's" ). Test the VBR's to 4,000 psi and the annular to 3,500 -psi. 2. Circulate out freeze protection and wellbore fluids 3. Pull and lay down tubing from cut. 4. Change the 7 - mandrel casing pack -off through the BOP stack. 5. Dress the tubing stub and scrape the 7 -5/8" casing. 6. Retrieve the junk catcher. 7. Run 4 - %" 12.6# L80 TC -II tubing with HES TNT packer and overshot to a packer setting depth of 11,150' MD. 8. Displace the IA to packer fluid, freeze protect to 2,200' MD and set the packer. 9. Test tubing and IA to 4,000 -psi. . 10. Set TWC. ND BOPE. 11. NU new 4- 1/16" tree and test and Set BPV. RDMO. Post -rig work: 1 Pull ball'n'rod, Pull BPV , . . r . 0 0 # • Current Wellbore Diagram (page 1) lea. ELEV .0 54 1 SAFETY NOTES; MS READIAOS AV IRAOE 124 ppm WHEN ON If 1 0 finkanilarit&tatithAttla . Mi. WELL AAOLE Tr g liMIE Max Ano • 98 0 15151 - 121 - Mainal. - ' zirr r,o,irrxam.4 'aml .: -. - - ' #6667:::: ...it NMI .,..... 6,11. lies x mz, 0 . 4 11/1 ' i 2216' 5403 ; 132" X 4-1/2' X0, ID • 3 939' P 45 50, L-130 OTC. IS • 925" 4740, OW 1ST /441sISSIS .., Minimum ID = 4.813- 011320 ' nit a ;..,......., • 4.1/2" HES X NIPPLE WS X082 0 021&0137 , • - "00 - • 4 - Olt - %."- 102- TSG, 1 250, LSO, 10 5431 032 Hot , 0 -; 3 aSs " I "STAMM 2 A 1 v COLVs ODEXTENDED PACING ' saol. ' 4. VT X S.117 XO 10 • 33 Isla. leo in, L-mi, To-i, -I a 816' ih D.2220 0 - ten" III an 6515' 5- X 4-14 TO. D = 3 SST III 4 rao. 1 / on. tto. To-4 r SEAM , 11544* 4-1/2' X 5-1/2" 40, 0 = 202303' 042 tat V = 3 or 5.17 119C, 174, L-10, TC-1. r 11223' iii t 11223' 5-L2* x 4-1.1~ 0232140, V = 4 592" II 1111 ', 11320' H4.112- HES X Ma X3= 341r 0,14 ir..7;14 ' ii 343 • -51' x 4-1/2 SKR 30•3 1404, Ii - MI El , 11364' 1 1 13115° H4.1/2" IfES x MI, V 0; 3 al 3" I 11387' 1---1/4 X 54/2' 3AR HRO 2XF LTP ID = 5 500 I 4-ur TSG, I2 ea, 1-80 204 11395' 0 ,14 11318' 4;1/2 CLEO C = 3 35.5" 0152 opt 0 = 31E0' 407, 0 11409 7-st X 501/2 Mtn FLEX IOC( 0 o- 4 830 MILLOUT 119100W 411-111) 11535' • 11545 11792' --fitik TAO A .. OF ki a I . '41iii , 700i . • . 1'S) 11535' 1011* - Kin TAO iMCOLE Of PUP -1 • RSV HY031 • 11563. N --fr , , 14 - 4 ...- 4 - & - 7 , ,,...... cer*7. - 1. 08 CON &WARY I, Ss - '''' ' a3111 REF Lao. Slit NOVO 10/1204 • «, ANELEAT T3P POW. ate 0 10 Oa '. WIT OM ir 1z F11:101,4110S DE for nistorcia parr data FS 32E1 S I NIENVAL J 9000ox f ()ATE . 1111 114 EEEPACE 2 F 110A1 D1R PERFORA cATA i 1 1 1 ''....: . { 4 , [ill C SO , 2' it Cie 2iiir it.'4..".........*****4, - *let tNgi, i 2 eit. LK). 14ve 6277w' 1604W I 1 91C 0469 toot ID 6 575' t„, oi 52 bpt 0 • 3 95e/' ciArE ca .7217 • •E - 7- . •., 1 '9' - ; AURORA Ut4T T/WM 10111111MS 139KX14/11. COMPLETION Oil244709 /MOW SET PX 03601100 *NELL. 3 1011 : .,‘• r" 1 - 1 , 77 .1 . Trot,a r7;:zrialuai PEICAT kr. "2050510 0 TAN CC> awl NV P$fPJ ItILL Fof (22/12/10 Al4 rob: 804329 0 / WI Px. rauz DRAFT CORM=04$ 0211 5 1 FAMAID AOCS31S5SV SAFETY NOTE SEG X, TUN, Mi2p. COM Post 4763' FM. :.,==, tay CM ' 001994 kill',64.,' „QV' * AD04:0 ,' ' - -- 80 01 I : ' - .-4 . , palmy i. , 0 (i - * ;1" , . MP Exploration (Alaska) S-111i 2012 RWO pg. 6 ' 1 • • I • Current Wellbore Diagram (page 2) s - 111 I 11 1 or P13iORAT1ON S(MMRY REF LOO SL8 MMD 10112104 ANGLE AT TOP PEW 66' § 11534' Note Faefer to Production 00 for hietorca1 pert d6ta SZE SW M@IVAL , Ourilig DATE 3311 6 11534.11569 0 ' 0911fiioe ;3315' 6 11560 11585 0 10/18106 1334' 6 11602.11827 o t>411506 R` 3315' 6 11612.11697 0 091 131B' 8 13973.1299E 0 ct15108 1335• 6 Im0.172t5 O 10,1806 13365' 6 14637 - 14E42 0 OliP15108 6 3315' 6 16160. 18250 0 0743446 A34' 6 15330.16450 0 0740405 ;316' 6 19560.16690 O 0743446 3 319' 6 17200. 17300 C 01A 4106 ,3318' 6 17520 • 17950 C wows P. 0 44111 4%4 Se a . /MIL asa� i► ii ,4 / i ��� i 6 .. i♦ • i . i iii IV ■ OA TE REV BY COMMENTS CMTE REV SY COMANTS AURORA vim 074190 IRIS 0150140. COMPLETION 03724431 JOVPRIC SET PX (06603101) V' L S 111 10110106 JOM!RJC PEAFORA11066 US44000 71 RC TOG O0RF113rT101NO PB 1T * 2050610 004596 OTRIRJC ($V (20 03/11/10 RIPOPJC PULL PX (02117110) _ m � AR N1 50.02323257-00 0111047 ./Y0 PJC CMG DRAFT CORRECT10h6 O? 15111 118410 AppED $S$V SAFETY NOTE SEC 35. T12N, R12E 783' PM. S 753' FN. 0311847 SYK'aPAG CM 01110/12 11 M1Jal) ACM WS SAFETY NOTE i 1011 1>tiYP.fC l.."' r,8r'(01x15- 911608) OPEtplorationOlathe) S- 11112012 RWO pg. 7 - • ' , . • ' 0 • I Proposed Wellbore Diagram a aeL - 64 la E NOTES Rts REAL= AV m ERAGE 124 pp BF ELEV = 35 60 S 6. 1 1 1 SAFTY WHEN ON ER WELL REQUIRES A ISSII WHEN ON KOP = 620 mi, WELL A$OL1.7r 116* Max Angle • 99' a 15164 Calt1m1,13 . 1'624' 1 Ehtura EVO. 68.00 SS I 21.11 } I 1 110 314 ad: 4556 L.00 BTC, 0. 9 05 1 4705' Minimum ID a 3 813" g 11320 4-1/2" HE8 X NIPPLE 1>‘ 14-112' III& 1.410 ICH p ( *1 123 1 14 1." IlLs %tap°. 1813" I il 11,154' . Li ,---: M 1--fi str. 4 irz ms itet PI013 Wf 10 I - 11 — 11 : 1 19131 114 1 ar /ICS X115: • 3 1113* 1 11,211' l ov. 7 44 /4 142 1 12* l ig" I I I 11320' 1 .14 ler HES X NP,ID•31117 I , I 11341 j- 1151r X 4-17 SPIR S-3 P11116, ID EITY 1 I I [ 113 ' 1 14 FAA A RP 6 • le' 1 1 I 1138V 4 1 rz HES X PP 08 3111Y X S-Trel 2 XP LIP 0 sum. 1 4 G, 1 60 7C-1, ••=11328 s I I 11398' 1+,/ 'MAO, IC .3 KW 1 --. 1 1140e 'J 174 X 5 fr BAR FLEE L00(11015, 0 .4 SSW J I *IOW VAACOW45.111 11539 - 11545 1 11792 1--fRA TAO (140CLE OF AP .1041Th 1 Mal los) H 11535' i ..... . 15191 RA TAO (941:XLEOf PLP zoom 1 1 u s v 1051311051 H 11653' C., ,,. 441 •6/ ,, 4* — 17100' 14.117 ISKR CW(091 1 ---•••■••••• RERFORA11ON &MARY /1 mTD 1795, I REF LOG 9..8 PAM 10/12J04 AA53LEA7 TOR PEW SW 4 11 SW .■104. Note Rafe( to AoLL.,otor 08 for Ns torca, pa t data ...a. 11,... SILL sw rutuRvA — 1 04%1E42 CATE Aiimmv ...44 SEEPAGE 2 FOR PERFORA 110N DATA I I I I 0 itAi i i Philw • 1 1 col Is 71, L0 — _ i - 2 1 9 5 . wo , c rre LNR 1264, L-80, 11Y01521, —I 180 j 1910111, 0459 WI, 0 . • OM' ■■•4442 4446 ° a ' 52 EV. 11:1 . &SW EA It REV BY CCAAENTS 7 CAW REV BY =MEWS AURORA LW 9711041119 WEB 0•001SAL COM PLETK1N i .., 1W74/Cf, JaaR/C SET PX (MOM NIL,. 5-111 10/113EIE .105411JC PERFORATIONS 1 05124/09 71 RIC TEIG CORRECT065 PERIM" Pb: t 011125,06 15 OLV au , 03111110 FVRIR10 IR.A.L P/C (02/17t1 01 AR No: 50-029-2325740 ' 01:10107 JYI RE CftG CRAFT QORRECTONS CO116111 1661,61LL iADDED $55V SAFETY NOTE SEC 35. Ti 214, R12 E 71311 RV. IL 753' F76. ,..., 03/1807 S1AOPAG GIN 0.0 01114'12 TIMMAE)1ADDED H2S SAWN ('WE 'tonne RRO/FUC_ PERM CRP t09/15-5618108) BP Btpleretion (Atsikal S-111i 2012 RWO pg. 8 FLOOR ELEVATION Workover Mode 25 AGL VALVE LEGEND ■ 10 BYPASS X01 CozIZI 1 02 KILL • • ■ ■ • • ® CHOKE Two Rams .y o ` OWOj= OIKO�I ® LOW PIPE RAMS gi i We' Ali i ©N /A • 13 5/8 ", 5000 PSI, HYDRIL ANNULAR BOP, STUDDED TOP /FLANGED BOTTOM : ; • ; Q7 ANNULAR ACCUMULATOR; KOOMEY TYPE 80, 180 GAL 1111 TRI PUMP: 575 VAC, 30 HP 5O SHEAR RAMS AIR PUMP: 3 ea. KOOMEY FLANGED TOP BX 160 3" CHOKE LINE •M. .111■ 13 5/8 ", 5000 PSI, 14" MPL OPERATORS, HYDRIL BLIND /SHEAR RAM O 0 I II _ STUDDED BOTTOM BX 160 A . . 3 1/8" 5000 PSI HCR VALVE ■'► 4II'J/III' /III.II" 3 1 II' /II► 2" KILL LINE , , , , , , Il 11 I 1r 11 lr 11 J 3 1/8" 5000 PSI HCR VALVE / /8" 5000 PSI GATE VALVE 1 3 1/8" 5000 PSI GATE VALVE 1 111111 f L — • • • • FLANGED TOP BX 160 1500 3000 SINGLE 13 5/8 ", 5000 PSI, 10" MPL OPERATORS, HYDRIL PIPE RAM OPEN LLUSE DISABLED OPEN I.LUL _ STUDDED BOTTOM BX 160 • • • • • • ADAPTER SPOOL KIII CHOKF BOP STACK i ■ ■ WELLHEAD — �i�� _i_i ∎i_i�i∎■_■ I (� • • U :>1 I`<ll ACCUMULATOR MANIFOLD WWI - 20 BOTTLES, 10 GALLONS EACH r ON • =_]1 • • • i REMOTE PA BOP STACK ELEVATION AND U TILITY NEL IN MODULE DOGHOUSE 41. Ilmll NITROGEN BACKUP BOTTLES 21 1 /4 2000 PSI, 5 EACH 16' 150 PSI HYOR. MOP HRDRIL BOP /DIVERTER tram N EEKK Art C �° • ° UMW OPERATED KNIFE GATE VALVE MUDDED TOP /FLANGED BOTTOM II FLANGE /FLANGE RX 73 �vY� 16" FLAb VENT LINE, SCH 80 O PROJECT RIG 16 7/1/10 3 LEA LEA 300 SHEARS 1 WORKOVER MODE BOP SYSTEM 12_20 -OC 2 owe LEA UPOME eoP STACK AND CONTROLS IM■ SURFACE DIVERTER CONFIGURATION 11 -2e -98 1 .m1 LEA 30*6 TO Av1300 °A7 /1/10 CHECKED BY APPROVED BY E 0 E' ear' eR. OEscwEncx ANTS COMB R16BOPSYS&CONTROL 5 WE • " r MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, March 27, 2012 Jim Regg P.I. Supervisor 1, t 4-1(4 z — SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -111 FROM: Jeff Jones PRUDHOE BAY UN AURO S -111 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JEP NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S - 111 API Well Number 50 029 - 23257 - 00 - 00 Inspector Name: JeffJones Permit Number: 205 - 051 - Inspection Date: 3/6/2012 Insp Num: mitJJ120326175509 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5 -111 - Type Inj N - TVD 6750 - IA 310 2520 . 2510 2505 - PTD 2050510 Type Test SPT Test psi 1687 • OA o 0 0 0 Interval IREQVAR P/F P ` ■ Tubing 2980 3140 - 3140 3140 - I Notes: AA 2 year MIT -IA post seal -tite repair. A-X0 2 - C . & 0& 5/ CANNEL: APR 1 4 `/ti, Tuesday, March 27, 2012 Page 1 of 1 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '7 DATE: Tuesday, March 27, 2012 P.I. Supervisor '' b 1 t Z SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -111 FROM: Jeff Jones PRUDHOE BAY UN AURO S -111 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON Comm Well Name PRUDHOE BAY UN AURO S - 111 API Well Number 50 029 - 23257 - 00 - 00 Inspector Name: JeffJones Permit Number: 205 - 051 - Inspection Date: 3/6/2012 Insp Num: mitJJ120326180328 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5 -111 . Type Inj N ' TVD 6750 - IA 157 364 - 364 364 - PTD 2050510 Type Test SPT Test psi 1687 OA 0 0 0 0 1 Interval RE P/F P - Tubing 596 3024 - 3008 3008 - Notes: AA 2 year MIT -T post seal -tite repair. 2Z C.O33 e .N1 APR 4 X011 Tuesday, March 27, 2012 Page 1 of 1 P Th ZO5osto Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, March 08, 2012 7:27 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Q q i (1, Cc: AK, D &C Well Integrity Coordinator Subject: S -111 (PTD #2050510) 2 year MIT -T and MIT -IA for AA 22D.003 Passed Attachments: MIT PBU S -111 3- 06- 12.xls; S -111 AA 22D -003 02- 09- 11.pdf Jim and Phoebe, Injector S -111 (PTD #2050510) that operates under AA 22D.003, had a successful MIT -T and MIT -IA completed on 3/6/2012. The anniversary date for the well was 02/15/2010, but due to the rig workover being performed on well S -110, the - figs were delayed with the well shut in on 02/17/2012 until the test date. The AA required a MIT -T and CMIT -TxIA, but he inspector on the job asked that a MIT -IA be performed with the tubing pressure exceeding the IA pressure by 500 psi, which meets the requirement of the AA. The plan will be to perform the next test prior to 02/15/2014 to maintain the anniversary date. A copy of the MIT and AA are enclosed for your review. - «MIT PBU S -111 3- 06- 12.xls» «S -111 AA 22D -003 02- 09- 11.pdf» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 ., ? M Cell (907) 752 -0755 ± *.44 - Pager (907) 659 -5100 Ext. 1154 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(cDalaska.gov; doa. aoacc.prudhoe.bav(aDalaska.aov; phoebe.brooksaalaska.aov; tom.maunderCcdalaska.gov 3(` (tv OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / S Pad DATE: 03/06/12 OPERATOR REP: Gerald Murphy AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S -111 ' Type lnj. N TVD '6,750' Tubing 2980 3140 3140 3140 Interval V P.T.D. 2050510 ' Type test P Test psi_ � 1687.5 Casing 310 2520- 2510 2505 P /F_ P Notes: AA 2 year MIT -IA (not CMIT TxIA as per J. Jones) OA 0 0 0 0 AA 22D.003 Well S -111 " Type Inj. N TVD 6,750' Tubing 596 3,024 3,008 3,008 Interval V P.T.D. 2050510 Type test P Test psi 1687.5 Casing 157 " 364 364 364 - P/F P Notes: AA 2 year MIT -T OA 0 0 0 0 AA 220.003 Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = lndustnal Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) I Form 10 - 426 (Revised 06/2010) 201 2 -0306 MIT_PBU_S -111 2testsjj • • � r -" f t K s # x a � g x y 4 " a # 1 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS ill 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM2IIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 22D.003 (CORRECTED) Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 BP Exploration (Alaska) Inc. Anchorage, age 196612 A 99519 -6612 ,,E 1 n. F ��� RE: PBU S -111 (PTD 2050510) Request for Administrative Approval Aurora Oil Pool Dear Mr. Cismoski: Pursuant to Rule 9 of Area Injection Order (AIO) 22D, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. This revision corrects the requirements of Rule 3. No other changes have been made. AOGCC finds that BPXA has performed a gel sealant squeeze on Prudhoe Bay Unit (PBU) S- 111 in an attempt to eliminate inner annulus (IA) repressurization. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. Reported results of BPXA's di- agnostic procedures and wellhead pressure trend plots indicate that PBU S -111 exhibits compe- tent primary (tubing and packer) and secondary (production casing) barriers to the release of well pressure while on water injection. The AOGCC believes that the well's condition does not com- promise overall well integrity so as to threaten the environment or human safety, if the well's op- eration is subject to the constraints enumerated below. AOGCC's administrative approval to continue water injection only in PBU S -111 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT -T and CMIT -TxIA every two (2) years to the maximum anticipated injection pressure; AIO22D.003 Corrected • • February 9, 2011 Page 2 of 2 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is February 15, 2010. 14,11,,SIKA 04 DONE at Anchorage, Alaska and dated February 9, 2011. A. // i , ,71 a, 9 - ,, - 14. (7:1; i Mil grl ' T. Se. o nt, Jr. Cathy . Foerster Jo r � an 4L . 1 ) s� Chair, Co - issioner Commissioner Commissioner . s i �,� cc: BPXA Well Integrity Coordinator, PRB -20 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • cr TE � 11 /K P / \ ° SEAN PARNELL, GOVERNOR Lit i \ i .L _I .L._ tr...z) J .,- Lr-L / ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AIO22D.003 Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 BP Exploration (Alaska) Inc. SUMMED FEB 0 4 2011, P.O. Box 196612 Anchorage, AK 99519 -6612 RE: PBU S -111 (PTD 2050510) Request for Administrative Approval Aurora Oil Pool Dear Mr. Cismoski: Pursuant to Rule 9 of Area Injection Order ( "AIO ") 22D.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby GRANTS BP Explora- tion (Alaska) Inc. ( "BPXA ")'s request for administrative approval to continue water in- jection in the subject well. AOGCC finds that BPXA has performed a gel sealant squeeze on Prudhoe Bay Unit ( "PBU ") S -111 in an attempt to eliminate inner annulus ( "IA ") repressurization. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. Re- ported results of BPXA's diagnostic procedures and wellhead pressure trend plots indi- cate that PBU S -111 exhibits competent primary (tubing and packer) and secondary (pro- duction casing) barriers to the release of well pressure while on water injection. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the constraints enumerated below. AOGCC's administrative approval to continue water injection only in PBU S -111 is con - ditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA and CMIT -TxIA every 2 years to the maximum anticipated injection pressure; • • Mr. Doug Cismoski February 4, 2011 Page 2 of 2 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is February 15, 2010. DONE at Anchorage, Alaska and dated February 4, 2011. i • , '"� , , ,. Danie . Seamount, Jr. athy P. oerster J i hn . Chair, Commissioner Commissioner Commissioner sKa U� cc: BPXA Well Integrity Coordinator, PRB -20 z . , '. tr P.O. Box 196612 ' t . • -.- s - Anchorage, AK 99519 -6612 / . ` 7 , RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • • bp sP Exploration (Alaska) Inc. 1 r Attn: WM Integrity Coordinator, PR8.20 Post Office Box 198812 Anchorage, Alaska 99819.8812 DEC 2 7 2010 AiasKa u, s E t3i1S. ConliriiSSiOEG Anclore o December 16, 2010 Mr. Dan Seamount, Chairman Alaska 011 and Gas Conservation Commission 333 West 7'" Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well S -111 (PTD# 2050510) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay Well 3 -111 with slow inner annulus repressurization while on MI injection. WeH 3 -111 was treated with a gel sealant on 02/01/10 to mitigate tubing by inner annulus communication. An AOGCC witnessed mechanical integrity test on the tubing and tubing by inner annulus passed on 02/15/10 verifying two competent barriers. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. In summary, BPXA believes Prudhoe Bay Well S -111 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, pleas* contact me at 564 -4303 or Torin Rosc hinger / Gerald Murphy at 659 -5102. Sincerely, D aed,‘4-ostta4 . Douglas A. Cisrrwski, P.E. BPXA Wells Intervention Manager • • • Attachments: Technical Justification TIO Plot Injection Plot Welibore Schematic Cc: Doug Cismoski Steve Rossberg Bixby /Liddelow Murphy /Roschinger Harry Engel GC2 O &M Team Leader Damien Greaves • . Prudhoe Bay Oil Poo! Well S -111 Technical Justification for Administrative Approval Request December 16, 2010 Well History and Status Prudhoe Bay Well S -111 (PTD #2050510) was treated with a gel sealant on 02/01/10 to mitigate tubing by inner annulus communication. An AOGCC witnessed mechanical integrity test on the tubing and tubing by inner annulus passed on 02/15/10 verifying two competent barriers. Recent Well Events: > 11/25/08: Memory LDL on MI, thread leak CO crossover - 26 ft > 02/01/10: Gel sealant treatment of TxIA > 02/15/10: AOGCC MIT -T Passed to 3000 psi & CMIT -TxIA Passed to 2500 psi > 02/17/10: Pulled TTP from 11364' Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A sealant was squeezed from the tubing into the inner annulus to ensure the sealant would hold against the water injection pressure. Consequently, if the pressure in the inner annulus becomes greater than that in the tubing, the sealant may be dislodged from the leak path. Thus, the well will need to be secured and a mechanical integrity test on the tubing and tubing by inner annulus will need to be conducted to evaluate future integrity of the welibore. A pressure test of the tubing and tubing by inner annulus passed on 02/15/10, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 2 -year MIT -T and CMIT -TxIA to 1.2 times maximum anticipated injection pressure. 4. The well will be shut -in and the AOGCC notified if there is any change a in the well's mechanical condition. 11111M. . S • Well S-111 TIO Plot WAS-1111 4.090 - ..... .......... .. ............... 3E00 • 2,600 L : 4 LA 4.-- OA Is ...41 00A 1 4. 000A -...• On IMO `'.. 1 , 0 : li fir ----- I. ort 1 1 1 71.1. 0 k — L ‘4, 4.7 Jill 4, 12/29/09 olnono 03/01/10 04/01/10 95/02/10 04/02/10 07/03/19 09/03/10 09/03/10 10/04/10 11/04/10 12/05/10 Well S-111 Injection Plot wsts.,,, . . . , 2.409 --- — - moo 2.200 . 18000 17,000 2.000 - 9 16.COC1 0 1,800 rk,,— I . , 1,603 - 13.060 —WHIP 1.400 5 1,200 — MI ) 1 X ,00 g ocoo 8 _ GI ....... o. Lr.A —0th. ll ) 700 COO . 6.000 E...----- 600 )11 1 { Iflt . 1, 5.003 ",- 400 400 3003 200 .. /I i rj 2.000 'LOCO 12/29/09 01/29/10 03/01/10 04/01/10 095/02/19 06/02/10 . 07/03/10 . I C8/03/10 . 09/133/10 10/134/10 11434/10 12415/10 • I a 0 • a a5.s8' SAFETY !MOTES: WELL A.NG4,E»70'@11835` I 63F. � ° 35.83* trax Mg3> ' 9a • n 15165 D39■rhM3a_ t9fi2S' — 26' 7'x5- tl2 X0. €D +4802' iiitJrnTVp; 89bp'SS f E 9' 3-112' t€S X I t7 P4 7 :76712 __I X0, is, . a . 03a' a -3.14' CSC, 45.80- L -a0 tiTC. 9) s 9.95' ,.... 4108` GAS LPT MANDRELS MinitTmm ID = 3.813`° CI 11320 ar ,i �r ® lad! — ii aT02 KCil2 a 0 03,1(1/0' 4.112" FiES X NIPPLE f Sass I Kcal 1 0 Me 8A37 �� 'f,0TE: 4-1 . Q M N5-ter TSG - _.. 4 -1e G. 12.i . L•80, Tea. 5431' «STAT10Tts 2 & t . DGI.V.4 WANT 5143C-0 PACK1120 0152 trtf.10 -;3 9 ' M 4- 1.2'X5 -1!2' X0. !3.3.938' 5.112' Tf9G, 174, L- t>Et.TGII. 5516• n2sx tpl. ED 4.s9r 951 5-1w X 4- la x0, a ° a.gaa• 4.112°TBG.12.t6l,L- 83,TC1I, 9544 9544' 4- 1r'X5- 1 /rXo,1D -5038' _0152 bpi, 43.3 958° 5• t/2 TSG, 174, L -i 4. TC I, 11223' MIUMNII 5 -t /2 -x 4 -i,' X0, 3 «•3.9-15` 02:32 tot. ID. 4.852 11325' 4 -1.12' 1 X MP 10.3 813' 01'771 !As, IIIII MM. 7.518'X4.1erS3KRS.3PKR.E3 -357 I 11384' 4- tirHESx14P.10 -3513' 1385 MgailliMiZata MEM 7.58' X & 1l2 0KR MS ZXPLTP, to = 5.580 4- ler TEG, 12+34, L.80, TO& - 11396' ,, .� 11336' 4.1x1' WLEG. 0. 3.959' a t $2 tot, :D. 3.959' RTd --- -- 11409' t 7.em 26t •x5- trRFLEXLOC IK tG/0 >a- 833' I IL TWINDOW(S -111) 11535'- 11545' 11792 N iik TAO (t.4DLEOE PUP.101N1) 1 WitPS OCK {0513 t.f1S} 11�T. I RA TAG (f/ DCLEOF 1 UP.30841) r' ZSV (05/3$05) 11553' 17100' 4- 1/2sKRC P(o9l14t00 s...° it . �': P�t�FOxaroia sLaRv RSE LOC: 51..8 t WD 10/12.114 Ahff AT TOP PS3tF :66° § 11534' ,sate: Eater Sa Praducton Ci3 1cr nstaelaat pert dela fik S¢EI SW I titEFIRdAL I Of:Wagz i DA1 *sew 8EE PAGE 2 FOR FERP 3RAT23N DATA E I I I );+;•;41.;* i + ; 1 440i.ii i. % s t/Y UR. 12.54. L•80, HYO 521. 18 +: 1' a' G SC,2s. ra a o. * * * * * * * * * * * * * * * * * 4 -e 7•Si ....a ∎, ....... - 4 0152 t, Et ..3.558 #iTG t$ 4459 tot, 0 +6. ��.�i� : *..� :. :i: �R 1 MITE REV E���Y COVMENf3 lYl7E REV 5Y CX?tedl'S AURORA UNIT 7Ii'T=i t+iil:ir::ata t. j r ' L� aT 3 a: � : i • s F.Iiplizi ptit: WW.:. -? I t to,19/09 yyj r ii '111=111 f ir PERMT No. '5Q510 'War' - _ ' LV C, - a 'r' - TT "' • (0 " , 110} AP1 Na: 93 -024- 23237.00 01/10,07 DELL DRAF-t'CORRECTSC3NS � .. SEC 35, Tt2N. R12E. 783' FV& & 753' FM. ,81. .1,T•Y- 'L s 10,17!09 RRO.P.JC PEWS/ CO Olga Slit 6ti8} LW Exploration IAlaska) r Schiamherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO. 5514 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99507 Log Description Date BL Color CD Z-30A P-16 03-01 P2-22 U-03 AWJI-00077 AYS4-00122 B9RH-00024 BBUO.00007 BBKA 00 21 MEMORY GLS - PRODUCTION PROFILE _ L X-FLOW CHECK/IBP/CEMENT DUMP - USIT 03/06/10 03/08/10 04/21/10 03!08/10 1 7 1 1 1 1 1 1 03.37 S-111 - 0 BBKA-00023 BSJN X--FLOW CHECK/P UGlC MENT G/ '- L STATIC PRESSURE SURVEY ~ ._) 04/22/10 04/24/10 1 1 1 1 R-28 R-04 13-23A S-O6 Z-31 17-22 14-07 04-29AL1 A-O6 A-28 -00049 BCZ2-00009 BCZ2-00010 BBSK-00016 BBKA-00026 83S0-00060 AWJI-00085 AVYO-00068 BBSK-00017 BBKA-00006 AYTO-00037 INJECTION PROFILE PRODUCTION PROFILE - ~ PRODUCTION PROFILE - INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE MEM PRODUCTION PROFILE ~" - PRODUCTION PROFILE ' Q USIT RST - RST - - 04/19/10 04/26/70 04/27/10 04/29/10 04/30/10 04/21/10 04/28/10 04/26/10 04/30/10 02/09/10 02/16/10 1 1 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 17-09A 17-09AP81 l0AKA0128 10AKA0128 OH MWD/L D EDIT - OH MWD/LWD EDIT ~ 02/11/10 0210'7/10 2 2 1 1 PLEASE ACKNOWLEDGE REC EIPT wv sirn~irJ r_ nun ocrrronnur_ n.,e nn.... ~...,. ~... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 os/o7n o C~ P~ [[ ' 1~t r]~1 ~n~`~ ~ ~~`~~ 7(~1C l~ NOT OPERABLE: 5-111 (PTD #205Q~10) TxIA communication • Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] 1 1 ~ Sent: Tuesday, March 09, 2010 4:42 PM 1~~~ X110\1 To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: Phillips, Patti J; Oakley, Ray (PRA); Janowski, Carrie Subject: OPERABLE: S-111 (PTD #2050510) TxIA comm mitigated post Seal-Tite treatment Attachments: S-111 TIO Plot 03-09-10.doc ,j" All, / Injector S-111 (PTD #2050510) has been reclassified as Operable. After monitoring the TIO plot for 8 days, the TxIA communication appears to have been mitigated with aSeal-Tite treatment. Please notify well integrity if the IA pressure begins tracking the tubing pressure. A TIO p of has been included for reference. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 `.~'~ ~~At( .'" `~ ~a)~ Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, February 20, 2010 2:17 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: Phillips, Patti J; Oakley, Ray (PRA); Quy, Tiffany; Wellman, Taylor T; Murphy, Gerald L; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-111 (PTD #2050510) Monitor post Seal-Tite treatment of TxIA Comm All, Well S-111 (PTD #2050510) has been treated with Seal-Tite in an attempt to restore tubing integrity. After the treatment, the well passed an AOGCC witnessed MIT-T and CMIT-TxIA. The well has been reclassified as Under Evaluation so that it may be returned to injection and monitored for repressurization. When ready, please contact the Well Integrity Engineer at 659-5525 to arrange for DHD to assist in returning the well to injection and managing annulus pressures. A recent TIO plot has been included for reference. If the Seal-Tice treatment is successful, a request for Administrative Approval will be sent to the AOGCC to modify UIC testing to conducting aMIT-T and CMIT-TxIA instead of a MITIA. This will help to protect the sealant as is was applied from the tubing side. Please let us know if there are any questions. Thank you, Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 3/10/2010 NOT OPERABLE: 5-111 (PTD #2050) TxIA communication • Page 2 of 3 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, July 27, 2009 10:22 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: NOT OPERABLE: S-111 (PTD #2050510) TxIA communication All, Well S-111 (PTD #2050510) is exhibiting IA repressurization and failed a subsequent MITIA. The well has been reclassified as Not Operable. The well will be secured with a downhole plug and remain shut-in until repaired. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, July 27, 2009 1:38 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-111 (PTD #2050510) Increased rate of IA repressurization All, Well S-111 (PTD #2050510) was bled on 7/25 after the IA pressure was found to be near tubing pressure. A monitor the following day showed the IA pressure back up to 1950 psi. The well has been reclassified as Under Evaluation. The plan forward is to leave the well on injection to investigate the communication with an MITIA this afternoon. If the well fails the MITIA, it will be immediately shut-in and secured with a downhole plug. A TIO plot and welibore schematic have been included for reference. « File: S-111 TIO Plot.doc» « File: S-111.pdf» Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator 3/10/2010 NOT OPERABLE: 5-111 (PTD #2050) TxIA communication • Page 3 of 3 Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 3/10/2010 PBU 5-111 PTD# 2050510 3/9/2010 TIO Pressure Plot ~- Tbg ~- IA --~- OA DOA ~- oaOA - On I 12!12!09 12!19!09 12!26!09 01!02110 01!09!10 01!16!10 01!2:;!10 01!30!10 02!06!10 02l1?f10 02f20~10 02!27!10 00!06!10 AOGCC MITIA Forms for MPE-17 (1961150), MPF-70 (1951530), MPI-OS (1951200), ... Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 28, 2010 9:51 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW Well Integrity Engineer; MPU, OMS Facility Coordinator; MPU, OMS Field Coordinator Subject: AOGCC MI For E-17 (1961150), MPF-70 (1951530), MPI-05 (1951200), 13-22 (1820770) S-111 (2050510), S-134 (2090830), WGI-03(1790490), WGI-08 (1900490} Attachments: Reviewed MIT Forms.zip Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: MPE-17 (PTD #1961150) MPF-70 (PTD #1951530) MPI-05 13-22 -~f S-111 "'S 134 WGI-03 WGI-08 (PTD #1951200) (PTD #1820770) (PTD #2050510 (PTD #20 0830) (PTD #1790490) (PTD #1900490) «Reviewed MIT Forms.zip» Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 .. ~. ~ U ~c` ~~ r~ C ~ & 5', .,. ~11i 4/29/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.brooks~alaska.gov; tom.maunder~lalaska.gov; doa.aogcc.prudhoe.bay~alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay! PBt1 f S Pad DATE: 2/15f10 OPERATOR REP: Anna Dube AOGCC REP: Chuck Scheve Packer D h Pretest Initial 15 Min. 30 Min. WeII S-134 T In'. W TVD 6,520' Tubi 1,875 1,875 1,875 1,875 Interval I P.T.D. 2090830 T test P Test i 163t? Casi 2,520 2,480 2,4$0 P/F P Notes: MIT-IA to 2500 psi post initial injection OA 50 200 190 190 W S-1 tt T N TVD 6,750' T 600 3,Ot0 2,940 2,895 lntervaf O P.T.E7. t0 T P Test 1688 175 t75 165 PIF P Notes: MIT-T to 3000 psi post Seal Tfte Treatment OA 120 140 140 140 Extended test for additional 30 mins. At 45 mins 2870/160/140. At 60 min 2860/160/140. Well S-111 T In'. N TVD 6,750' Tubi 2,860 3,000 3,240 3,220 Interval O P.T.D. 2050510 T test P Test i 1688 Casi 160 2,500 2,470 2,465 P!F P Notes: CMIT-TxIA to 2400 psi post SCI Tite treatment OA 140 420 410 410 Well T In'. TVD Tubi Interval P.T.D. T test Test i Casin P/F Notes: OA Well T In'. TVD Tubin Interval P.T.D. T test Test Casi P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Mon'doring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Gycle I =Industrial Wastewater R = IMemal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomay Survey T =Test during Workover W =Water D =Differential Temperature Test O = Olher (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU S-111 S-134 02-15-10.x1s STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS Ib 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ SEAL TITS Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ TREATMENT Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ GEL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 205-0510 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-23257-00-00 8. Property Designation (Lease tuber) : 9. Well Name and Number: ADLO-028256 ~ S-111 10. Field/Pool(s): \ `PRUDHOE BAY FIELD /AURORA OIL POOL 11. Present Well Condition Summary: Alaska Oil 8 6s~ Cert. Conrnis Total Depth measured ~ 18090 feet Plugs (measured) 17100' 9/14/08 feet ~~~~~~~~ true vertical 6884.05 feet Junk (measured) None feet Effective Depth measured 17955 feet Packer (measured) 11341 11387 true vertical 6894.64 feet (true vertical) 6750 6772 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31 - 111 31 - 111 Surface 4678 10-3/4" 45.5# L-80 30 - 4708 30 - 3348 6890 4790 Intermediate Production 12169 7-5/8" 29.7# 26 - 12195 26 - 6945 6890 4790 Liner 6653 4-1/2' 12.6# L-80 11387 - 18040 6772 - 6887 8430 7500 Liner Pertoration depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# LL-80 24 - 11223 24 - 6692 4-1/2" 12.6# L-80 11223 - 11397 6692 - 6776 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer 11341 6750 5-1/2" BAKER ZXP PACKER ••_---~--~-11387~~- ... 6772 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,~~~gy ~• Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 10061 1976 Subsequent to operation: 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daity Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-427 Contact Patti Phillips Printed Name Patti Phillips Title Pad Engineer Signature -- Phone 564-4578 Date Form 10-404 Revised 7/2009 2 23.to Submit Original Only ron S-111 205-051 PERF 4TTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-111 7/4/05 PER 16,180. 16,250. 6,864.87 6,866.41 S-111 7/4/05 PER 16,330. 16,450. 6,870.02 6,877.62 S-111 7/4/05 PER 16,550. 16,590. 6,888.83 6,894.34 S-111 7/4/05 PER 17,200. 17,300. 6,934.86 6,935.15 S-111 7/4/05 PER 17,520. 17,950. 6,929.83 6,895.11 S-111 10/18/05 PER 13,200. 13,215. 6,897.33 6,897.46 S-111 10/19/05 PER 11,550. 11,565. 6,841.08 6,846.79 S-111 9/14/08 BPS 11,354. 11,534. 6,756.4 6,834.91 S-111 9/15/08 PER 14,537. 14,562. 6,925.34 6,926.07 S-111 9/15/08 PER 11,672. 11,697. 6,884.56 6,892.07 S-111 9/15/08 PER 12,973. 12,998. 6,899.11 6,898.74 S-111 9/16/08 PER 11,602. 11,627. 6,860.93 6,869.9 S-111 9/16/08 RPF 11,534. 11,559. 6,834.91 6,844.47 S-111 8/3/09 BPS 11,364. 17,200. 6,761.09 6,934.86 S-111 1/24/10 BPS 100. 102. 100. 102. S-111 2/13/10 BPP 100. 102. 100. 102. S-111 2/17/10 BPP 11,364. 17,200. 6,761.09 6,934.86 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 5-111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/30/2010 T/I/0= 80/35/95. Temp= SI. Assist Seal-rite (Pumping Flo-Seal). Bleed IAP from 35 psi to 0 psi. Started pumping Flo-Seal down TBG. Using 5 gal of Flo-Seal to ; pressure TBG to 1000 psi hold for 1 hour. Shut-in IA bleed to monitor BUR. IAP j increased 4 psi in 15 minutes. Open IA bleed and continued pumping Flo-Seal to increased TP to 1500 psi. Shut-in IA bleed to monitor for 1 hour. During monitor €TP dropped from 1500 psi to 250 psi in 3 minutes, IAP increased to 3 psi during , `that time. Re- pressured TP back to 1500 psi, using 1 gal of sealant and ;monitoring for 1 hour. WHPs unchanged, left 1500 psi on TBG to track overnight ?pressure. "*Job Incomplete"" Final WHPs= 1500/0/95. SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 1/31/2010;T/I/0= 320/10/95. Temp= SI. Assist Seal-Tite (Flo-Seal Treatment). TP ~ decreased 1280 psi, IAP increased 10 psi overnight. Bled IAP from 10 psi to 0 psi in 30 sec. Pumped Flo-Seal to increased TP from 320 psi to 1500 psi. Shut-in IAP bleed, held TP @ 1500 psi for 1 hour, IAP increased 3 psi during 1 hr monitor. j Bled IAP back to 0 psi. Continued pumping sealant to increase TP in 500 psi increments from 1500 psi to 3000 psi, holding TP for 1 hour each time. IAP I increased 4 psi during 3 hr monitor. Total Flo-Seal used 2.5 gal. 3000 psi left on TBG to allow sealant to cure. **Job incomplete**. Final WHPs= 2950/4/95. €SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. i 2/1/2010~T/I/0= 2500/7/105. Temp= SI. Assist Seal-Tite (Flo Seal Treatment). TP decreased 500 psi, IAP increased 2 psi, OAP increased 10 psi overnight. Pumped E 1 gals diesel down TBG to increased TP to 3000 psi, IAP increased 5 psi. ;Monitored for 30 minutes, 1st 15 minutes T/I/0= 3000/12/105 psi, no pressure lost. i2nd 15 minutes 0 psi lost. In 30 minutes 0 psi lost. 3000 psi left on TBG. **SWAB VALVE LEFT CRACKED TO MONITOR TP WHILE SEALANT CURES, VALVE ~ HANDLE FLAGGED AND TAGGED. DSO NOTIFIED AND APPROVED*" Job 'incomplete- ** Final WHPs= 3000/12/105. WV=closed. SSV,WV=open. IA,OA=open to gauge. NOVP. 2/5/2010 T/I/O = 2050/30/120. Temp = SI. WHPs for 5 days (eval Sealtite repair). TBG pressure decreased 950 psi, IAP increased 18 psi, OAP increased 15 psi, since 2/1/10. "*NOTE"* Swab valve left cracked open to monitor TP while sealant cures, valve handle flagged and tagged. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. • • 2/6/2010 T/I/0=2050/30/120. Temp=S1. WHPs for 5 days (eval Sealtite repair). WHPs unchanged overnight. WV=Closed. MV, SSV, SV=Open. IA & OA=OTG. NOVP. 2/7/2010T/I/O= 2600/44/130. Temp= SI. MIT-T-FAILED to 3000 psi (post Seal-Tite treatment). Pumped approximately .5 gal diesel to reach TBG test pressure of 3000 psi. Started 30 minute monitor, 1st 15 minutes 0 psi lost, 2nd 15 minutes 40 ~ psi lost. Total lost of 40 psi in 30 minutes. IAP did not increased during test. Re- ~pressured TBG to 3000 psi for second test. 1st 15 minutes 0 psi lost, 2nd 15 !minutes 40 psi lost. Total lost of 40 psi in 30 minutes. IAP did not increased during test. Repeated process once more testing TBG 3 times w/ the same results. Total ?diesel used 10 gallons. Flowline pressure unchanged during testing. Possible leaking WRP set @ 75'. Job complete. Final WHPs= 2920/44/130. ~SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 2/9/2010 _ . _ . _~.__.__..... ~ ~ _ ~ . _ _ _ ___. ___W_.._.. __ __ ___. _.___ ~ ~ ~__ T/I/O 2100/48/140. Temp= SI. MIT-T to 3000 psi & IA to 2000 psi (post Seal-Tite treatment). Pumped approximately 1 gal of diesel to reach TBG test pressure of 3000 psi. Pumped approximately 86.3 gal of diesel to reach IA test pressure of 2000 psi. Total diesel used 87.3 gals. Started 1 hour monitor, 1st 30 minutes T & IA= 100/10 psi lost, 2nd 30 minutes 160/10 psi lost. Total pressure lost in 1 hour 260/20 psi. Slowly bled IAP from 1980 psi to 0+ psi in 45 minutes, during IA bleed TP decreased 470 psi. Monitored for 30 minutes. TP decreased 130 psi, IAP increased 10 psi._ Flowline pressure unchanged during job. Final WHPs= 2140/10/140. SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 2/9/2010;T/I/O= 2010/20/140. Temp= SI. WHPs (post MITs) [increased 10 psi, OAP unchanged. SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. TP decreased 130 psi, IAP 2/13/2010 ~ ****W ELL S/I ON ARRIVAL**** (post sealtite) PULLED 5 1/2"WRP FROM 72' SLM. ***WSR CONT ON 2 14/10'"*'` • 2/14/2010?T/I/O=SU50/130. Temp=S1. Hold open bleed on IA while Slickline pulls WRP (eval Sealtite repair). Bled IAP from 50 psi to 0 psi in 20 mins (gas/fluid). Maintained an ;open IA bleed during SL operations. Final T/I/O=SUO/130. **Job Complete** SL in control of well upon departure. 2/14/2010 2/15/2010 ***WSR CONT FROM 2/13/10"*" (post sealtite) ~~~~;RIG DOWN SWCP 6 *"*WELL S/I ON DEPT'`*" T/I/0=850/20/120. Temp=S1. T & IA FL's (pre-MIT's). T FL @ 120' (<10~bbls). IA FL near surface. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. .~~~_~a __ ____ -- ~---._ 2/15/2010;T/I/O=840/30/130. Temp=S1. Bleed TP (pre- MIT-T). Bleed TP to 610 psi, fluid to 1 surface. jSV,WV=C. SSV,MV=O. IA,OA=OTG. 2/15/2010 T/I/0= 600/20/120 Temp= SI MIT-T PASSED to 3000 psi CMIT TxIA PASSED to 2500 psi (AOGCC state witnessed by Chuck Scheve) Pressured up Tbg to 3000 psi with 3.5 bbls 60/40 MW. 1 st 15 min Tbg lost 70 psi, 2nd 15 min Tbg lost 55 psi, ;3rd 15 min Tbg lost 15 psi and 4th 15 min Tbg lost 10 psi with a total loss of 150 psi in 60 min test. Bumped up TBGP to 3000 psi to maintain 500 psi above IA while ;testing. State rep declined witness on CMIT TxIA. Pressured up T/ IA to 3000/2500 psi with 2.4 bbls 60/40 MW. 1st 15 min Tbg gained 250 psi, IA lost 30 psi, 2nd 15 mm Tbg lost 20 psi, IA lost 5 psi with a total loss of 35 psi loss in 30 min. Bled back [ IA first to 100 psi. Bled down Tbg next to 600 psi. Final W HP's= 600/100/100 "Operator notified of valves as SV,WV=closed, SSV,MV,IA and OA open on s 2/17/2010;***WELL S/I ON ARRIVAL*"* (post sealtite) 'PULLED PX PRONG FROM 11368' SLM ;PULLED 4 1/2" PX PLUG BODY FROM 11374' SLM (11364' MD) ~'~ **"*WELL S/I ON DEPARTURE.PAD OP VERIFIED VALVE POSITIONS**** FLUIDS PUMPED BBLS 9.5 meth 1.5 DIESEL 2.5 GALS. FLO-SEAL GEL 11 Total KB. EV = 64.10' BF. ELEV = ~ - 35.60' KOP = ~ 620' Max Angle = 98 @ 15164' Datum MD = 11624' Datum ND = 8800' SS ~ S-111 10-3/4" CSG, 45.5#, L-80 BTC, ID = 9.95" + 4708' Minimum ID = 3.813" @ 11320 4-1 /2" NES X NIPP<_E 4-1/2" TBG, 12.6#, L-80, TGII, 5431' .0152 bpf, ID = 3.958" 5-112" TBG, 17#, L-80, TGII 9516' .0232 bpf, ID = 4.892" 4-1/2" TBG, 12.6#, L-80, TGII, 9544' .0152 bpf, ID = 3.958" 5-1/2" TBG, 17#, L-80, TGII, I 11223" .0232 bpf, ID = 4.892" 4-1/2" TBG, 12.6#, L-80, TGII, .0152 bpf, ID = 3.958" WHIPSTOCK (05131/05) (-j 11535' EZSV (05/31/05, 11553' PERFORATION SUMMARY REF LOG: SLB MWD 10112/04 ANGLE AT TOP PERF: 66° @ 11534' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA 7-5/8" CSG, 29.7#, L-80, 12195' BTGM, .0459 bpf, ID = 6.875" SAFETY :WELL ANGLE > 70° @ 11635' { 26, ~- j 7" x 5-112" XO, ID = 4.892" I 2219' 5-112" HES X NIP, ID = 4.562 5403' 5-112" X 4-112" XO, ID = 3.938' GAS UFT MANDRELS. ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 5414 9527 3702 5815 58 68 KGB2 KGB2 *DMY *DMY BK BK 0 0 03/18/07 03/18!07 `NOTE 4-1/2" GLM IN 5-112" TBG **STATIONs 2 8 1 = DGLVs W/EXTENDED PACKING 5431' 4-1/2" X 5-1/2" XO, ID = 3.938" 9516' I-15-112" X 4-1/2 XO, ID = 3.938" 9544' I-I4-1/2" X 5-112" XO, ID = 3.938" 11223` -j5-1/2" X 4-112" XO, ID = 3.938" 11320` 4-1 /2" HES X NiP, ID = 3.813" 11341' 7-5/8" X 4-i/2" BKR S-3 PKR, ID = 3.875" 11364' 4-112" HES X NIP, ID = 3.813" 11385` 4-1/2" HES X NIP, ID = 3.813 11387' 7-5/8" X 5-1/2" BKR HRD ZXP LTP, ID = 5.580' 11398' 4-1/2" WLEG, ID = 3.958" 11409` 7-5/8" X 5-1/2" BKR FLEX LOCK HGR, ID = 4.830" MILLOUT WINDOW (S-111} 11535' - 11545' 11792' RA TAG (MIDDLE OF PUP JOINT) 16791' RA TAG (MLLE OF PUP JOINT) 17100` 4-112" BKR CIBP (09(14/08) ~ PBTD 17956' 4-1(2" L NR, 12.6#, L-80, HY D 521, I 1$040' .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/08!05 N7ES ORIGINAL COMPLETION 08/24/09 JCM/PJC SET PX (08(03/09} 10/19/05 JGM/PJC PERFORATIONS 08/24109 ?/ PJC TBG CORRECTIONS 06!25/06 DTRlPJC GLV GO 41!10!07 JY/ PJC DRLG DRAFT CORRECTIONS 03/18/07 SWGPAG GLV GO 10/17/08 RRD/PJC PERFSI CIBP (09115-9116108) AURORA UNIT WELL: 5-111 PERMIT No: '2050510 API No: 50-029-23257-00 SEC 35, T12N, R12E, 783' FWL & 753' FNL BP Exploration (Alaska) ~,~~~ ~ ~ ~ ~ ~.t ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR AI.A58iA OII, A1~TD GAS 333 W. 7th AVENUE, SUITE 100 COZIT5ERQA'TI011T COMDIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ms. Patti Phillips Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 aa~~ v,~ ~ Re: Prudhoe Bay Field, Aurora Oil Pool, S-111 Sundry Number: 309-427 Dear Ms. Phillips: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount Chair DATED this ~~day of December, 2009 Encl. ~a~ STATE OF ALASKA ~i~r'~~ ~ ALAS~OIL AND GAS CONSERVATION COMMISS ~ti~ ~ APPLICATION FOR SUNDRY APPROVALS ~n aac ~s ~Rn ~~~g~a~9 n 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ pen ed~ ell Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ p Other ^~ Sp~C~":~`s "* ALTITE Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Time Extension ^ REPAIR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ ~ Exploratory ^ 205-0510 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23257-00-00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ S-111 9. Property Designation (Lease Number): 10. Field/Pool(s): , ADLO-028256 ~ PRUDHOE BAY Field /AURORA OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18090 ~ 6884.05 - 17955 - 6894.64 ~ 17100 9/14/08 NONE Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 31 111 31 111 Surtace 4678 10-3/4" 45.5# L-80 30 4708 30 3348 6890 4790 Intermediate Production 12169 7-5/8" 29.7# L-80 26 12195 26 6945 6890 4790 Liner 6653 4-1/2" 12.6# L-80 11387 18040 6772 6887 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" 12.6# L-80 11223-11397 see attached - - 5-1/2" 17# L-80 24 - 11223 Packers and SSSV Tvoe: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD and TVD (ft): 11341 6750 5-1/2" BAKER ZXP PACKER 11387 6772 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^/ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/1/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval Date: WINJ ^ GINJ ^ WAG ^~ ~ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patti Phillips Printed Name Patti Phillips Title pad Engineer Signature ~ Phone Date _ 564-4578 12/18/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O Plug Integrity ^ BOP Test ^ Mechanical Integrity Test Location Clearance ^ Other: ~. n;., i q, ;. yY~q H ~. Subsequent Form Required: /O r tJ0 G.~ ` / / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z ,~ Form 10-403 Revised 07/200 ~---- Submit in Duplicate S-111 205-051 DCOC ATTA/'_I.IMFWT • • Sw Name Operation Date Perf Operation Code ~Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-111 7/4/05 PER 16,180. 16,250. 6,864.87 6,866.41 S-111 7/4/05 PER 16,330. 16,450. 6,870.02 6,877.62 S-111 7/4/05 PER 16,550. 16,590. 6,888.83 6,894.34 S-111 7/4/05 PER 17,200. 17,300. 6,934.86 6,935.15 S-111 7/4/05 PER 17,520. 17,950. 6,929.83 6,895.11 S-111 10/18/05 PER 13,200. 13,215. 6,897.33 6,897.46 S-111 10/19/05 PER 11,550. 11,565. 6,841.08 6,846.79 S-111 9/14/08 BPS 11,354. 11,534. 6,756.4 6,834.91 S-111 9/15108 PER 11,672. 11,697. 6,884.56 6,892.07 S-111 9/15/08 PER 12,973. 12,998. 6,899.11 6,898.74 S-111 9/15/08 PER 14,537. 14,562. 6,925.34 6,926.07 S-111 9/16/08 PER 11,602. 11,627. 6,860.93 6,869.9 S-111 9/16/08 RPF 11,534. 11,559. 6,834.91 6,844.47 S-111 8/3/09 BPS 11,354. 17,200. 6,756.4 6,934.86 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE To: Jerry Bixby /Clark Olsen Well Operations Team Leader From: Gerald Murphy /Taylor Wellman Well Integrity Projects Engineer Subject: S-111 i Tubing x IA Leak Sealtite Repair AUSPDWLI I Please perform the following procedure(s): Date: December 15, 2009 Est. Cost: $80M IOR: 800 Step Type Procedure 1. D Establish fluid level in T and IA. Bleed WHPs to 0 psi. 2. S Pull PX prong from plug at 11364'. Drive fluid level in tubing to 200' depth with lift gas. Reset PX prong. Set W RP at 100'. 3. D Load tubing.above plug with 10.3 ppg brine. Pump SealTite procedure. Allow to cure 5 days. 4. D MIT-T to 3000 psi 5. S Pull WRP at 100' Post Sealtite. DHD to be on location to hold open bleed on IA 6. F AOGCC MIT-T to 3000 psi, CMIT-TxIA to 3000 psi 7. SP Pull PX Plug 10-403 is required Status: SI after swapping to M-1 on 11/08/08 due to T x IA communication Last injection: 9300 BWPD on 07/27/09 Max Deviation: 62 ° C 11390' MD, 98° C~1 15,164 MD Min ID: 3.813"@ 11,320', 4-1/2" HES X Nipple Last Tag: 12,564' MD on 10/28/07 Last Downhole Op: Set PX Plug ~ 11364' SLM on 8/03/09 Latest H2S Value: No data available Tie in Logs: SLB MWD 10/12/04, LDL run 11/23/08. Objective: The objective of this wellwork is to repair confirmed TxIA communication in the tubing below the wellhead and restore well Integrity for PWI using Seal-Tite Sealant. A TecWel LDL was run on 11/24/08 and confirmed the leak =/- 2' below the tubing hanger. Recent Events• Well S-111 i is a produced water injector, that was about to begin its second injection with M-I when TxIA communication was observed. The well was then shut-in. This well was completed in 7/08/05 and had a RWO on 11/22/86. • • This well was has been on PWI for all but 1 month of its injection history. The well was on M-I injection for 1 month begin in December of 2006. When the second swap to M-I took place, IA pressure was seen tracking with the tubing pressure. Initial investigation showed the IA pressure would not bleed below 80 psi. A WRP is needed to hold the pressure differential to get a passing MIT-T to 3000 psi for the Seal-Tite work and to act as a platform for the 10.3 ppg brine to be spotted in the wellbore and keep it from swapping with current wellbore fluids. Please contact Gerald Murphy /Taylor Wellman at 659-5098 or Harmony 2418. cc: Well File History This well has a leak in the 7" x 5 ~/z" crossover or in the 5'/z" production tubing, identified via a TecWel log at +- 2' below the base of the tubing hanger. Recent Well Event Highlights 05/08/07: Operator call in high IAP; will not stay bled -advised to shut in 05/13/07: AOGCC MITIA Passed to 3000 psi 07/17/07: AA 2X.003 approved for water only 02/13/08: Caliper 4.5" & 5.5" TBG: All 275 jts< 14% 11/25/08: Memory LDL on MI, leak near tubing hanger 04/30/09: AOGCC MIT-IA Passed to 2500 psi 07/24/09: Operator called in high IAP after increased injection 07/27/09: MIT-IA Failed, LLR too small for FB( est ~0.1 gpm @ 3000 psi) 08/03/09: Set TTP @ 11364', MITIA Failed, CMIT-TxIA Passed to 3000 psi 11/27/09: PPPOT-T Passed to 5000 psi 11/28/09 MIT-T Failed, LLR ~0 .45 gpm, MIT-IA Passed to 3000 psi w/ LLR ~.55 gpm S-111 LDL Log (11/25/2008) 0 7me &+®49 OVrrx0 -3011 0 'JVL6~1t 120060 1060 CCL •106 0 WLD•@ 920000 ZO Temperalura fde~) 220 0 ~N10-G 120060 • Operational Steps Prior to Seal-Tite Technician Arrival: DHD 1. Establish fluid levels in tubing and IA. Bleed WHPs to zero. Slickline - Coordinate to have DHD w/ Echometer on site to shoot fluid levels 2. Pull PX prong from plug at 11364'. Allow fluid to fall, or drive fluid level down in tubing to 200' measured depth with lift gas if required. a. Utilize DHD to shoot fluid level in tubing to determine depth. b. Reset PX prong in plug. 3. Set WRP at 100'. DHD - Oder triplex to location - Coordinate with Well Support for Flat Bed Truck and MI for chemical tote. - Have 4 bbls of 10.3 ppg Calcium Chloride brine loaded into chemical tote. 4. Load tubing with 10.3 ppg CaCI brine (freezing point at -22 deg F). If required, 10.8 ppg CaCI brine has a freeze point at -51 deg F, if required. a. If WRP was set at 100', fluid loading should be ~3 bbls above WRP. b. Establish LLR with brine. Seal-Tite and DHD 5. Rig up SealTite pump to tubing and pump according to the attached Seal-Tite program included with this document. a. Once the leak has been sealed, allow sealant to cure 5 days. DHD Post Seal-Tite 6. MIT-T to 3000 psi with diesel a. If Fails -Establish LLR Slickline and DHD 7. Upon a passing MIT-T, slickline to pull WRP set in step 3 while DHD is holding an open bleed on the IA Fullbore 8. Perform AOGCC MIT-T and MIT-IA to 3000 psi. a. Insure IA pressure is never allowed to become greater than the tubing pressure, due to the potential to displace the plugging agent. Slickline 9. Pull PX Plug from 11,364'. Operations 10. Resume injection with the WIC/WIE monitoring the TIO plot for communication. • • Seal-Tite International Advanced Sealant Technology Proposed Procedure BP Alaska, S-111 Tubing Leak Repair December 15, 2009 Seal-rite International 500 Deer Cross Drive Madisonville, I.A 70447 Telephone:985-875-1292 Facsimile: 985-875-0687 http: //www.seal-tite.net Objectives Repair Tubing / IA Communication and restore well Integrity using Seal-Tite Sealants and Procedures Mechanical Considerations This well has an apparent leak in the 7" x 5'/z" production tubing crossover, identified via a TecWel log at +- 2' below the base of the tubing hanger. The recorded liquid leak rate from previous diagnostics is approximately 0.5 gpm at 3000 psi. The objective of this repair is to allow the well to return to PWI service. Tubing - 5'h" 17 Ib/ft, 0.0232 bbls/ft = 0.975 gallons per ft Intended Repair Procedure 1. Meet with field personnel; travel to location and verify well condition. 2. Perform Job Safety Analysis with all concerned personnel. 3. Take pressure readings as follows: - Tubing - IA - OA 4. DHD crew to establish fluid levels in the Tubing and IA. 5. R/U slickline. Pull the PX prong from the plug at 11364'. 6. DHD crew to confirm fluid level in tubing with Echometer. If deeper than 200', refill with 60/40 methanol to bring the fluid level back to approximately 200'. 7. Route lift gas to the tree and push the fluid level. down to +- 200', if required. 8. slickline to reset prong in plug at 11,364'. 9. Set a W RP as close as feasible below the leak location. Estimated setting depth is 100' below tubing hanger, in the middle of the 3rd tubing joint. R/D slickline. u U 10. R/U pump on tree cap and fill tubing above plug w/ with sufficient 10.3 ppg CaCl2 to put fluid level just below leak (freeze point of 10.3 CaCl2 is -22 F). Assume plug setting depth of 100' below tubing hanger, +- 95 gallons of brine. 11. Bleed IA to zero and route to tank to monitor returns. 12. Blend +- 20 gallons of water based sealant (Flo-Seal) and use a Fireball pump to push sealant into the tree and tubing. The water-based sealant will float on the brine and fill up across the leak site. 13. Increase squeeze pressure until a seal is obtained at 1000 psi. Monitor IA returns to ensure no further communication. Allow seal to cure for 1 hour. 14. If desired, switch to diesel for remaining pressure steps. Compression of 100 gallons brine below the leak is +- 0.35 gallons per 1000 psi = 0.35 ft per 1000 psi. 15. Increase squeeze pressure to 1500 psi. Allow seal to cure for 1 hour. 16. Increase squeeze pressure to 2000 psi. Allow seal to cure for 1 hour. 17. Increase squeeze pressure to 2000 psi. Allow seal to cure for 1 hour. 18. Increase squeeze pressure to 2500 psi. Allow seal to cure for 1 hour. 19. Increase squeeze pressure to 3000 psi. Allow seal to cure for 1 hour. 20. Continue to maximum pressure that will be used for PWI plus an additional 500 psi. 21. Allow seal to cure for 12 hours or overnight. 22. Reduce squeeze pressure to 2000 psi and lock in. Allow to cure for 5 days. 23. DHD MIT tubing to 3000 psi. 24. Bleed pressure to zero. 25. R/U slickline and pull WRP. DHD to be on location to hold open bleed on IA. R/D slickline. 26. Fullbore to perform AOGCC witnessed MIT-T and CMIT-TxIA to 3000 psi. 27. R/U slickline and pull TTP at 11,364'. 28. Return well to normal PWI. DNC 12/15/09 h:6.ELEV = _ di~A.iC! ~~. ELE1,'. ~ ... ai ~. k~ ~ , . ia2t7 >h9x At~tt~ ~ X38 ~ t ~} ~,q, ~. ~3,~rri IA0 - t i a~A' ____ __ , aaal~r,rra - I?~~a~ ~~ SAf~TY :WELLAF~..E>70'~ tiB35' . 4s:sa1, >..--~o etc, D ~ 9.95• H ~0~' ~11'llrt'i 11 rTl ~~ = ~.~ "~ ~ ~` t t ~z~} ~-'~~~" ~~$~ ~ ~~P~~E 4-1J2" 1`9C3, t2.fifC, L~ltl, TG I, .}l152 tsg~", ~ x.3.958' 543t' 5-#!~" TgCi, f7#, L-80,1~G1, .6232 t~;at, !l7 =~ 9.8'92' ~5~t6' ~-t.'z' T9C3, 12, 2.-~9t5, T+~1, 9~1A~' 5-12' Tom. 17~f, L-SdS, 7D-1, .€t232 cspf, ~ ~ 4.8.92' tt~23' ~j' '--IT x 5-1fF' 1CQ. ~ ~ 4~~9Z' 22t9~` 5-12' r~5x f,~ ~ X4:562 r;~s ~ ~ r -aa,,~aa~ :3T 1~ 7~'D O8/ TYRE `d L'1 LATC~i ! C1~AT~ 2 1 5414 952 371 ~ 58}S 68 K~92 K~~BT `Dl~f $~ Q 0 t53J18tC}T (~itt#1~}1 "PRtt t: 4-E1LE CaLdA W .'D~3t1 t 6Li "~TAT14Ms 2 ~ 1 ~ C3DLYs 1N~EXT PACI9NG Wit' ~4-~t1" !t'5-t12' J{a-, !] ~+ ~ e33$" 95t~i 5-112' %4-112 Jai, C? X3.938' t;t~P a-ia2!' x S-f I2' a~~ CII a ~_9 tt?23' H~ta~xa-try x~=~.i t t3~t' 7-5.'8' x ~I-1J2' ~# ~-3 ~ICI~, ~ ~ 3kt75'" t t35d' 1 t3$5° ~-112' F~5 x NP, ~ ~ 3.81' 9-112' t~5 X Nl-. ~? ~ 3.81:x' ATP. ~3 9-1;~ 1'8G, 12.6#P, Lam, TG 1, .G i 52 Lei . it) $ 3.958" ~ t 1536' ~ 1138' ~--~s-tr2"' '~ri.i_t3, ~ ~ 3.' ~ t tom` ~ X ~ 112" icX LG'~ FG R, D ~ 4~83U' 1~ LS51l1` ($-11 t} } 1 ~~' - 11545` t 4792' ~ TAf3 ~ ~F JC?Nf - tTt~!' H9-112' rr~~ s FIEF LCt~3: $L9 NIVIfC? fE};f21W AhK3LEAT T~ F'EF~: 66° 11534` trtfiz: infer td f?t~dut3an Cr3 fcx tN~4t5t4C~ ~ this StZf= 5PF 'I=#7~AL OS~ I]AT~ SEEPa4C~ 2 ~`~ "~L'1N DAl`A C5~3, 29.7, L-8Q 4 A~159 C¢t, ~ ~ 6..875' m 3.958' A t 1h'ELL. S~ 111 #~~#AT hb: ~5+tk1(! ARI NtE: 5t3~t32s~2323~i~=d34 T121~i, ft12£, 7;~# F'~'L b 753' i brat7at {Aiest~aj ~mmaaa~~~~va - ~ ~ _ _ ~ oco~o~-~ eursn,a~e, ~ -~ + Q ~pp ~' ~ ~ ~7i, ~; ~ ~ ~,Q y S -111 (PTD #2050510) Plans for sealant repair and future UIC MITs Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWellintegrityEngineer @BP.coml Sent: Friday, December 18, 2009 11:06 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; Murphy, Gerald L; Wellman, Taylor T Subject: S -111 (PTD #2050510) Plans for sealant repair and future UIC MITs Attachments: S- 111.pdf Hi Tom and Jim, A sealant repair is being planned for well S -111 (PTD #2050510) to mitigate the TxIA communication. A 10 -403 is being sent next week. Given the sealant will be applied down the tubing and cured as it crosses a pressure drop from the tubing into the IA, plans are to confirm integrity by conducting a MIT -T, then holding pressure on the tubing while pressuring up the IA effectively conducting a CMIT -TxIA. If the sealant treatment is successful, the plan is to apply for Administrative Approval to conduct a MIT -T and CMIT -TxIA instead of a MIT -IA for UIC compliance. Please let us know if you have any questions or concerns regarding this approach. A wellbore schematic has been included for reference. <<S -111. pdf>> Thank you, Anna (Du6e, T.E. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 I I f 12/21/2010 NOT OPERABLE: S -111 (PTD #2050510) TxIA communication Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Monday, July 27, 2009 10:22 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: NOT OPERABLE: S -111 (PTD #2050510) TxIA communication All, Well S -111 (PTD #2050510) is exhibiting IA repressurization and failed a subsequent MITIA. The well has been reclassified as Not Operable. The well will be secured with a downhole plug and remain shut -in until repaired. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, July 27, 2009 1:38 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2 /WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; NSU, ADW Well Operations Supervisor; GPB, Well Pad SW; Collins, Patrick J; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S -111 (PTD #2050510) Increased rate of IA repressurization All, Well S -111 (PTD #2050510) was bled on 7/25 after the IA pressure was found to be near tubing pressure. A monitor the following day showed the IA pressure back up to 1950 psi. The well has been reclassified as Under Evaluation. The plan forward is to leave the well on injection to investigate the communication with an MITIA this afternoon. If the well fails the MITIA, it will be immediately shut -in and secured with a downhole plug. A TIO plot and wellbore schematic have been included for reference. << File: S -111 TIO Plot.doc >> « File: S- 111.pdf >> Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 12/21/2010 S -111 (PTD #2050510) TIO Plot 4.404 .... ... ............................... ................. ' I. 3A00 0 T6g 2,000 —A— OA ■ OOA —� - OOOA IR, On i i • � I i 05/02/09 05/09/09 05/16/09 05/23109 05/30/09 46 /06J09 06/13/09 06/20/09 06/27/09 07/IM /09 07/11/09 07/12/09 07/25109 I I • • June 25, 2009 .~ f. r-~ e~ e ~~ ~ ~~a ~~ ~~~~~` Mr. Tom Maunder ,IUL ~ ~, 2009 Alaska Oil and Gas Conservation Commission ~~,~~~~~ ~~~ ~<, ~~;~ ~~~c~ ~~~r~i~si~~ 333 West 7th Avenue ~an~~~~~~ c~~ Anchorage, Alaska 99501 ~Wr~~~ Subject: Corrosion Inhibitor Treatments of S-Pad ~~ ~` ~~'~'~ Dear Mr. Maunder, 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 name, 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, ~;~;'~~, ~~ ~UL E_ ~ 2~~!~ Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corcosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) &pad ~ ns*e ~n~i~nna Well Name PTD S Initial top of cemeni Vol. of cement um ed Final top of cement Cement top off tlate Cortosion inhibitor Corrosion inhibirod seaiant date ft bbls it ~a al 5-016 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 5-04 7830790 0 NA 0 NA 0.9 5/25/2009 S-o5A 1951890 0 NA 0 NA 0.9 5/26/2009 5~06 1821650 0 NA 0 NA 0.9 5/26I2009 S-o7A 1920980 0 NA 0 NA 0.9 5/262~9 S-088 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-118 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-12A 1851930 0.25 NA 025 NA 1.7 6/1l2009 S-~3 1821350 8 NA 8 NA 55.3 6/7I2009 S•15 1840170 0.25 NA 0.25 NA 3 6/2I2009 S-17C 2020070 025 NA 0.25 NA 2.6 6!1l2009 S-18A 2021630 0.5 NA 0.5 NA 3 6!2/2009 5-19 7861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2070450 025 NA 0.25 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 7970510 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 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 7900660 0.5 NA 0.5 NA 5.~ 5/31/2009 S-3iA 1982200 0.5 NA 0.5 NA 3.a 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S-35 1921480 0 NA 0 NA .BS in 5/31/2009 S-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 5-37 7920990 125 NA 125 NA 77.9 5/27/2009 5-38 1921270 0.25 NA 025 NA 702 5/27/2009 S-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 5-43 1970530 0.5 NA D.5 NA 7.7 5/2&2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 S~t00 2000780 2 NA 2 NA 21.3 5/29/2009 S-1a7 2001150 125 NA 125 NA 11.9 5/29/2009 5-102L1 2031560 125 NA 125 NA 11.7 5/31Y2009 5-103 2001660 1.5 NA 1.5 NA 11.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-tos 2010120 16.25 NA 76.25 NA 174.3 6J2/2009 S-107 2011130 2.25 NA 225 NA 28.9 5/18/2009 S-708 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 S-t70 2011290 11J5 NA 11.75 NA 98.6 5/30/2009 S-i t t 20.50510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/78/2009 S-7taA 2021980 125 NA 125 NA 10.2 5/30/2009 S-tts 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 13.6 5/28J2009 5-777 2030120 1.5 NA 1.5 NA 75.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28/2009 5-119 2041620 1 NA 1 NA 52 5/30/2009 5-~20 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26J2009 5-124 2061360 1.75 NA 1.75 NA 17.9 5/26/2009 5-125 2070830 2.25 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 1.25 NA 15.3 6/1/2~9 S-2oo 1972390 1.25 NA 125 NA 1a.5 5/28/2009 S-207 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2001970 4.75 NA 4.)5 NA 51 5/29/2009 5-277 2070950 025 NA 0.25 NA ~.7 6/112009 S-400 2070740 2 NA 2 NA 9.4 5/2B/2009 S•401 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 • MEMORANDUM TO: Jim Regg P.I. Supervisor ~~~~ '~f ~ I FROM: BOb NOble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 04, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-11 I PRUDHOE BAY UN AURO S-] 11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: PRUDHOE BAY UN AURO 5-111 Insp Num: mitRCN090430141617 Rel Insp Num: API Well Number: 50-029-23257-00-00 Permit Number: 20s-051-0 ~ Inspector Name: Bob Noble Inspection Date: 4/30/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-IU ' TypeInj. ~' TVD 6~so IA Ilso zslo za7o zaso zaao P.T.D 2ososlo TypeTest SPT Test psi zslo OA s6o ~o0 690 6so 6so Interval REQvAR P/F P / Tubing Isao lsao lgao lsao lsao Notes: Monday, May 04, 2009 Page 1 of 1 -~ tla PROACTIVE DAAGNOSTIC SEevicES~ Ilvc_ • • V 1f~~~ ~~~.7 To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 J Leak Detection - WLD 23-Nov 08 S-111 2) Signed Print Name: 1 BL / EDE 50-029-23257-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)2458952 E-MAIL : ;~ t ':3;^ ~ >, .. ~ WEBSITE : ~_:_ _..~;_ ~~ C'',Docurnents and Sethngs\Diane Williams~Desktop\Transnut_I3P-docx OPERABLE: 5-111 (PTD #2050510) Returned to PW Injection Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, November 29, 2008 8:46 AM ~~~°( ~ z~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Wells Slickline Scheduler; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Cismoski, Doug A; Oakley, Ray (PRA) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: S-111 (PTD #2050510) Returned to PW Injection All, Well S-111 (PTD # 2050510) was logged while on MI on 11/25108. The well was shut in on 11/26/08 and has been swapped back to PW Infection as outlined in A1022C.003. This log should aid us in designing a patch to return the well to Ml service. ----, Please contact me if there are any questions. Thank you, ~ ~ ~' , ~ ,r Taylor Wellman filNng in for Anna DubelAndrea Hughes ~~~"~~ `~ ~~ °~~~ ... ~ ~~~~ Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, November 22, 2008 8:41 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Wells Slickline Scheduler; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Cismoski, Doug A; Oakley, Ray (PRA) Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: 5-111 (PTD #2050510) Place on MI while logging All, Well 5-111 (PTD 2050510} has been reclassified as Under Evaluation to allow for logging while on MI injection. Slickline will be on the well shortly to pull the SSSV. While Slickline is on location, a DHD crew member will also come to location to help manage the IA pressure before the well is swapped to MI. Once the well is swapped to Mi, a leak detection lag will be conducted. As soon as the log is complete, the well will be swapped back to produced water injection, DHD will remain an location until the welt is swapped back to water. Please let me know if you have any questions. Thank you, ,Anna tDu6e, ~? E. Wail Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 12/24/2008 OPERABLE: 5-111 (PTD #2050510) Returned to PW Injection Page 2 of 2 • From: NSU, ADW Well Integrity Engineer Sent: Friday, October 17, 2008 12:46 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: Cismoski, Doug A; NSU, ADW Well Integrity Engineer; Oakley, Ray (PRA); NSU, ADW Well Operations Supervisor Subject: S-111 (PTD #2050510) Place on MI while logging Jim, S-111 (PTD #2050510) is currently limited to water injection per 2X.003 due to observed IA repressurization while on MI injection. Our plan is to repair the well to enable MI service, but first the leak must be found. As the well passes MIT-IA's to liquid, we would like to swap the well to MI during our logging operation. As soon as the log is complete, the well will be swapped back to produced water injection until the patch can be designed and set. Please let me know if this plan poses a problem or further questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 12/24/2008 UNDER EVALUATION: 5-111 (PTD #2050510) Place on MI while loggin Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, November 22, 2008 8:41 PM Page 1~ ~ ~~~ ~' i~I2~( To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Wells Slickline Scheduler; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Cismoski, Doug A; Oakley, Ray (PRA) Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: S-111 (PTD #2050510) Place on MI while logging All, Well S-111 {PTD 2050510) has been reclassified as Under Evaluation to allow for logging,while on MI injection. Slickline will be on the well shortly to pull the SSSV. While slickline is on location, a DHD crew member will also come to location to ~ help manage the IA pressure before the well is swapped to MI. Once the well is swapped to MI, a leak detection log will be conducted. As soon as the log is complete, the well will be swapped back to produced water injection. DHD will remain on location until the well is swapped back to water. Please let me knout if you have any questions. Thank you, Anna ~Du6e, ~? E. Weft Integrity Coordinator GPB Wens Group Phone: {907) 659-5102 Pager: {907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, October 17, 2008 12:46 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: Cismoski, Doug A; NSU, ADW Well Integrity Engineer; Oakley, Ray (PRA); NSU, ADW Well Operations Supervisor Subject: 5-111 (PTD #2050510) Place on MI while logging Jim, S-111 (PTD #2050510) is currently limited to water injection per 2X.003 due to observed IA repressurization while on MI injection. Our plan is to repair the well to enable MI service, but first the leak must be found. As the well passes MIT-IA's to liquid, we would like to swap the well to MI during our logging operation. As soon as the log is complete, the well will be swapped back to produced water injection until the patch can be designed and set. Please let me know if this plan poses a problem or further questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /24/2008 y STATE OF ALASKA ~~~ ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS r~ ,_ ~'~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ - Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension 0 Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 205-0510 , 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23257-00-00 P 7. KB Elevation (ft): 9. Well Name and Number: 64.4 KB - PBU S-111 8. Property Designation: 10. Field/Pool(s): ADLO-028256 - PRUDHOE BAY Field/ AURORA OIL Pool 11. Present Well Condition Summary: Total Depth measured 18090 , feet Plugs (measured) 17100 9/14/2008 true vertical 6884.05 ~ feet Junk (measured) None Effective Depth measured 17955 - feet true vertical 6894.64 - feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 31 - 111 31 - 111 SURFACE 4678 10-3/4" 45.5# L-80 30 - 4708 30 - 3348 5210 2480 PRODUCTION 12169 7-5/8" 29.7# L-80 26 - 12195 26 - 6945 6890 4790 LINER 6653 4-1 /2" 12.6# L-80 11387 - 18040 6772 - 6887 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ ~ , `; ~"~~~~~~' ~ ~, ~ ~ 20~~ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 24 - 11223 4-1/2" 12.6# L-80 11223 - 11397 Packers and SSSV (type and measured depth) 4-1 /2" Baker S-3 Perm Packer 11341 5-1/2" BAKER ZXP PACKER 11387 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 4730 2013 Subsequent to operation: 2374 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development `~''. Service ~" Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ _~ WINJ ~ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/24/2008 Form 10-404 R ised 04/2(~0~ r ' ~ ! ~ ~ - Submit Original Only ~~ ~ ~F4( t S-111 205-0510 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth B ase Tvd Depth Top Tvd Depth Base S-111 7/4/05 PER 16,180. _ _ 16,250. 6,864.87 6,866.41 S-111 7/4/05 ___ PER 16,330. ___ 16,450. __ _ 6,870.02 6,877.62 S-111 7/4/05 PER _ 16,550. 16,590. 6,888.83 6,894.34 S-111 7/4/05 PER 17,200. 17,300. _ 6,934.86 6,935.15 S-111 7/4/05 PER 17,520. 17,950. 6,929.83 6,895.11 S-111 10/18/05 PER 13,200. 13,215. 6,897.33 6,897.46 S-111 10/19/05 PER 11,550. 11,565. 6,841.08 6,846.79 S-111 9/14/08 BPS 17,100. 17,950. 6,935.37 __ 6,895.11 S-111 9/15/08 APF 11,672. ' 11,697. 6,884.56 6,892.07 S-111 9/15/08 APF 12,973. 12,998. 6,899.11 6,898.74 S-111 9/15/08 APF 14,537. ~/ 14,562. __ 6,925.34 6,926.07 S-111 9/16/08 APF 11,534. ' 11,559. 6,834.91 _ 6,844.47 S-111 9/16/08 APF 11,602. __ 11,627. _ 6,860.93 6,869.9 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED __ FCO FILL CLEAN OUT SPS _ SAND PLUG SET FIL FILL SQF __ SQUEEZE FAILED _ MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC _ STRADDLE PACK, CLOSED MLK MECHANICAL LEAK _ STO STRADDLE PACK, OPEN __ OH OPEN HOLE __ • • • ACTIVITYDATE 5-111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY 9/14/2008 ~`*WELL INJECTING ON ARRIVAL*** T/I/0=1250/1200/200 RIH WITH WELLTECTRACTOR-PGGT-CPST-HALLIBURTON 4 1/2" EZ DRILL CAST IRON BRIDGE PLUG. OD = 3.66", L=2.09'. SET EZ DRILL CIBP AT 17,100'., POOH AND PLACE WELL ON INJECTION @ 1500 PSI, INJECT FOR 1 HOUR AT A RATE OF 8600 BBUDAY, RATE STEADY FOR 1 HOUR. RIH WITH 25' 3-3/8" HSD. GUN MISFIRED, POOH. "'"`JOB CONTINUED ON 15-SEPT-2008*** 9/15/2008 "*JOB CONTINUED FROM 14-SEPTEMBER-2008*** RIH WITH WELLTEC TRACTOR/PGGT/WPSA/ATPS/3-3/8" HSD PJ FIRST GUN PERFORATE INTERVAL FROM 14537-14~~2' SECOND GUN PERFORATE INTERVAL FROM 12973-12998' .THIRD GUN PERFORATE INTERVAL FROM 1 1 672-1 1 697' RIG UP FOURTH GUN ***JOB CONTINUED ON 16-SEPT-2008*** 9/16/2008 *'`*JOB CONTINUED FROM 15-SEPTEMBER-2008'*~ RIH WITH WELLTEC TRACTOR/PGGT/WPSA/ATPS/3-3/8" HSD PJ FOURTH GUN PERFORATE INTERVAL FROM 11602'-11627'. FIFTH GUN RUN WITHOUT WELLTEC TRACTOR AND PERFORATED INTERVAL 11534'- 11559'; WELL LEFT SHUT IN ON DEPARTURE. VALVE POSITIONS LEFT AS FOUND AND VERIFIED WITH PAD OPERATOR UPON DEPARTURE. T/I/0=350/1200/200. ***JOB COMPLETED*** FLUIDS PUMPED BBLS 1 diesel 1 Total DATA SUBMITTAL COMPLIANCE REPORT Permit to Drill 2050510 Well Name/No. PRUDHOE BAY UN AURO S-111 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23257-00-00 MD 18090 TVD 6884 Completion Date 7/8/2005 Completion Status 1WINJ Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye '~ DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, MWD DIR/ GR/ RES/ PWD/ DEN/ NEW, MWD DIR / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~~ D Asc Directional Survey 0 18090 7/14/2005 '~D D Asc Directional Survey 0 12788 7/14/2005 PB 2 pt Directional Survey 0 18090 7!14!2005 ~t Directional Survey 0 12788 7/14/2005 PB 2 D Asc Directional Survey 0 12210 6/10/2005 PB 1 pt Asc Directional Survey 0 12210 6/10/2005 PB 1 L g Cement Evaluation 5 Col 1 4990 12000 Case 6/10/2005 Ultrasonic Cement Log/USIT/GR/CCL-Primary Depth Control g Injection Profile 5 Blu 1 11400 14000 6/23/2006 Mem Projection Profile PBMS/PIES/PFCS/X-Y ~~ Caliper 15-Apr-2006 'ED C Lis 15069 Induction/Resistivity 32 12209 Open 4/30/2007 PB1 LIS Veri, FET, ROP, GR, DRHO, NPHI wlGraphics PDS & TXT 15069 Neutron 2 Blu 110 12210 Open 4/30/2007 P61 MD Vision, Density, Neutron, CDR 24-May-2005', i 15069 Neutron 2 Blu 110 12210 Open 4/30!2007 PB1 TVD Vision, Density, Neutron, CDR 24-May-2005. D C Lis 15070 Induction/Resistivity 32 12788 Open 4/30/2007 PB2 LIS Veri, FET, ROP, DRHO, NPHI w/Graphics PDS & TXT 15070 Induction/Resistivity 25 Blu 110 12778 Open 4/30/2007 PB2 TVD Vision Service 6- Jun-2005 og 15070 Induction/Resistivity 25 Blu 110 12778 Open 4/30/2007 PB2 MD Vision Service 6- Jun-2005 • DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050510 Well Name/No. PRUDHOE BAY UN AURO S-111 Operator BP EXPLORATION (ALASKA) INC MD 18090 TVD 6884 Completion Date 7/8/2005 Completion Status 1WINJ Current Status WAGIN UIC Y D C Lis 15076 Induction/Resistivity 32 18089 Open 4/30/2007 LIS Veri, FET, ROP, GR, DRHO, NPHI w/Graphics PDS & TXT (~,e§ 15076 Induction/Resistivity 25 Blu 110 18090 Open 4/30/2007 MD Vision Service 1-Jul- 2005 je6g 15076 Induction/Resistivity 25 Blu 110 18090 Open 4/30/2007 TVD Vision Service 1-Jul- 2005 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Chips Received? ~! Formation Tops W N Analysis ti'7'1~ Received? Comments: API No. 50-029-23257-00-00 Compliance Reviewed By: 1f~1 Date: J 1 \ 1 ~ -a_ ~ ~ ~ ~ a 7 j4 1~ ~ I , ~ ~ ~ ~ ~ ~ , ~~ ~ ' ~ ~ ' ~ I ~ ! , "`` ` ~ ' SARAH PAL1N, GOVERNOR ~ ~ ~' ~ f ~ ~ ~? ~l -' ~~_; y ~ ' o~ ~ ~ ~ 333 W. 7th AVENUE, SUITE 100 ~T~+ p~ 1~T ~R ~~t*~ CD~SS~~l~ C® ANCHORAGE, ALASKA 99501-3539 ii is-7 s l` PHONE (907) 279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL AIO 2ZC.003 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~~~ JAN ~ ~ 2©08 RE: PBU S-111 (PTD 2050510) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 8 of Area Injection Order ("AIO") 22.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water .injection in the subject well. PBU 5-111 exhibits slow tubing by inner annulus communication. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU S-111. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU S-111 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in PBU 5-111 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform an MIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPXA shall limit the well's IA pressure to 2,000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 220.003 July 17, 2007 Page 2 of 2 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 7. The MIT anniversary date is Nlay 13, 2007. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated July 17, 2007. Jo rman Daniel T. Seamount, Jr. Cathy P Foerster ,,.,..„.,„ Commissioner Comm ssioner MEM®I~liIDLTM State of Alaska llaska OiI and Cas Conservation Commission DATE: Monday, May 2b, 200? TO. Jim Regg ~S'~'c' ~ J~(~ ~ SUB3ECT: Mechanical tntegrit Tests P.I. Supervisor ~ ( ~ ~ y BP E\PLORATION (ALASKA] IVC S-111 FROM: John Crisp PRLDHOE BAY li V AORO 5-11 I Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J ~~ - Comm Well Name: PRUDHOE BAY UPI AURO S-III API Well Number: 50-029-23257-00-00 Inspector Name: John Crisp Insp Num: mirJCr0705 1 8 1 048 1 0 Permit Number: 205-051-0 Inspection Date: ~~13~2007 Rel Insp Num: Packer - Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-i i I (Type Inj. •. w TVD r 6so IA z2o 3000 , z9ao ~~ z9ao i T ~ososlo ' snT ~ P.T.D~ - iTypeTest ~ i Test psi - - - -- i 3000 - OA i o ~~~ loo I _ _-- loo I loo ~ ~ - - Interval ~T~R P/F P ;/ Isso ~ Isso ~ Tubing~I _ - Isso ~ Isso NOtes' MIT La for A?. request _ Monday, May 21, 200? Page 1 of 1 a ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton AubertQadminstate.ak.us; t3ob Fieckenstein~adminstate.ak.us; Jim_Regg~dminstate.ak.us; Tom Mlaunder~adminstate.ak.us OPERATOR: 8P Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay 1 PBU / S pad DATE: 05/13/07 OPERATOR REP: Jack Winskwv AOGCC REP: John Crisp Packer Depth Pretest initial 15 Min. ~ Min. Well S-111 Type Inj. W TVD 6,750' TutK 1850 1850 1850 1850 Interval O P.T.D. 2050510 Type test P Test psi 3000 Casing 220 3000 2980 2980 P/F P Notes: AOGCC State witnessed MIT-W for AA regl~.st. OA 0 100 100 100 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA WeII Type Inj. TVD Tubing Interval P.T.D. Type test Test Casi P/F Notes: OA Well Type Inj. TVD Tut>i Interval P.T.D. Type test Test psi Cali P/F Notes: OA Well T Inj. TYD Tubing Interval P.T.D. Type test Test Casing P/F Notes: OA TYPE ItdJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey 6 = Ditferential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O = QUrer (describe in notes} MIT Report Form BFL 911!05 MR PBU 5-111 OS-13-07.zls Re: S-111 (PTD #2050510) IA repressurizati~ ~~~~ Subject: Re: 5-111 (PTD'#2050510) IA repressurization h From: James Regg <jmregg~a,admin.state.ak.us> ~~~ Date: Wed, 09 Ma~~ ?~)Q7 1 r):3>:50 -0800.. 'i`o: "NSU, ;~ll~~' ~~'ell Inic~~rit~~~ En~~it~~cr" <-ti~S[_1AD~~~~'~~'ell[ntc~rritvEn~in~er~~iiBP.com% C'C: Tom tilaundcr °~_tom illaundcr~~z'.admin.st~ite.ak.us== Thank you for the notice this morning. The Commission was notified 1/29/2007 about the TxIA communication and aware of BP's efforts to diagnose the communication while 5-111 was on MI injection. As discussed this morning, we agree. with swapping the well to PWI and monitoring for repressurization. The well may continue to operate on PWI while you prepare the admin approval request per AIO 22C, Rule 8. Re: bleeding to maintain pressure below 2000 psi; as I noted yesterday in an email, please remember that there are no annulus pressure allowances for injectors. Any indication of pressure communication in annulus of an injection well must be reported to the Commission and approval sought to allow the well to continue in operation. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim and Tom, Well 5-111 (PTD #2050510) is exhibiting indications of pressure communication between the tubing and IA while on MI injection. The field Operators have been bleeding the IA with increasing frequency over the last week to maintain a pressure below 2000 psi. The well was found to exhibit indications of TxIA communication in January, at which time DGLVs with extended packing were set. The well was then returned to MI service and evaluated. The current plan forward is to perform an MITIA and pursue a AA for PWI injection only. While we are pursuing the AA, we will place the well on PWI while monitoring the IA for repressurization. Attached is a TIO plot and wellbore schematic for reference. Please call with any questions. Thank you - */Jack L. Winslow (for Andrea Hughes)/* Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 «S-111 TIO.doc» «S-111.pdf» Jim Regg <jian re~~(cc;ad~r~in.staie.ak.us> Petroleum Engineer ', AOGCC 1 of 1 5/9/2007 10:43 AM • ~111a~ 4,000 _ - ------- - ~ -'~ '~ '~ TI 4' P~ Ot f -~- Tbg 3,000 2,000 1,000 0 StJ -E- IA -f- OA l • OOA -~- 400A I ~f~SS~ve_ ~t~-5~ bleeA~S ~...1,c~~,. ul~~ Sw~~r ~/~ !~1T TREE= 7-1116" CIW 11Vt1LHEAD = FMC ACTUATOR= LEO' KB. ELE1! = 64.10' BF. E~EV = 35.60, KOP = 620' Max Angle = 98 @ 15164` Datum MD = 11624' Datum TV D = 8800` SS 10-314" CSG, 45.5#, L-80 BTC, ID = 9.95" 4708° irtimurrt ID = 3.813" a~ 1132Q 4-1 d2" HES N NIPPLE 4-112" TBG, 12.6#; L-80, TGII; 5431_ .0152 bpfi, ID = 3.958" 5-1f2" TBG, 17#, L-80, TGII, 9516' .0232 bpf, ID = 3.958" 4-112" TBG, 12.6#, L-80, TGII. 9544" .D152 bpf, ID = 3.958" 5-112'° TBG, 17#, L-80, TGII, 11223' .D232 bpf, ID = 3.958„ 4-1(2" TBG, 12.6#, L-8D, TGII, 11398" .0152 bpf, ID = 3,958„ PERFORATION SUMMARY REF LOG: SLB MWD 10!12/04 ANGLE AT TOP PERF: 68° @ 11550 Note: Refsr to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3f8" 6 11550 - 11565 O 10f18f05 3-318" 6 13200 - 13215 O 10r`18i'05 3-3I8" 6 16180 - 16250 O 07/04;05 3-3f8°' 6 16330 - 16450 O 07r`04i'05 3-3t8" 6 16550 - 16590 O 07104;05 3-318" 6 17200 - 17300 O 07i04r'O:a 3-318" 6 17520 - 17950 O 071'04f05 L'UHIPSTOCK(05i31r05) (-~ 11535' EzsV (D5i311D5) I~ 11553' 7-5f8°' CSG, 29.7#, L-80, 12195' BTGM, .fl459 bpf, ID = 6.875" SAPRY 1VOTES: ***70 ° f-W GLE @ 11635 & HORIZONTAL @ 15358"*** 26' J- -~ 7" x 5-1/2" XO, ID = 4.892" 2219' S-112" HES X NIP, tD = 4.562 !5403' 5-112" X 4-1f2" XO: ID = 3.938' '' GA5 LIFT h1ANDRELS ST MD 11iD DEV TYPE VLV LATCH PORT DATE 2 1 5414 9527 3702 5815 58 68 KGB2 KGt32 'DMY `DMY BK BK 0 0 03118?07 03?18?07 "NUlk' 4-1/L" CiLM IN ~-'If2" f 13Ci **STATIONs 2 & 1 = [)GLVs WfIXTt]VDED PACKING 5431' 4-112" X 5-1f2" XO, ID = 3.93$" 5-1/2" X 4-1 f2 XO, ID = 3.938" 4-1 /2" X 5-112" XO, ID = 3.938" 11223' (- -~ 5-1?2" X 4-112" XO, 1D = 3.938" 11320' 4-1r2" HES X NIP, ID = 3.813" 11341' 7-5,'8" X 4-1i2" BKR S-3 PKR, ID = 3.875" 11364" 4-112" HES X NIP, ID = 3.813' 11385° 4-1f2" HES X NIP, ID = 3.$13" 11387' 7-5i8" X 5-112" BKR HRD ZXP LTP, ID = 5.580' 11398' 4-112" WLEG, ID = 3.958" 11409` 7-518" X 5-1;2" BKR FLEX LOCK HGR, ID = 4.83D" MILLOUT 1,NINDOW (3-11't) 11535' - 11545' 11792' RA TAG {MIDDLE OF PUP JOINT} 4-1,2" LNR, 12.6#, L-8D, HYD 521, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS... 07f48tt15 N7ES ORIGINAL COMPLETION 10119105 .1GMfPJC PERFQRATIONS ..._ 06/25106 DTRIPJC GLV C70 01l10f07 JYf PJC DRLG DRAFT CORRECTIONS 03/18107 SV^JCIPAG GLV Ci0 ~ RA TAG {tt11DDLE OF PUP JOINT) ~ PBTD ~--~ 17956' 1 / 1 Schlamberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4232 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Aurora Date BL coh. cn L-103-~ 11626079 INJECTION PROFILE V-121 L-214 11630464 40011949 USIT OH EDIT MWD/LWD 03127/07 03129107 1 1 S-111 40011960 OH EDIT MWDILWD 05125105 2 1 07/01105 2 1 - ~.-~~~ ....nnwvr.cwc rctGtlPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. __ v,,,, _ Petrotechnical Data Center LR2-1 ,` I ~ ' w- 900 E Benson Blvd. ~ ~ ¢ ~ ~ ~ `r 'y,~ Anchorage AK 99500-4254 ~~~ ~ ~ ~- .g c. l/ ~Ut1~ Date Delivered: r 1~~~ ._ -..~ ~ a , ,~3,. ~.~~d~VBB~u~~33w v a1.. I Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage,AK 99503-2838 ATTN: Beth Received 04!2710% ' t __ oalz s/o / i Schlam~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # v T L ~~~~ _L~~- ~ ~Z) / ~' Log Description NO. 4223 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CO L-213 ~ W-210 S-104 L-278 L 11649950 11626075 10563057 10913045 MEMORY (PROF USIT INJECTION PROFILE CEMENTIPERF EVALUATION ~ 03117107 03106107 05103/03 09104105 1 1 1 1 -218 5-111PB1 10913045 40011960 MDT OH EDIT MWDILWD 09104105 OS/2A/OS 2 1 1 5-111PB2 L-202 40011960 40012011 OH EDIT MWDILWD OH EDIT MWD/LWD 06106105 06117/05 2 2 1 1 L-202L1 L-202L2 40012011 40012011 OH EDIT MWD/LWD OH EDIT MWDILWD 06124/05 06129105 2 2 1 1 L-202L3 S-122 40012011 40012137 OH EDIT MWDILWD OH EDIT MWD/LWD 07/05105 08/17/05 2 2 1 1 S-122PB7 5-122P82 40012137 40012137 OH EDIT MWD/LWD OH EDIT MWD/LWD 08109/05 08174105 2 2 1 1 S-122P83 40012137 OH EDIT MWD/LWD 08175/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. p, 4"''zhi I~ yr f? '~"' r Petrotechnical Data Center LR2-1 Cd - - '~ 6.~ [3 ~-'.' `- 900 EBenson Blvd. Anchorage AK 99508-4254 y'p (yy~ (,a )~j~g~]' P"tY fQ ~ r1 L1JUI Date Delivered: r~ al ~' ~+ ~'c,GY1~ao ~myV~9EG ~~rfs~+'~~~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN. Beth Received ~~-: i RE: 5-111 (PTD #2050510) IA repressurization Subject: RE: 5-111 (PTD #2050510} IA repressurization Front: "NSU, ADW Well Integrity Engineer" <NSUABWWeIllntegrityEngineer@BP.com Date: Tue, 30 Jan 2007 10:45:44 -0900 Tv: "Young, Jim" <Jim.Young@bp.com>, "NSU, ADW Well Integrity Engineer" <NSUADWWelilntegrityEngineer@BP.com>, James Regg <jirrt regg~admin.state.al~_us>, "NSU, ADW Weil Operations Supervisor" <NSUADWWeIIUperatxonsSupervisar'a~,BP.com>, "Rassberg, R Steven" <Steven.Rosslxergbp.cotn>, Thomas Maunder <~ mauu~#e~rc~,admir~.state.~.us>, "GPB, Wells Opt Eng" <GFBWellsOptEng~a BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr~?u BP.com>, "GPB, GC2 OTL" <g~agE2otl@BP.cvm> CC: "NSU, ADW WI Tech" <NSUADWWITech@BP.com>, "D~rrck, George (l1r€ackie} M" <dengm@BP.com> Jimetal- You are absolutely right - my mistake. This well does fall under AIO 22.Our plan forward will be as follows, then: 1. WOE: Swap well to PWI 2. S: DGLV #1 & 2 with extended packing 3. F: MITIA to 3000 psi 4. WOE: Swap weN to M1 5. WIE: Evaluate for TxIA comm while on MI. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 From: Young, Jim Sent: Tuesday, January 30, 2007 10:27 AM To: NSU, ADW Well Integrity Engineer; 'James Regg; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Thomas Maunder'; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, GC2 OTL Cc: NSU, ADW WI Tech; Derrick, George (Mackie) M Subject: RE: S-111 (PTD #2050510) IA repressurization understood this well as being under AIO 22 for the Aurora Poo1...the rule you're referring to was written in 1986, so I guess we could use same clarification here. Thanks Jim RE: 5-111 (PTD #2050510) IA repressurization Rule 4 Monitoring the Tubing-Casing Annulus Pressure Variations (Source AIO 22)The tubing-casing annulus pressure and injection rate of each injection well must be checked at least weekly to confirm continued mechanical integrity. Rule 5 Demonstration of Tubing-Casing Annulus Mechanical IntegrityA schedule must be developed and coordinated with the Commission that ensures that the tubing-casing annulus for each injection well is pressure testedprior to initiating injection, following well workovers affecting mechanical integrity, and at least once every four years thereafter. From: NSU, ADW Well Integrity Engineer Sent: Tuesday, January 30, 2007 9:55 AM To: Young, Jim; NSU, ADW Well Integrity Engineer; 'James Regg'; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Thomas Maunder'; GPB, GC2 Area Mgr; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, GC2 OTL Cc: NSU, ADW WI Tech; Derrick, George (Mackie) M Subject: RE: S-111 (PTD #2050510) IA repressurization Jim - Per Area Injection Order 3 for the WOA, me must cease injection on this well due to rule 7. We're going to line up a Atate-witnessed MITIA while it is on water to confirm that is still does not communicate while on water, and we'll pursue the required AA from there. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 From: Young, Jim Sent: Tuesday, January 30, 2007 9:34 AM To: NSU, ADW Well Integrity Engineer; 'James Regg'; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Thomas Maunder'; GPB, GC2 Area Mgr; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, GC2 OTL Cc: NSU, ADW WI Tech; Derrick, George (Mackie) M Subject: RE: S-111 (PTD #2050510) IA repressurization Since the well is approved for water & shows integrity, I request that we allow the well to stay on water injection as it supports a significant amount of production. This is a new FOR pattern with significant reserves at stake so we will be pursuing options to eliminate the TxIA communication to allow Ml in the future. We recently had 2 live gas-lift valves in the well for a fill cleanout/flowback; they we're replaced with dummies, bu# I will request they. be re-run with extended packing. • ItE: S-III (PTD #200510) fA repressurization Thanks Jim Young From: NSU, ADW Well Integrity Engineer Sent: Monday, January 29, 2007 7:43 PM To: 'James Regg'; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; 'Thomas Maunder'; GPB, GC2 Area Mgr; GPB, Wells Opt Eng; GPB, Optimization Engr; Young, Jim; GPB, GC2 OTL Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Derrick, George (Mackie) M Subject: 5-111 (PTD #2050510) IA repressurization Hello Jim and Tom, Well S-111 (PTD #2050510) is exhibiting indications of pressure communication between the tubing and IA on MI injection. The Field Operator bled the IA from 2120 psi to 860 psi four days after bleeding the lA from 2600 psi to 1200 psi. Our plan forward is to swap this well to water and then to shut it in until such time as an AA for PWI only can be approved due to TxIA communication while on MI. Please note that the well does not exhibit TxIA communication when on PWI. a or`c~ S-111 Attached is a wellbore schematic for reference. Please call with any questions. Thank you - Jnck L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 -~ Y~ 4A :l `y ~~ '3~ ~~ TREE = 7-1116" CNV tNELLHEAD = FMC _.,.,.,m......~. ACTUATOR= - LEO' KB. ELEV = 64.10' µ~m BF. f3EV = m~ .m_ 35.60' xoQ = _ ~ szo' Max Angle = 98 @ 15164' DaturrF MD = 11624' Datum TV D = 8800' SS 10-314" CSG; 45.5#, L-80 BTC, ID = 9.95" 47a$' Minimum ID = 3.813" @ 11320 4-1 /2" HES XN NiPPLE 4-112" TBG, 12.6#, L-80, TGII, 5431` .0152 bpf, ID = 3.958" 5-112'° TBG, 17#, L-80, TGII, 9516` .0232 bpf, Ip = 3.958" .. . . 4-112" TBG, 12.6#, L-80 TGII, 954.4' .0152 bpf, ID = 3.958" 5-1J2" TBG, 17#, L-80, TGII, 11223' .0232 bpf, ID = 3.958„ 4-112" TBG, 12.6#, L-80, TGII, .0152 bpf; ID = 3.958" PERFORATION SUMMARY REF LOG: SLB MWD 10f12104 ANGLE AT TOP PERF: 68° C~ 11550 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 3-318" 6 11550 - 11565 O 10(1$105 3-318°` 6 13200 - 13215 O 10118(05 3-318" 6 16180 - 16250 O 07104105 3-3/8" 6 16330 - 16450 O 07104(05 3-3(8" 6 1655G - 16590 O 07104!05 3-3/8" 6 17200 - 17300 O 07!04(05 3-318" 6 17520 - 17950 O 07!04/05 WHIPSTOCK (45131105) 115$5' EZSV (05I31/05) 7-518" CSG, 29.7#, L-80, ~ 12195' BTGM, .0459 bpf, ID = 6.875" 11223' --15-112" X 4-112" XO, ID = 3.938" 1132x' 4-112°' HE5 K NIP, ID = 3.813" 11341' 7-518'° X 4-112" BKR S-3 PKR, iD = 3.875" 11364' 4-112°' HE5 X NIP, ID = 3.813" 11385' 4-112" HES X NIP, ID = 3.813" 113$7' 7-5/8" X 5-112" BKR HRD ZXP LTP, ID = 5.580' 11398' 4-1/2" WLEG, ID = 3.958°' 11409' 7-518" X 5-112" BKR FLEX LOCK HGR; ID = 4.830" MILLOUT WINDOW (S-111) 11535` - 11545' 11792' RA TAG (MIDDLE OF PUP JOINT} 16791' RA TAG (MIDDLE OF PUP JOINT) 4-11'2" LNR; 12.6#, L-80, HYD 521, .0152 bpf, ID = 3.958" DATE REV BY COMfv9ENT5 DATE REV BY t)7lQ8t05 N7E5 pR1GtNAL COMPLETtC3N 10119105 JGNi,-PJC PERFORATIONS 06/25106 DTFZ'PJC GLV GO 01!10107 JY? PJC DIZLG DRAFT CORRECTIONS COiV1MEMS PBTD I-I 17956' ~ 1 sa4a' ~ PRUDHOE BAY UNIT WELL: 5-111 PERMIT No. 2050510 API No: 50-029-23257-00 SEC 35, T11 N, R15E, 2352.57' FEL & 2465.03` FNL SP Exp{oration (Alaska) SA NOTES: ~**70 ° ANGLE @ 11635 & .~ `~ ~ HORIZONTAL @ 15358"*"` 26' 7" x 5-1 t2" XO, ID = 4.892" 2219' S-112" HES X NIP, iD = 4.562 5403' S-112" X 4-112" XO, ID = 3.938° GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 5414 9527 3702 5815 58 68 KGB2 KGB2 CMY CMY BK BK 0 0 Os/26/06 06/26/06 °NOTE: 4-1(L" LiLM IN 5-112" TBCi 5431" 4-112" X 5-112" XO, ID = 3.938" 9516' 5-112" X 4-112 XO, ID = 3.938" 9544' 4-1(2" X 5-1t2" XO, ID = 3.938" Scbqun~ergP.1' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 3862 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Date BL Color CD S-itt S-114A 11216189 10572082 MEMORY INJECTION PROFILE RST UPFLOW WFL Od/15/06 03!01!03 1 1 V-105 E•103 10663005 10560276 INJECTION PROFILE TEMPERATURE WARMBACK 03/12/04 06/22/03 1 1 V-214 11162720 UBI 11/24/05 1 V-213 11076450 INJECTION PROFILE 07101!03 1 V-216 V-221 M1107645f 11058523 INJECTION PROFILE INJECTION PROFILE 07/02/05 07!03105 1 1 L-103 NIA INJECTION PROFILE 07718109 1 W-209 W-207 11078461 10980569 INJECTION PROFILE INJECTION PROFILE 08/20/05 07120105 1 1 W-272 N/A INJECTION PROFILE 07119!05 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 Date Delivered: Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bv: A 1 ~1UN 2 3 ZD06 ilca ~'tl ~ has Cans. Ccmmissicn Ante 08!21!06 i_I •a ~~ 1~1JJ `J ab3 ~s~--- Sshlumherger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # a Log Description NO. 3680 Company: Alaska Oif & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Borealis Aurora Date BL Color CD 5-03 I 0 11057082 PERF/SBHP 01/03106 1 V-114A REVISED S-111 ~ 40009730 11058510 OH LDWG EDIT OF MWD/LWD USIT 12115/03 05/28105 1 1 L-123 10997558 USIT 01/01/06 1 V-114A PB1 40009730 OH LDWG EDIT OF MWD/LWD 11103/03 6 1 Y-114A P62 40009730 OH LDWG EDIT OF MWDlLWD 12/15!03 1 1 W-207 PB1 40008886 OH LDWG EDIT OF MWD/LWD 04/04/03 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 8P Exploration (Alaska)Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508.4254 Date Delivered: a~a~-I a~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth;//~p~-'/~~-~gr1 Received b~~ tt )V V V f~ ~ 02!73/06 STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COMMN REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ N0~ X005 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Atth~r (~, ,, q , (~3 I Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time E t rt~i L~J Change Approved Program [] Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well ~ Ai1Cht)C~~B 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~ 205-0510 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23257-00-00 7, KB Elevation (ft): 9. Well Name and Number: 64.4 KB S-111 8. Property Designation: 10. Field/Pool(s}: ADL-028256 Prudhoe Bay Field/ Aurora OII Pool 11. Present Well Condition Summary: Total Depth measured 18090 feet Plugs (measured) None true vertical 6884.05 feet Junk (measured} None Effective Depth measured 17955 feet true vertical 6894.64 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20"x30" 31 - 111 31 - 111 Surface 4678 10-3/4" 45.5# L-80 30 - 4708 30 - 3348.33 5210 2480 Production 12169 7-5/8" 29.7# L-80 26 - 12195 26 - 6945.24 6890 4790 Liner 6653 4-1/2" 12.6# L-80 11387 - 18040 6771.74 - 6887.25 8430 7500 Perforation depth: Measured depth: 11550 - 11565 13200 - 13215 16180 - 16250 16330 - 16450 16550 - 16590 17200 - 17300 17520 - 17950 True Vertical depth: 6841.08 - 6846.79 6897.33 - 6897.46 6864.87 - 6866.41 6870.02 - 6877.62 6888.83 - 6894.34 6934.86 - 6935.15 6929.83 - 6895.11 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 24 - 11223 4-1/2" 12.6# L-80 11223 - 11397 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Packer 11341 5-1/2" BAKER ZXP PACKER 11387 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 14557 1160 1469 Subsequent to operation: 0 0 17419 460 1447 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' Gas 1 ~;, WAG GINJ ~ WINJ ~. WDSPL 1-' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: NiA Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr Signa Phone 564-4424 Date 11/22/2005 ~'~~ Form 10-404 Revised 04/2004 r ~ ~ t ~ ~ ~ ~ /~ ~ Submit Original Only S-111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY A~CTIVtTYDi4TE $UhM1MARY 10/18/2005 Continued from 10/17!05 WSR. MU/RIH w/ PDS GR/CCL in 2.2" carrier w/ 3.4" JSN drift on bottom to 16050' .Log up at 40 fpm from 16050'- 11100' paint RED flag at 13150' and paint WHITE flag at 11500' - POH, verify good data, correct -10' - MU/RIH/SLB 3 3/8 -6SPF-2906PJ with PURE and Fast Gauge. Perf interval 13200 - 13215 with 3-3/8" - 6SPF. POH. MU/RIH w/ SLB' 3 3/8"-2906 PJ conventional gun w/ Fast Gauge. Continued on 10/19/05 WSR. 10119!2005 Continued from 10/18/05. In progress -RIH w/ SLB 3 3/8"-2906 PJ conventional gun w/ Fast Gauge. Tie-in to upper flag. Perf interval 11550' - 11565' with 3-3/8" - 6SPF. POOH. Lay down gun #2. Blow down reel w/ N2. RDMO. **** Job is complete.**** Ready to put on injection. FLUIDS PUMPED BBLS 62 Meoh 30 N2 92 TOTAL MEMORANDUM • To: Jim Regg ~/~,~ it ~~~DS P.I. Supervisor '"'~" FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 24, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-I I 1 PRUDHOE BAY i1N AURO 5-111 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv , Comm Well Name: PRUDHOE BAY UN AURO 5-111 Insp Num: mitCS051015170828 Rel Insp Num API Well Number 50-029-23257-00-40 Permit Number: 205-051-0 Inspector Name• Chuck Scheve Inspection Date: 10115!2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ sa a Type Inj. ~ `~' ~ TVD 67a9 I IA ~ 130o i aooo 400o aooo P.T. 2050510 'TypeTCSt, sPT ;Test psi I 1687.25 ~ OA 340 500 i 500 i 500 Interval INITAL p~ P TUbing I 1350 1350 1350 ` 1350 I ~ NOteS Pretest tubing and IA neaz equal, no indication of leak on 4000 psi 30 minute test. Monday, October 24, 2005 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~EGE1V~~ SEP 2 6 ZDQS Revised: 09!26!05 Put on Injectyion el~~l,~ nit ~ Ir>~ r_'~ Cemnut~me 1a, Weli Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 1b. Well Clas 20AAC 25.105 20AAC 25.110 s ^ Developmen ploratory ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other ^ Stratigraphic ®Service 2, Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 7/8!2005 205-051 3. Address; 6. Date Spudded 13, API Number P,O. Box 196612, Anchorage, Alaska 99519-6612 5/14/2005 50-029-23257-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4 ' ' 7/1/2005 PBU 5.1111 527 NSL, 4497 WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon; g, KB Elevation (ft): 15. Field /Pool(s): 2374' NSL, 714' WEL, SEC. 22, T12N, R12E, UM 64.4' Prudhoe Bay Field 1 Aurora Pool Total Depth: 9. Plug Back Depth (MD+ND) 391' NSL, 863' WEL, SEC. 16, T12N, R12E, UM 17956 + 6895 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ND) 16. Property Designation: Surtace: x- 618930 y- 5980730 Zone- ASP4 18090 + 6884 Ft ADL 028256 TPI: x- 617289 y- 5989112 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 611805 Y- 5992325 Zone- ASP4 {Nipple) 2219' MD - 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ®Yes ^ No NIA MSL 1900' (Approx.) 21. Logs Run: MWD DIR / GR, MWDDIR / GR /RES / PWD /DEN /NEU, MWDDIR / GR /RES / ABI /DEN /NEU, USIT 22. CASING, LINER AND EMENTING RECORD CASING ETTING EPTM MD ING EPTH TVD HALE. AMOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 29' 109' 29' 109' 42" 260 sx Arctic Set A rox. 10-314" 45.5# L-80 30' 4708' 30' 3348' 13-1/2" 719 sx AS Lite, 444 sx Class 'G' 7-5/8" 29.7# L-80 26' 11535' 26' 6835' 9-7/8" 96 sx LiteCrete, 331 sx Class 'G' 4-1/2" 12.6# L-80 11387' 18040' 6772' 6887' 6-3/4" 1128 sx Class 'G' 23. Perforations open to Produc tion (MD + N D of Top and ' " 24. TUBING RECOan Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf ~-1/z^, 17it X a-vz^, ,2.F#, L-ao 11398' 11341' MD TVD MD ND 16180' - 16250' 6865' - 6866' 16330' - 16450' 6870' - 6878' 25. ACfD, FRACTURE, CeMENT SQUEEZE, ETC. 16550' - 16590' 6889' - 6894' 17200' -17300' 6935' - 6935' DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 17520' - 17950' 6930' - 6895' 11553' Set EZSV 11535' et Whipstock for Kick Off from P61 2200' Freeze Protect with 88 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Method of Operation {Flowing, Gas Lift, etc.): September 23, 2005 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED E OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (coRR) Press. 24-HOUR RAT 27. CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ ~~ ~~~ ~ ~ 21145 None ~.~:~~ r ^q~ fy P I~ :~ Form 10-40f"T~71S~tT~"Z12003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD ND and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 5158' 3571' None Ugnu M Sands 7543' 4791' Schrader Bluff N Sands 7994' 5025' Schrader Bluff O Sands 8180' 5122' Base Schrader Bluff 1 Top Colville 8735` 5415' HRZ 11315' 6738' Kalubik 11519' 6829' Kuparuk C 11530' 6833' Kuparuk G 18045' 6887' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby cert'rfy that the fo egoing is true and correct to the best of my knowledge. r / Signed Terrie Hubble " f ~ Title Technical Assistant Date alp ~~ PBU S-1111 205-051 Prepared ey Name/Number.• Terrie Hubble, 564-4628 Well Number Drilling Engineer: DaveWes/ey, 564-5153 Permit No. / A royal No. INSTRUCTIONS Ger+eRA~: This form is designed for submitting a complete and con-ect well completion report and log on all types of lands and leases in Alaska. IreM 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. Irene 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 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. IreM 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). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 Submit Original Only ALASKA~AND GAS CONSERVATION COMIV~iON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~ ~ ~~~~ ~s~~lr~ ~;r ~. ,~..,_ ~ __ ~, 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned 20AAC25.105 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions p ^ Suspended ®WAG 20AAC25.110 One Other 1b. Well Clas : `" ' ' "~ `° ` tq•'a ^ Developni ht~ ~cploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/8/2005 12. Permit to Drill Number 205-051 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/14/2005 13. API Number 50-029-23257-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/1/2005 14. Well Name and Number: PBU S-111 i 4527 NSL, 4497 WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 2374' NSL, 714' WEL, SEC. 22, T12N, R12E, UM g, KB Elevation (ft): ~ 4' 15. Field /Pool(s): Prudhoe Bay Field /Aurora Pool Total Depth: 391' NSL, 863' WEL, SEC. 16, T12N, R12E, UM 9, Plug Back Depth (MD+TVD) 17956 + 6895 Ft 4b. Location of Well (State Base Piane Coordinates): Surface: x- 618930 y- 5980730 Zone- ASP 4 10. Total Depth (MD+TVD) 18090 + 6884 Ft 16. Property Designation: ADL 028256 _ TPI: x- 617289 y-_5989112 Zone-_ASP4 Total Depth; x- 611805 y- 5992325 Zone- ASP4 11. Depth where SSSV set (Nipple) 2219' MD 17. Land Use Permit: --"----~---~-'--- -~---------------- ------------------- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR, MWDDIR / GR /RES / PWD /DEN /NEU, MWDDIR / GR /RES / ABl /DEN /NEU, USIT 2. CASING, LINER AND CEMENTING RECORD CASING ETTING EPTH MD ETTINQ EPTH TVD .`HOLE OUNT SIZE' WT. PER FT. GRADE OP TTOM OP TTOM S¢E CEMENTING RECORD PULLED 20" 91.5# H-40 29' 109' 29' 109' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 30' 4708' 30' 3348' 13-1/2" 19 sx AS Lite, 444 sx Class 'G' 7-5/8" 29.7# L-80 26' 11535' 26' 6835' 9-7/8" 96 sx LiteCrete, 331 sx Class 'G' 4-1/2" 12.6# L-80 11387' 18040' 6772' 6887' 6-3/4" 1128 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. ` TUBING fECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf s-,/2°,,~s x a-,r2°, 12.61f, L-80 11398' 11341' MD TVD MD TVD 16180' - 16250' 6865' - 6866' 16330' - 16450' 6870' - 6878' Qrj, ACID, FRACTURE, CEMENT-SQUEEZE, ETC. 16550' - 16590' 6889' - 6894' 17200' - 17300' 6935' - 6935' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 17520' - 17950' 6930' - 6895' 11553' et EZSV 11535' et Whipstock for Kick Off from P61 2200' Freeze Protect with 88 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Not on Injection yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None C01'APLETSOd'~ RBDMS ~L AUG 16 203 .: FOrm 10-407 R2VISed 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29' MAT10N TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 5158' 3571' None Ugnu M Sands 7543' 4791' Schrader Bluff N Sands 7994' 5025' Schrader Bl ff O S d 818 ' ' $~ f F ' w ~ ~ u an s 0 5122 ~ ;, Base Schrader Bluff /Top Colville 8735' 5415' ~~~~7 ~ ~ ~~~~ HRZ 11315' 6738' ~c#~;8 ~Ia ~° ~ ~ :,, ,~ ^,~~: Kalubik i 1519` 6829' ~~~ `~ a w:~ : ~; Kuparuk C 11530' 6833' Kuparuk C 18045' 6887' 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 Hubbl Title Technical Assistant Date ~ ~ - I b-O PBU S-111 i 205-051 Prepared By Name/Number.• Terrie Hubble, 564-4828 Well Number Permit No. / A royal No. Dulling Engineer: Dave Wesley, 564-5153 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Frets 23: If this welt 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), IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 2T: If no cores taken, indicate "None°. IreM 29: List al! test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 7/11!2005 10:19:40 AM BP EXPLORATION ~"' '~~ ge 1 of 20 ~w ~ Operations Summary Report AL~G ~ ~ Z~O~ Legal Well Name: S-111 ~ ~ y.~ , ,iU_,; ~.,II ~:, .. ~ ~ ~'`''~ Common W ell Name: S-111 Sp~t17i~~'+~s~/15/2005 Event Nam e: DRILL+C OMPLE TE Start : 5/15/2005 End: Contractor Name: NABORS ALASK A DRI LLING I Rig Release: 7/812005 Rig Name: NABOR S 7ES Rig Number: Date ~~ From - To ~ ~ Hours ~~, Task ! Code I ~ NPT j Phase ~~ ~ Description of Operations ---____~ ----- -L --- ~ 5!11!2005 22:00 - 00:00 2.00 MOB P PRE Rig released from U-066 at 22:00. Wait for notification of completion of construction to cross Kuparuk River bridge w/rig. Mechanics inspecting gear ends of mud pumps. Rig down pit module and prepare for move. 5!12/2005 00:00 - 06:00 6.00 MOB P PRE Rig released from U-066 at 22:00. Wait for notification of completion of construction to cross Kuparuk River bridge w/rig. Lowered derrick. Rig down ancillary equipment. Blow down pit lines. Inspect mud system. 06:00 - 00:00 18.00 MOB P PRE Break down Kuskokwim camp prepare to move. Prepare Iliamna camp for move. 5/13/2005 00:00 - 06:00 6.00 MOB P PRE Move camps, truck shop and pits, to S pad. Kuskokwim camp rigged up on south side of S pad. 06:00 - 14:00 8.00 MOB P PRE Move rig to S-111 i. No problems when crossing the Kuparuk River bridge. 14:00 - 17:30 3.50 MOB P PRE Raise derrick, pull up cattle chute, bridle down. Rig up top drive. Rig up electrical hookups and test. 17:30 - 20:00 2.50 MOB P PRE Prep cellar, place wellhead equipment in cellar and hang diverter from overhead winches in cellar. 20:00 - 23:00 3.00 MOB P PRE Move sub over 20" conductor. 23:00 - 00:00 i.00 MOB P PRE Rig up. Spot pit module. Connect air, water, mud lines and electrical lines. 5114!2005 00:00 - 02:00 2.00 RIGU P PRE Rig up. Take on spud mud and water. Accept rig at 02:00. 02:00 - 06:00 4.00 RIGU P PRE Complete mud transfer. Load pipe shed with 5" drill pipe and 17 jts 5" HWDP. 06:00 - 11:00 5.00 RIGU P PRE Pick up 5" drill pipe and heavyweight drill pipe. Nipple up diverter. 11:00 - 12:00 1.00 DIVRTR P SURF Function test diverter. Witnessing of test waived by AOGCC Jeff Jones. 12:00 - 13:00 1.00 DRILL P SURF Rig up Gyrodata equipment and Sperry Sun wireline unit. 13:00 - 14:00 1.00 DIVRTR P SURF Fill diverter and riser, test lines to 3500 psi. 14:00 - 19:00 5.00 DRILL P SURF Pick up 2 drill collars, make up 13 112" bit and drill out ice in conductor, stand collars back in derrick. 19:00 - 21:00 2.00 DRILL P SURF Pick up mud motor with 1.83 deg bend, MW D, stabilizers and UBHO. Orient tool face. RIH to 110'. 21:00 - 22:30 1.50 DRILL P SURF Spud well @ 21:00. Drill from 110' to 302'. 450 gpm, 460 psi, 40 rpm. Up wt. = 50k, slackoff wt. = 50k, rotating wt. = 50k. 22:30 - 00:00 1.50 DRILL P SURF Pull BHA to add drilling jars and run in hole to 302'. Rot. hours = 1.32, jar hours = 1.32. 5115!2005 00:00 - 00:45 0.75 DRILL P SURF Drilling 13 1/2" hole from 302' to 348'. 450gpm, 672 psi., 38 rpm. WOB 4-5K. Torque off = 0, torque on = 3K. 00:45 - 02:45 2.00 DRILL P SURF Perform initial gyro survey with Gyrodata. Perform backup to initial survey by repeating with second tool. 1.01 deg. Inclination. 22.64 deg. Azimuth for initial and backup survey. 02:45 - 03:15 0.50 DRILL P SURF Directional drill from 348' to 450'. Kicked well off at 360'. Sliding 639 psi, 505 gpm, 0 rpm, 6k WOB. 03:15 - 06:00 2.75 DRILL P SURF Directional drill from 450' to 625'. Perform Gyrodata surveys as per program. 06:00 - 17:00 11.00 DRILL P SURF Dircectional drill from 625' to 1195'. Did not get needed dogleg angle of 3 deg./ 100 ft. Falling behind TVD dogleg with 100°1° sliding. 17:00 - 20:30 3.50 DRILL P SURF Pulled out of hole to check bit. Bit ok. Stabilizer gage ok. Motor bearings ok. Changed bit. Printed: 7/11/2005 10:19:48 AM BP EXPLORATION ,«~, Page 2 of 20 Operations Summary Report `- Legal Well Name: S-111 ~ :. ;~ ; _ Common Well Name: S-111 ~pud~Date: 5/1~F,5 Event Name: DRILL+COMPLETE Start: 5/15!2005 `End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/812005 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To ~ Hours ~ Task Code ~ NPT I Phase 5/15/2005 20:30 - 23:00 2.50 DRILL P SURF 23:00 - 00:00 1.00 DRILL P SURF 5/16/2005 00:00 - 04:00 4.00 DRILL P SURF 04:00 - 05:00 1.00 DRILL P SURF 05:00 - 12:00 7.00 DRILL P SURF 12:00 - 13:45 1.75 DRILL P SURF 13:45 - 16:45 3.00 DRILL P SURF 16:45 - 00:00 7.25 DRILL P SURF 5!17/2005 00:00 - 08:45 8.75 DRILL P SURF 08:45 - 09:30 0.75 DRILL P SURF 09:30 - 14:00 4.50 DRILL P SURF 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 15:00 0.50 DRILL P SURF 15:00 - 15:30 0.50 DRILL P SURF 15:30 - 18:30 3.00 DRILL P SURF 18:30 - 00:00 5.501 DRILL ~ P I SURF 8/2005 100:00 - 08:30 I 8.501 DRILL I P I I SURF 08:30 - 10:00 i.50 DRILL P SURF 10:00 - 11:30 1.50 DRILL P SURF 11:30 - 12:30 1.00 DRILL P SURF 12:30 - 15:00 2.50 DRILL P SURF 15:00 - 18:30 3.50 DRILL P SURF 18:30 - 20:30 2.00 DRILL P SURF 20:30 - 23:00 2.50 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 9/2005 00:00 - 07:45 7.75 CASE SURF Description of Operations Pick up additional 33 jts of drill pipe and stand back. Adjust motor angle from 1.83 deg. to 2.12 deg. Orient motor. Trip in hole. Directional drill 13 1/2" hole from 1191' to 1389'. 100% sliding. Pressure =1050, gpm = 553> Dn. 77K, weight on bit 1-30K, Up 80K Drilling very rough and GR log lost function for 20'. Magnetic interference occurring. Performing Gyrodata surveys at 100' intervals. Run check shot surveys with Gyro. MW D and gyro are within 1 deg azimuth and inclination is the same. Rig down Gyrodata and Sperry Sun E-line unit. Directional drill 13 1 /2" hole from 1359' to 1759'. 100°I° sliding. Pressure =1123, gpm = 541, Up 98K, Dn. 80K, Rot. = 90K. Weight on bit 1-30K. ADT = 6.17, AST = 3.27, ART = 2.90. Drill f/1759' to 1854'. POH to i 687'. Ream out dogleg f/1687' to 1854'. 550 gpm, 1300 psi, 40 rpm, Tq. 3-5K. Drill f/1854' to 2385' MD, 2149' TVD.Up = 100K, Dn. = 80K, rot. = 90K, Tq. on = 7K, rpm = 40, gpm = 550, psi = 1300. ADT = 6.02, ART = 2.37, AST = 3.65. Drill surface hole from 2385' to 3264'. TVD 2632'. Up wt. 115K, Down wt. 75K, Rot. wt. 95K. Pressure on 1800, pressure off 1600. Gpm 600, rpm 40, wob 8-45K, Tq. 7-8K. ADT = 5.62, AST = 2.17, ART = 3.45. Circulate 2 bottoms up. 600 gpm, 1400 psi, 60 rpm. Pump dry job and POH. Remove ice from derrick. Adjust motor from 2.12 deg. to 1.50 deg. & Orient. Service top drive. TIH with BHA #3. Shallow test MW D, TIH to 1890' tight hole to 1946', wash through with no problem, continue to 3168', MU top drive and wash to bottom @ 3264'. No fill. Drill from 3264' to 3738'. 2874' TVD. Up wt. 125K, Down wt. 80K, Rot. wt. 100K. Gpm 650, pressure on -1800 psi, pressure off - 1650 psi. 100 rpm, 6-8K tq. on, 4-6K tq. off. ADT = 3.27, AST = 0.42, ART = 2.85. Drill surface hole from 3738' to TD C«~ 4720'. Up wt. 140K, Down wt. 90K, Rotating wt. 108K. 650 gpm, 2000 psi on bottom, 1850 psi off bottom, tq. 8K on, tq. 4K off, 100 rpm. ADT = 6.13, AST = .83, ART = 5.30. Circulate 2 bottoms up. 650 gpm, 1800 psi, 100 rpms. POH to 2980'. Pulled 20K over at 4524', 3785', 3710', 3505' - wiped each once -drag eliminated. RIH to TD C~ 4720' with no problems. No fill. Circulate and pump sweep C~3 650 gpm, 1850 psi, 100 rpm. POH 5 stands, pump dry job, POH to 2050.20K over pull. Wipe tight spots from 2050 to 1850, POH to BHA. Lay down BHA. R/U to run 10 3/4" casing. Clear floor. Make dummy run and check mandrel hanger/split landing joint lengths. PJSM with all hands. Run casing shoe and float joints. Circulate shoe track and test floats. Run 10-3/4" surface casing to 4708' and land. Tight spots at 1820', 3080', 3500'. Printed: 7/11/2005 10:19:48 AM BP EXPLORATION ~ ~ ~ ~ ~~ ~ V, Page 3 of 20 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report ~~ IG 1 ~ 2O05 S-111 ~ -~ ~~~ ~_, . ~.,.._ ..r~ ~ ._ ._.. S-111 '4~pud U~te: 511512005 DRILL+COMPLETE Start: 5115/2005 End: NABOBS ALASKA DRILLING I Rig Release: 7/8/2005 NABOBS 7ES Rig Number: Date I From - To I Hours j Task 5/19/2005 07:45 - 08:30 0.75~CASE 08:30 - 11:00 2.50 CASE 11:00 - 11:30 I 0.501 CEMT 11:30 - 13:30 I 2.001 CEMT 13:30 - 14:30 ~ 1.00 ~ CEMT 14:30 - 16:00 I 1.501 CEMT 16:00 - 17:00 1.00 CEMT 17:00 - 19:30 2.50 CEMT 19:30 - 23:00 3.50 CEMT 23:00 - 00:00 1.00 BOPS 5/20/2005 100:00 - 03:00 I 3.00 03:00 - 04:00 I 1.00 Code ~ NPT ~ Phase I ~ Description of Operations ~-. i - - - --- --- ___ __ SURF R/D Franks tool and MU cementing head. .SURF Circulate and condition mud. Stage pumps up to 10 bpm ~ 750 psi. Reciprocate pipe. SURF Switch to SWS Cementers & pump 5 bbls. water. Test lines to 3500 psi. SURF Pump 15 bbls CW 100, 75 bbls of 10.1 ppg Mudpush, drop bottom plug, pump 575 bbls. of 10.7 ppg ArcticSet Lite lead slurry, pump 93 bbls. of 15.8 ppg Class 'G' tail slurry. Drop top plug. All cement pumped ~ 5 to 6 BPM. Full returns. SURF Rig displaced w/9.5 ppg mud C~ i0 bpm. Slow rate to bump plug. Bump plug ~ 1500 psi, check floats. Full returns. 28 bbls of good, 10.7 ppg cement slurry back to surface. SURF R/D cement head, UD landing jt., R/D casing elevators and stabbing board. SURF M/U cleanout tool and flush cement from diverter. SURF N/D riser, knife valve, diverter and diverter line. SURF NU ROPE. ~ SURF Rig up to test BOPE. AOGCC representative Chuck Scheve on location to witness test. SURF Test BOPE to 250 psi -Low and 4000 psi -High. No failures. Test witnessed by Chuck Sheve: AOGCC, Lowell Anderson: BP WSL, and Chris Weaver: NAD Tourpusher. SURF R/D BOP test and clear rig floor. Check ID and install wear bushing. 04:00 - 04:45 0.75 DRILL INT1 04:45 - 09:00 4.25 DRILL INT1 09:00 - 10:15 1.25 DRILL INT1 10:15 - 11:00 0.75 DRILL INTi 11:00 - 11:45 0.75 DRILL INT1 11:45 - 12:00 0.25 DRILL INTi 12:00 - 13:00 1.00 DRILL INT1 13:00 - 14:30 1.50 DRILL INT1 14:30 - 15:15 0.75 DRILL INT1 15a5 - 16:30 I 1.251 DRILL I I f INT1 16:30 - 17:00 I 0.501 DRILL I I I INT1 17:00 - 20:00 3.00 DRILL INT1 20:00 - 20:30 0.50 DRILL INT1 20:30 - 23:30 3.00 DRILL INT1 23:30 - 00:00 0.50 DRILL INTi 112005 00:00 - 00:30 0.50 DRILL P INTi 00:30 - 04:15 3.75 DRILL P INT1 04:15 - 05:15 I 1.001 DRILL I P I I INT1 05:15 - 00:00 I 18.751 DRILL I P I I INT1 UD used jars. P/U new set of jars. M/U BHA. P/U 126 jts of 5" drill pipe and RIH. Cut and slip drilling line. Adjust brakes on draw works. Circulate from 4350' to 4620' and tag up on top plug. Pressure test casing to 3500 psi and hold for 30 minutes. Drill plugs and float collar. Drill cement and stop at shoe. Circulate and swap out to 8.8# system. Drill out of shoe to 4740'. 120 rpm, 500 gpm, 630 psi. Tq. on 7-10K. Circulate, rotate, and reciprocate f/4700' to 4670' 03500 gpm, 630 psi, tq. 7K. Mud balanced 8.8 ppg in & out. Perform LOT C~3 3354' TVD to 14.48 ppg EMW, 8.8 ppg mud, 991 psi. Pump dry job and POH. UD BHA PJSM before picking up BHA w/radioactive sources. P/U Rotary 5teerable BHA and surface test C~ 90'. P/U 5" DP from pipe shed and TIIH. Lubricate rig and top drive. PU 123 jts. of 5" drill pipe + 3 stands from derrick to shoe at 4708'. Circulate bottoms up, record SPRs, establish clean hole baseline ECD C~ 9.65 ppg. Drill w/9-718" RSS from 4740' to 6629'. Pumped 25 bbl./ 10.8 ppg /240 vis sweeps @ 5130', 5600', 6440'. Saw good cuttings increases. ART = 11.1, At 00:00 drilling parameters as follows: Up wt. 150K, dn. wt. 110K, rot. wt. 125K, tq. off 10K, Printed: 7!11/2005 10:19:48 AM BP EXPLORATION Operations Summary Report :~ ~ ~ ~~'~ gage 4 of 20 At~~ ~ ~ Z~irlS Legal Well Name: S-111 ~', ~,; Common Well Name: S-111 Spud Date: 5!1512005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABOBS ALASKA DRILLING l Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: i Date ~ From - To ! Hours ~ Task i Code NPT ~, Phase Description of Operations ~ i i ~ --1___~___--+---! ___- ---- --~------------------------------- 5/21/2005 05:15 -00:00 18.75 DRILL P INT1 tq. on 12K, 140 rpm, 624 gpm @ 1850 psi on. Solids control van processed mud for 16 hrs, conditioned 2037 bbls of mud, removed 37 bbls. of solids, maintained discharge back to mud system of approximately 8.7 ppg. Calculated ECDs 9.65 ppg, PWD ECD 10.06 ppg. 5/22!2005 00:00 - 00:00 24.00 DRILL P INT1 Drill w/9-718" RSS from 6629 to 9090' Backreamed each connection, rotating, full stand. Pumped 25 bbl. hi vis sweeps @ 6830' w/10% cuttings increase, 7300' w/100°I° cuttings increase, 7800' w/75% cuttings increase, 8260' wl25% cuttings increase and 8730' w150% cuttings increase . Solids control van processed for 24 hrs. conditioning 3484 bbls. of mud removing 51 bbls. of solids. Solids van effluent maintaining approximate wt. of 8.9 ppg. Drilling parameters at 00:00 were: Up wt.180K, dn. wt. 120K, rot. wt. 145K, tq, off 10,500K, tq. on 12,000K, 140 rpm, 627 gpm @ 2200 psi on. ECDs @ 6629' _ 9.65 calculated/10.06 actual. ECDs @ 9090' = 10.08 calculated/10.45 actual. ECD hardline maintained @ maximum .5 above calculated/actual throughout day. ADT = 15.08 hrs. AT 8992' MD/5480'TVD crossed fault "B" 30' !ow per geologist. No fluid loss evident. 5/23/2005 00:00 - 00:00 24.00 DRILL P INT1 Drill w/RSS from 9090' to 11166'. Drilling parameters at 00:00 = Up wt.220K, dn. wt. 135K, rot. wt. 160K, tq, off 15000K, tq. on 16000K, 140 rpm, 630 gpm @ 2925 psi on. WOB 12K-14K, PWD ECD = 11.84 Calculated ECD = 11.41. Pumping Hi-Vis sweeps every 400'. 40°I° to 60°f° cuttings increases w/sweeps. Glycol introduction to mud system caused ECDs to spike as predicted in program. Cut back WOB/BOP until well cleaned up. Solids control van procesed for 15 hrs., conditioning 2364 bbls. of mud, removing 43 bbls of solids and maintaining approximate mud wt. of 9.3 ppg. 5/24/2005 00:00 - 11:30 11.50 DRILL P INTi -Drilling w! RSS from 11,166' to TD @ 12,210'. Drilling parameters at TD = WOB 30K P/U wt.230K, S/O wt 135K, rot. wt. 165K, Tq on bottom 19K, Tq off bottom 14K, 140 rpm, 630 gpm @ 2980 psi. - Pumped hi-vis sweeps every 500'. i 1:30 - 14:00 2.50 DRILL P INTi -Pump hi-vis sweep surface to surface & 1 additional B/U @ 605 GPM, 2725 psi, 140 RPM & reciprocating. 50% excess cuttings seen @ shakers w/ sweep. 14:00 - 20:00 6.00 DRILL P INT1 - POH w/ 2 stands w/ no problems. - Backream from 12,100' to 11,250' due to tight hole & swab. - POH from 11,250' to 4646' w/ no problems. Hole slick. 20:00 - 22:00 2.00 DRILL P INTi -Cut & slip 112' of drilling line. - Inspect & service brakes. - Service TD & crown. 22:00 - 00:00 2.00 DRILL P INTi -RIH from 4646' to 7480'. 5/25/2005 00:00 - 02:30 2.50 DRILL P INTi -RIH from 7,480' to 12,210'. Hole slick. 02:30 - 06:00 3.50 DRILL P INT1 -Circulate hi-vis sweep surface to surface & additional B/U x 2 to condition mud for casing run. Staging up pumps from 400 GPM to 630 GPM. FCP 2800 psi. Initial ECD 11.83 -final ECD 11.32 06:00 - 17:00 11.00 DRILL P INT1 -Monitor well -pump dry job. - POH & VD 5" DP 1 x 1. Hole slick. Printed: 7/11/2005 10:19:48 AM BP EXPLORATION Operations. Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To ---+- 5/25/2005 17:00 - 20:00 20:00 - 20:30 20:30 - 22:30 S-111 S-111 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES ~~ Hours Task I Code ; NPT I ~°~`'~~ Page 5 of 20 Al~~ ~. ~ Z~~5 e .=.i 4ii~ .. _. ., ,. .. ~.-' l.a, .,.-..,liar ~~~~ud ~~te: 5/15/2005 Start: 5/15/2005 End: Rig Release: 7/8/2005 Rig Number: Phase --~--- ~---L---_ ___ 3.00 DRILL P INT1 0.50 BOPSU P INT1 2.00 CASE P INT1 22:30 - 23:30 1.00 CASE P INTi 23:30 - 00:00 0.50 CASE P INT1 5126!2005 100:00 - 05:30 I 5.501 CASE P 05:30 - 06:30 1.00 CASE P 06:30 - 21:30 15.00 CASE P INT1 INT1 INTi 21:30 - 22:00 0.501 CASE P I INTi 22:00 - 00:00 I 2.001 CASE I P I I INT1 5/27/2005 100:00 - 02:30 I 2.501 CASE P I INT1 02:30 - 03:00 I 0.501 CEMT I N I SFAL I INT1 03:00 - 06:30 I 3.501 CEMT I P I I INT1 06:30 - 07:30 1.00 CASE P INT1 07:30 - 08:00 0.50 CASE P lNT1 08:00 - 12:00 4.00 CASE P INT1 Description of Operations - L/D HWDP & BHA. Bit grade i-3-CT-T-X-I-WT-TD. - Pul{ bowl protector & install test plug. - C/O top pipe rams to 7 5/8". - R/U & test door seals to 250 psi 14,000 psi. - Make dummy run w/ 7 5/8" hanger. - R/U to run 7 5(8" casing, - M/U float shoe, 2 jts 7 5/8" 29.7# L-80 BTC-M casing, & float collar. Bakerlok connections. -Fill casing & check floats -floats holding. - M/U & run 7 5/8" 29.7# L-80 BTC-M casing utilizing Best of Life thread compound. Avg M/U Tq 9200 fVlbs. - Stage up pump & circulate 1.5 casing volumes before entering OH @ 6 BPM 510 psi - Continue RIH w/ 7 5/8" 29.7# L-80 BTC-M casing into OH w/ running speeds less than 60' per minute. Filling pipe every jt & washing down 1 jt every 15 jts C 5 minutes per jt. From 6,200' to 7,000' & from 8,200' to 8,900' washed down each jt as precaution to prevent losses C~1 5 minutes per jt. - Ran a total of 294 jts of 7 5!8" 29.7# L-80 BTC-M casing w/ no losses. - VD Frank's fill up tool & P!U landing jt & hanger. - Land hanger (S/O wt 140K) & M/U cementing head. - Stage up pumps slowly- circulate & reciprocate in preparation for cement job - lCP @ .5 BPM 410 psi, FCP t«~ 5 BPM 720 psi. No losses. - Stage up pumps slowly- circulate & reciprocate in preparation for cement job - {CP C«~ .5 BPM 410 psi, FCP @ 5 BPM 720 psi. No losses. Batch up tail cement. - Line up to cementers. Pump 5 bbls fresh water through tee to warm the lines. - Start pressure test to 4,000 psi. During the test, found a leak from the cement line in the pipe shed. - Shut down and repair the leak. - Line back up to cementers. Pump 5 bbls fresh water through tee to warm the lines. Pressure test lines to 4,000 psi - Pump 55 bbls of Mudpush spacer ~ 11.5 ppg - Shut down and drop the bottom plug. Pump 219 bbls 12.0 ppg Litecrete lead - Pump 69 bbls 15.8 ppg Class G + adds. - Drop top plug and flush the lines. Turn over to the rig to displace. - Displace cement & with 557 bbls of 10.5 ppg mud. Bump plug & increase pressure to 1500 psi. Hold pressure for 2 minutes - bleed off & check floats. Floats holding. - CIP C~? 06:05 - R/D cement head, L/D landing jt, & R/D casing tools. - Install 7 518" packoff & test to 5,000 psi. Hold test for 10 min. - CIO top pipe rams from 7 5/8" to 3 1/2" x 6" variables. - C!O saver sub to 4" HT-40. - Install test plug & test door seals to 3,500 psi. - Pull test plug & install bowl protector. - Clear & clean floor, B/D fines, & R/D stabbing board. - Load pipe shed w/ 4" DP. Printed: 7/11/2005 10:19:48 AM BP EXPLORATION ~~~ ~ ~ ~a~ge 6 of 20 Operations Summary Report ~~ .~;~, ~~ ~ ; . ~ ~;, e:a. ~~„ '°~`~;,?3; Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5/15/2005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/8!2005 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours ~ Task I Code ~ NPT ~ Phase i Description of Operations --- ----~ - ~ ----~_---- 1---------------_------ ------- 5l27/2005 12:00 - 16:00 4.00 CASE P INTi -Continue loading pipe shed with 4" DP and Cleanout BHA. - Service Iron roughneck & TD. - Simops: Perform infectivity test down the 10-3l4" x 7-5(8" annulus. Fracture initiation pressure - 785 psi. Increase rate to 2 BPM and clear the annulus by pumping 100 bbls of 10.5 mud, ICP - 1030 psi, FCP - 890 psi. - Simops: RU LRHOS and freeze protect the 10-314" x 7-5/8" annulus with i 00 bbls of diesel to 2,500' MD / 2,200' TVD. 16:00 - 17:00 1.00 CASE P INT1 - PU Cleanout BHA and RIH. Cleanout BHA: 6-3/4" window mill, bit sub, upper mill, bumper sub, pumpout sub, 9 x 4.75" drill collars, xo, 21 x4" HWDP. 17:00 - 00:00 7.00 CASE P INT1 - P/U 4" DP &RIH 1 x 1 to 7855'. 5/2812005 00:00 - 04:00 4.00 CASE P INT1 - P!U 4" DP &RIH 1 x 1. - Wash down last stand C~3 3.5 BPM, 800 psi & tag float collar on depth ~ 12,109'. 04:00 - 06:00 2.00 CASE P INT1 -Pump 100 bbls fresh water w! 2 drums DD followed by 40 bbl pill w/ 4 drums EP mud tube. - Displace well to new 9.0 ppg flo-pro NT drilling fluid ~ 10.5 BPM, 2400 psi, 15 RPM, & reciprocating. 06:00 - 07:00 1.00 CASE P INTi -Test the 7-5/8" casing to 4,000 psi. Chart and hold for 30 minutes. 07:00 - 12:30 5.50 CASE P INT1 - POH standing back 4" DP in the derrick. - Stand back 4" HWDP and drill collars. - LD pump out sub, bumper sub, upper mill, bit sub and window mil{. 12:30 - 23:00 10.50 EVAL P INT1 - RU Schlumberger E-line. - RIH with USIT to log cement quality. - Test choke manifold while logging to 250 psi / 4,000 psi. Hold & chart 5 minutes per test. Replaced valve 16 due to leaking stem packing. Test witnessed by W SL's James Franks /Mike Dinger. AOGCC Rep John Crisp waived witness of test. 23:00 - 00:00 1.00 STWHIP P INTi - M/U EZSV &RIH on E-line. 5/29!2005 00:00 - 02:00 2.00 STWHIP P INT1 -RIH wf EZSV on E-fine & attempt to set ~ 11,569' WLM. 02:00 - 05:00 3.00 STWHIP N DFAL INT1 -Unable to set EZSV. Move E-line down to -11,800' -EZSV still on. POH to 11,330' & hanging up (4000 lbs. tension) - Run back down to 11,970'. Pick back up & hanging up to --11,600' w/intermittent drag (4000 lbs. tension) - Run back down to 11,970' & pull free C~ rope socket w/ 6500 Ibs tension. POH w/ E-line. 05:00 - 10:00 5.00 BOPSU P INT1 - R/U & test BOPE. Test annular preventer to 250 psi f 3500 psi & remaining equip't to 250 psi 14000 psi. w/ no failures. Witness of test waived by AOGCC Rep John Crisp & witnessed by Toolpusher Larry Wurdeman. 10:00 - 12:00 2.00 FISH N DFAL INT1 - M/U &RIH w! fishing BHA - 5 314" overshot, bumper sub, oil jars, circ sub, 9 drill collars, XO, & 21 jts 4" HWDP. 12:00 - 17:30 5.50 FISH N DFAL INTi -RIH w/ fishing ass'y to 11,830'. 17:30 - 18:30 1.00 FISH N DFAL INT1 - CBU & condition mud ~ 9 BPM, 1600 psi, 80 RPM, & reciprocating. 18:30 - 20:00 1.50 FISH N DFAL INTi -Wash down C~ 2.5 BPM, 515 psi, 25 RPM from 11,830'. Tag & swallow fish on bottom. (top of float collar) Engage fish & set down 5K. P/U & shear off of setting tool w/ Printed: 7/71!2005 10:19:48 AM BP EXPLORATION Zad~ Page 7 of 20 ~+~ ~ ~ ~ Operations Summary Report Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5!15!2005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABOBS ALASKA DRILLING l Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: Date j From - To j Hours ~~ Task II Code I NPT Phase ~~ Description of Operations 5/29/2005 18:30 - 20:00 1.50 FISH N DFAL INTi 45K overpull. 20:00 - 00:00 4.00 FISH N DFAL INT1 -Drop dart to open circ sub & POH wet w/ 20 stands. Shear dart & open circ sub w/ 2100 psi. - Pump dry job & POH to 4,800' 5/30/2005 00:00 - 02:30 2.50 F1SH N DFAL INT1 - POH & recover fish. Recovered OB logging head, rollers, gamma gun w/ adaptors, &CPST setting tool. Only item left in hole is EZSV. 02:30 - 03:00 I 0.501 FISH I N I DFAL I INTi 03:00 - 06:30 I 3.501 EVAL I N I DFAL I INTi 06:30 - 12:00 { 5.501 EVAL I N I DFAL I INT1 12:00 - 13:30 I 1.501 F{SH I N I DFAL I INT1 13:30 - 18:00 4.50 FISH N DFAL INTi 18:00 - 19:00 1.00 FISH N DFAL INTi 19:00 - 20:00 I 1.001 FISH I N I DFAL I INT1 20:00 - 21:30 I 1.50 ~ FISH I P I I INTi 21:30 - 00:00 I 2.501 FISH I P I INT1 5/31/2005 100:00 - 03:00 I 3.001 FISH I N I DFAL I INT1 03:00 - 09:00 6.00 STWHIP N DFAL INT1 09:00 - 14:00 5.00 STWHIP P INTi 14:00 - 14:30 0.50 STWHIP P INT1 14:30-16:00 1.50 STWHIP P WEXIT 16:00 - 00:00 I 8.001 STWHIP! P I I WEXIT Note: Preliminary findings indicate ignitor received voltage but did not transfer power to explosive portion of ignitor which prevented shearing of setting tool. - B/D jars, bumper sub, overshot, & fished components. UD same. - R/U E-line & RIH w/ 6.75 gauge ring & junk basket to 11,700'. - Recovered 2 small pieces. of ceramic & 1 small piece of 'O' ring from junk basket. - M/U EZSV &RIH on E-line & attempt to set ~ 11,574' WLM. No indication of firing head detonation. Repeat x 3 w/ no success. - POH w/ EZSV to -10,100' & hung up. Could not move upward, RIH to -12,100' & attempt to pull upward at various intervals w! no success. Shear off tool string w! 6700 lbs. - POH & R/D Schlumberger. Note: Tools left in hole: OB logging head, gamma gun w/ adaptors, 1 set rollers, CPST setting tool, &EZSV. - M/U &RIH w/ fishing BHA -overshot, bumper sub, oil jars, circ sub, 9 drill collars, XO, & 21 jts 4" HWDP. - RIH w/ fishing ass'y to 11,833'. - CBU to condition mud ~ 9 BPM, 1650 psi, 80 RPM, & reciprocating. - P/U wt 175K, S/0 wt 125K, Rot wt 140K. -Wash down from 11,833' C«? 2 BPM, 450 psi, & 30 RPM. Tag & swallow fish on bottom. Engage fish & set down 5K. P/U & shear off of setting tool w/ 45K overpull. - Rack back one stand & drop dart to open circ sub. - Cut & slip 114' drilling line, inspect brakes, service 7D, & replace grabber die on pipe handler. - Shear circ sub w! 1800 psi, pump dry job, & POH w/ fishing ass'y to 5470'. - POH wl fish. Recovered all tools except EZSV including OB logging head, gamma gun w/ adaptors, 1 set of rollers, &CPST setting tool. UD same. - M/U EZSV, setting tool, and RIH on DP. - Rotate string & set EZSV ~ 11,553'. Shear out setting tool & wt check EZSV. - POH to BHA. - UD BHA & clear floor. - P/U & M/U bottom anchor, whipstock, window mill, bit sub, upper mill, float sub, 1 jt 3 1/2" HWDP, MWD, bumper sub, circ sub, XO, & 9 drill collars &RIH - RIH w/ whipstock at controlled running speeds to 11,433'. Printed: 7111/2005 10:19:48 AM BP EXPLORATION Al~~~ ~ ~ ZQ.~~ Page 8 of 20 Operations Summary Rept~t~ ~,, t, ~; ,;Y,. l ,;r~~;,; ~~,I Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5!15/2005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: Date ~ From= To ~ Hours ~ Task L ode j NPT I Phase ----- ~_ i 5/31/2005 16:00 - 00:00 8.00 STWHIP P WEXIT 6/1/2005 00:00 - 01:00 1.00 STWHIP P WEXIT 01:00 - 08:30 I 7.501 STW HI P I P 08:30 - 09:00 0.50 STWHIP P 09:00 - 13:30 4.50 STWHIP P 13:30 - 16:30 3.00 STWHIP P 16:30 - 18:00 1.50 BOPSU P 18:00 - 21:00 3.00 DRILL P 21:00 - 00:00 3.00 DRILL P 6/2/2005 00:00 - 03:30 03:30 - 04:30 04:30 - 07:00 07:00 - 00:00 3.50 DRILL P 1.00 DRILL P 2.50 DRILL P 17.00 DRILL P 6/3/2005 100:00 - 06:00 06:00 - 07:00 07:00 - 10:30 10:30 - 13:00 13:00 - 15:00 15:00 - 20:30 20:30 - 21:00 21:00 - 21:30 6.001 DRILL I P 1.00 DRILL P 3.50 DRILL P 2.50 DRILL P 2.00 DRILL P 5.50 DRILL P 0.50 DRILL P 0.50 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Description of Operations Shallow test MWD C~ 1, i 00' - Orient whipstock 33 deg LHS. P/U wt 165K, S/O wt 120K. - S/O 15K & set bottom anchor. P/U to 170K to ensure bottom anchor set. Lower string & squat 35K to shear mills from whipstock. -Mill window in casing & 20' new hole. WOM 1-15K, 350 GPM, 2275 psi, 120 RPM, Tq on bottom 10K, Tq off bottom 5K, P/U wt 165K, S/O wt 120K, Rot wt 140K. - Pump sweeps as needed to remove metal - recovered a total 80 lbs. of metal. TOW - 11,536'; BOW - 11,549' -Perform FIT to 11.0 ppg EMW w/ 8.9 ppg mud. (750 psi) - Pump dry job -monitor well - POH to BHA. - UD 21 jts of 4" HWDP & BHA. Clear floor. - Pull bowl protector, RIH & flush stack w/ flushing tool, & install bowl protector. - M/U 6 3/4" drilling assy as follows: 6 3/4" DSX111 PDC bit, mud motor w/ 1.5 deg bend w/AIM, flow bypass sub w/ float, NM stab, NM lead collar, MWD, PWD, ADN, 3 non-mag flex DC's, circ sub, XO, & hydraulic jars. - P/U 4" DP 1 x 1 from pipeshed &RIH. - Shallow hole test MW D ~ 995'. - P/U 4" DP 1 x 1 from pipeshed & RIH to 5,820'. - Slip & cut drilling line. - Lubricate rig & service TD. WEXIT -RIH w/ 6 3/4" drilling assembly on DP stands from derrick. - Orient above window. PROD1 -Drill directional in 6 3/4" hole from 11,562' to 11,798'. Difficult sliding -pick up string above window & pump EMI-920 sweep w/ temporary relief while drilling 20'. (BOP increase to 60 FPH from 15 FPH) - WOB 5-10K, pump pressure on bottom 1900 psi, off bottom 1800 psi, 100% slide. P/U wt 160K, S/0 wt 115K. -ART 0 hrs, AST 9.13 hrs, ADT 9.13 hrs PROD1 -Drill directional in 6 3/4" hole from 11,798' to 11,885' -difficult sliding. Increasing tubes to 4%. Unable to attain required build rates w/current BHA. PROD1 -Pump out of hole to window -pull through window w! no pumps -pull additional 5 stands. Hole in good condition w1 no swab. PROD1 - POH to BHA. PROD1 -Remove source, UD ADN, change motor to 2.12 deg bend, & download MWD. PROD1 -RIH w/ BHA & 8 stands DP. BHA consists of: Smith 6 314" XR10T bit, mud motor w! 2.12 deg bend w! AIM, flow bypass sub w! float, NM stab, NM flex lead collar, MWD, PWD, NMXO, 3 NM flex DC's, circ sub, XO, & jars. - Shallow hole test MWD. PROD1 -RIH to just above top of window. PROD1 -Pump 50 bbl EMI-920 sweep & spot inside casing. PRODi -RIH to 11,885' taking check surveys @ 3 stations. Printed: 7(11/2005 10:19:48 AM BP EXPLORATION ~~~~ ~ ~ ~O~~age 9 of 20 Operations Summary Reports§~~,R~,{A ~` ~ P ,, i ,r~ . ~ ~-3 Legal Well Name: S-111 Common W ell Name: S-111 Spud Date: 5/15/2005 Event Nam e: DRILL+C OMPLE TE Start : 5/15/2005 End: Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 7/8/2005 Rig Name: NABOB S 7ES Rig Number: Date ~ From - To ~ Hours i Task ~ Code j NPT j Phase I Description of Operations _--_- -____---- -- -- 1- ~~ ~ -------------- 6/3/2005 21:30 - 00:00 2.50 DRILL P PROD1 -Drill directional in 6 3/4" hole from 11,885' to 11,935'. WOB 20-30K, 300 GPM, 1750 psi, P/U wt 155K, S/O wt 110K. - Last 24 hrs: AST 5.52 hrs, ADT 5.52 hrs. - Displaced EMI-920 sweep & old mud overboard & replaced w/ 580 bbls of new 8.9 ppg flo-pro NT while taking surveys & drilling. 6/4/2005 00:00 - 17:30 17.50 DRILL P PRODi -Drill directional in 6 3/4" hole from 11,935' to 12,292". WOB 20-30K, 300 GPM, 1800 psi, P/U wt 160K, S/O wt 115K. - AST 10.95 hrs, ADT 10.95 hrs 17:30 - 19:00 1.50 DRILL P PRODi -Pump out of hole to just below window @ 4.5 BPM, 850 psi. - Monitor well -static -pump dry job. 19:00 - 00:00 5.00 DRILL P PRODi - POH to BHA. 6/5/2005 00:00 - 01:30 1.50 DRILL P PRODi -Handle BHA. L/D impulse tool & bit. 01:30 -04:00 2.50 DRILL P PRODi - M/U BHA as follows: 6 3/4" DSX111 bit, bias unit, control collar, XO, receiver sub, XO, Impulse toot, PWD, ADN, 3 NM flex collars, circ sub, XO, & jars. - Surface test impulse tool & bias unit. 04:00 - 08:30 4.50 DRILL P PRODi -RIH w/ 6 3/4" RSS assy to top of window. 08:30 - 09:30 1.00 DRILL P PROD1 - ~ ubricate rig & service top drive. - Cut & slip 70' of drilling line. 09:30 - 12:30 3.00 DRILL P PRODi -RIH to 11,735' & MADD pass down to 12,292'. 12:30 - 21:30 9.00 DRILL P PROD1 -Drill directional in 6 3/4" hole w/ RSS from 12,292' to 12,788'. WOB 8-18K, 290 GPM, 2100 psi, 140 RPM, Tq off bottom 6K, Tq on bottom 9K, P/U wt 168K, S/O wt 115K, Rot wt, 130K. - Calculated ECD 9.95 ppg, actual ECD 10.05. - ART 5.59 hrs, ADT 5.59 hrs. - Came out of the top of the Kuparuk C and into the Kalubik for a minimum of 116'. Discuss options w/ Anchorage Team & decide to attempt OH sidetrack w/ BSS. 21:30 - 22:00 0.50 STKOH C PROD1 -Pump out of hole to 12,404'. 22:00 - 23:00 1.00 STKOH C PROD1 -Collect & record inclination data every 10' from 12,404' to 12,495' for OH sidetrack. 23:00 - 00:00 1.00 STKOH C PROD1 -Trench from 12,404' to 12,436' C~3 300 GPM, 2000 psi, 140 RPM, Tq 5K. 616/2005 00:00 - 02:00 2.00 STKOH C PRODi -Trench from 12,404' to 12,436' @ 300 GPM, 2000 psi, 140 RPM, Tq 5K. 02:00 - 14:00 12.00 STKOH C PROD1 -Time drill from 12,436' to 12,446'. 290 GPM, 1920 psi, 140 RPM, Tq 5K. - Check ledge w/ 10K w/o pumps. Put pump on hole w/ 2K WOB & fell off ledge. - P/U to 12,440' & time drill @ 2' hr to 12,444'. Check ledge - no good. 14:00 - 16:00 2.00 STKOH C PROD1 - POH to window. Backream from 12,440' to 12292' w/ hole attempting to packoff. Wipe & clean interval. No problems from 12,292' to window. 16:00 - 21:00 5.00 STKOH C PROD1 -Pump dry job & POH to BHA. 21:00 - 23:00 2.00 STKOH C PROD1 -Handle BHA -Pull source & L/D ADN, UD impulse tool & BSS. 23:00 - 00:00 1.00 STKOH C PROD1 - P/U BHA - 6 3/4" STX-1, mud motor w/ 2.12 deg bend w/ AIM, flow bypass sub w/ float, NM stab, impulse tool, PWD, NMXO, 3 NM flex DC's, circ sub, XO, & jars. 6!7/2005 00:00 - 04:00 4.00 STKOH C PROD1 Shallow hole test impulse tool. Printed: 7/11/2005 10:19:48 AM BP EXPLORATION Operations Summary Report ~4~.'G ~ ~ 2~~~1~ Legal Well Name: S-111 /4'`` ~ ~ `~ ~ - :` Common Well Name: S-111 .Spud Date: 5(15(2005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: . Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/8f2005 Rig Name: NABORS 7ES Rig Number: Date ~~ From - To ~ Hours ~ Task ~ Code ! NPT 'i Phase j Description of Operations ------- ---- ~i- 6/7/2005 00:00 -04:00 4.00 STKOH C 04:00 - 04:30 0.50 STKOH C 04:30 - 05:00 0.50 STKOH C 05:00 - 13:30 { 8.501 STKOH I C 13:30 - 14:00 0.50 STKOH C 14:00 - 21:00 7.00 STKOH C 21:00 - 22:30 1.50 DRILL C 22:30 - 00:00 1.50 DRILL C 6/8/2005 ~ 00:00 - 04:30 I 4.501 DRILL ~ C 6/912005 04:30 - 05:30 1.00 DRILL C 05:30 - 06:00 0.50 DRILL C 06:00 - 08:00 2.00 DRILL C 08:00 - 11:30 3.50 DRILL C 11:30 - 12:00 0.50 DRILL C 12:00 - 13:30 1.50 DRILL C 13:30 - 14:00 0.50 DRILL C 14:00 - 17:30 3.50 DRILL C 17:30 - 23:00 23:00 - 00:00 00:00 - 01:00 01:00 - 03:00 03:00 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 12:00 12:00 - 13:30 13:30 - 18:00 5.50 DRILL X 1.00 DRILL X 1.00 DRILL X 2.00 DRILL X 3.50 DRILL X 0.50 DRILL X 1.50 DRILL X 3.50 DRILL X 1.501 DRILL fX 4.501 DRILL IX L- ! _ - __ - - _ - -- - --- - ---- PRODi RIH to top of window filling every 30 stands. PRODi Orient &RIH to kick off point. PROD1 Check inclination data with AIM from 12,410' to 12,490' to verify baseline angle of sidetrack. PRODi Time/slide to initiate OH sidetrack from 12,439' to 12460'. 300 gpm ~ 1850 psi. PROD1 Slide from 12460' to 12463' PROD1 Directional drill from 12456' to 12678'. 310 gpm ~ 1950 psi. Up wt. 165K, Dn. wt. 110K, Rot. wt. 130K, 40 rpm, 6K tq. PROD1 Pump hi-vis sweep. Rotate 20 rpm. PROD1 POH w/bent housing motor assembly backreaming from 12678' to 12391'. ADT = 6.06 hrs., ART = 4.28 hrs., AST = 1.78 hrs. PROD1 POH w/2.12 deg. motor assy. Backream to window. Tight spots required reaming and backreaming from 12569' to 12439'. gpm 305, psi 1975, tq. 5K-10.5K while reaming and backreaming. PROD1 Lay down BHA PROD1 Glean rig floor. PROD1 PU rotary steerable assembly BHA and shallow test tools. PROD1 RIH to 10900'. PROD1 Lubricate rig/top drive. PRODi RIH to 12312'. PROD1 MAD Pass (/12312' to 12473'. PROD1 Attempt to enter sidetrack w(rotary steerable system--no pump, no rotation, no entry. Attempt OH sidetrack entry w/20 rpm rotation, 290 gpm, 1900 psi, no entry. Attempt OH sidetrack entry w/60 rpm and 290 gpm. Attempt to time drill into OH sidetrack C~ 140 rpm, 290 gpm, 20 rpm, 1900 psi C~ 2 min./ft. from 12349' to 12449'. Unsuccessful getting into OH sidetrack w/rotary steerable system. Call town team and decision made to POH wlrotary steerable system and RIH w/1.83 deg. motor assy to attempt OH sidetrack entry. DPRB PROD1 POH to window, monitor well. Well static. Pump dry job, POH to BHA. DPRB PROD1 PJSM on handling of nuclear sources. Set back flex drill collars. Remove nuclear sources. DPRB PROD1 Lay downlstand back rotary steerable system BHA components. DPRB PROD1 Pick up BHA and nuclear sources. DPRB PROD1 RIH to window w/1.83 deg. bent housing motor. Well taking mud @ 1 bbl/hr. DPRB PROD1 Lubricate top drive and service rig. Monitor well for losses. Static. DPRB PROD1 RIH to OH sidetrack depth C~ 12439' DPRB PRODi Dress kick off point of open hole sidetrack. Work stabilizer across side track. Pull up to above side track and trough ho{e with the bit. RIH into new hole with bit and BHA in several positions with no problem. Confirm bit in new hole with survey. DPRB PRODi Enter OH sidetrack and MAD PASS f/12519' to 12678'. No fill found in OH sidetrack section. DPRB PROD1 Drill from 12678' to 12788'. ,~,~,'r "~ ~°°° t ; t: ~ Page 10 of 20 ~.~ , ~.~ ~,`..; 3 a a Printed: 7/11/2005 10:19:48 AM BP EXPLORATION Page 11 of 20 Operations Summary Report Legal Well Name: S-111 Common W ell Name: S-111 Spud Date: 5/15/2005 Event Nam e: DRILL+C OMPLE TE Start : 5/15/2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: f Date ~ From - To i Hours j Task j Code j NPT Phase ~ Description of Operations ~ ~ 6!9/2005 18:00 - 00:00 6.00 DRILL P PROD1 Drill from 12788' to 13100', 6896' TVD. Drilling parameters at 00:00 as follows: 310 gpm., 2150 psi off, 2300 psi on, 80 rpm, tq. off 5.5K, tq. on 6-SK. Up wt. 168K, dn. wt. 110K, rot. wt. 130 K. ADT = 5.89 hrs, AST = 2.12 hrs, ART = 3.77 hrs. Well taking 1 bbl/hr. ECDs = 10.03 calc., 10.09 actual. 6110/2005 00:00 - 06:00 6.00 DRILL P PRODi Drill 6.75" hole from 13100' to 13410'. Up wt. 165K, do wt. 105K, rot. wt. 130K. ECDs = 10.01 calc., 10.13 actual, gpm 305 @ 2200 psi. Sliding. 06:00 - 00:00 18.00 DRILL P PROD1 Drill from 13410' to 13762'. Up wt. 170K, do wt. 108K, rot. wt. 130K. Tq. off = 5-6K, tq. on = 7-9K. ECDs = 10.00 calc., 10.17 actual, gpm 310 C«3 2250 psi. Well took 6 bbls mud at 13770'. Hole taking 5-10 bbls mudlhour for last 24 hrs. Crossed fault @ 13690'. Sliding yields 101100 DLS. Sliding getting more difficult and slower. ADT for 24 hrs = 14.49, ART = 4.92, AST = 9.57. Time drilling = 2.56 from 13489' to 13527' building angle. 6/11/2005 00:00 - 13:30 13.50 DRILL P PROD1 Drilling 6.75" production hole from 13762' to 13953', 6910' . TVD. Up wt. 170K, do wt. 108K, rot. wt. 130K. 310 gpm @ 2550 on, 2350 off. 80 rpm., tq. on 8K, tq. off 6K. 13:30 - 14:30 1.00 DRILL P PRODi Circulate bottoms up, 310 gpm C~ 2450, 80 rpm. 14:30 - 17:00 2.50 DRILL P PRODi Backreaming out of hole past OH sidetrack. Pulled through several rough spots and reamed/backreamed through with no repeat of overpull. At OH sidetrack point, attempt to enter sidetrack but tools entered old hole as verified by MWD. 17:00 - 19:30 2.50 DRILL P PRODi Repeatedly trenched low side and 120 deg right at OH sidetrack entrance from 12405' to 12460'. After trenching, oriented tool face toward old hole and tools entered new OH sidetrack with pumps on, and off as verified by MWD. 19:30 - 20:30 1.00 DRILL P PROD1 POH to 7-5/8" casing window. No problems. 20:30 - 00:00 3.50 DRILL P PROD1 Monitor well (static), pump dry job, and continue to POH. 6112/2005 00:00 - 02:30 2.50 DRILL P PROD1 POH. PJSM with Schlumberger MWD and all hands and handle nuclear sources. L/D BHA. 02:30 - 07:00 4.50 BOPSU P PROD1 Pull wear bushing and perform BOP test: high pressure 4000 psi, low pressure 250 psi. AOGCC representative Chuck Scheve waived AOGCC witnessing of test. Test witnessed by BP WSL Lowell Anderson and Nabors Tourpusher Ray Barnes. 07:00 - 08:00 1.00 BOPSU P PROD1 Pull test plug. Install wear bushing and clear rig floor. 08:00 - 10:00 2.00 BOPSU P PRODi PJSM installation of nuclear sources. PU rotary steerable BHA and shallow test MWD. 10:00 - 15:00 5.00 DRILL P PRODi RIH wlrotary steerable system to window at 12536' filling drill pipe every 4000'. 15:00 - 16:30 1.50 DRILL P PROD1 Cut and slip drilling line. Service rig. 16:30 - 17:30 1.00 DRILL P PROD1 RIH to 12495', no trouble accessing OH sidetrack. Survey. 17:30 - 00:00 6.50 DRILL P PRODi MAD Pass 12495' to 13953'. 100 gpm @ 700 psi. 40 rpm. 6k tq. Up wt. 170K, do wt. 110K, rot wt. 130K. 6/13/2005 00:00 - 06:00 6.00 DRILL P PROD1 Drill 6.75" hole w/rotary steerable system from 13953' to 14247'. 300 gpm ~ 2316 psi. 120 rpm. 8k tq. Up wt. 170K, do wt. 110K, rot wt. 130K. Check baseline ECD Calc. 10.34, Act. 10.42. WOB 7-10. Per directional driller--increased ROPs caused bit to climb. Now drilling w/reduced ROP to hold line. 06:00 - 00:00 18.00 DRILL P PROD1 Drill 6.75" hole w/rotary steerable system from 14247' to 14571'. 290 gpm @ 2300 psi. 140 rpm. 6K tq. off, 9k tq. on. Up wt. 175K, do wt. 108K, rot wt. 128K. ECD calc. 10.45, Act. Printed: 7/11/2005 10:19:48 AM BP EXPLORATION Page 12 of 20 Operations Summary Report Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5/15/2005 Event Name: DRILL+COMPLETE Start: 5!15/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/8!2005 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours j Task I Code ~~ NPT i Phase 6/13/2005 06:00 - 00:00 ~ -; 18.00 ~ -_-- DRILL -r- I P I r -- PROD1 6/14/2005 100:00 - 17:00 I 17.001 DRILL ! P ! I PROD1 17:00 - 19:00 I 2.001 DRILL I N (DEAL I PROD1 19:00 - 21:30 2.50 DRILL N DEAL PROD1 21:30 - 23:30 2.00 DRILL N DEAL PROD1 23:30 - 00:00 I 0.501 DRILL I N IDEAL I PROD1 6/15/2005 00:00 - 05:00 5.00 DRILL N DEAL PROD1 05:00 - 06:30 1:50 DRILL N DEAL PROD1 06:30 - 08:30 ~ 2.00 ~ DRILL ~ N ~ DEAL ~ PROD1 08:30 - 16:30 8.00 DRILL N DEAL PROD1 16:30 - 19:00 2.50 DRILL P PROD1 19:00 - 21:00 2.00 DRILL N DEAL PROD1 21:00 - 22:00 1.00 DRILL N DEAL PROD1 22:00 - 00:00 I 2.00 (DRILL I P I { PROD1 6!2005 100:00 - 12:00 12.00! DRILL I P { I PROD1 12:00 - 13:00 I 1.001 DRILL I P ! { PROD1 13:00 - 14:00 1.00 DRILL N DPRB PROD1 14:00 - 16:00 2.00 DRILL N DPRB PROD1 16:00 - 16:30 0.50 DRILL N DPRB PROD1 16:30 - 18:00 1.50 DRILL N DPRB PRODi 18:00 - 19:30 1.50 DRILL N DPRB PROD1 19:30 - 23:00 3.50 DRILL N DPRB PROD1 23:00 - 23:30 0.50 DRILL N DPRB PROD1 Description ofi Operations 10.43. WOB 4-10. Fluid losses negligible. ROP 7-20. Dropping angle to 85.00 deg. ADT/ART= 17.5 hrs. Dri11 6.75" hole from 14571' to 15300'. Drilling parameters as of 17:00 = 290 gpm @ 2300 psi. 140 rpm. 6.5K tq. off, 10.5k tq. on. Up wt. 178K, do wt. 110K, rot wt. 130K. ECD talc. 10.65, Act. 10.66. WOB 8-20. RSS unable to build angle. Decision made w/town team to POH and run 2nd RSS w/new bit. Circulate sweep around. Backream to 13,839 ft with no problems. Con't POH to 12,420 ft with no pumps or rotary - no problems. Backream thru side track interval. Slide into new hole no problems, confirm with survey ~ 12,550 ft. Con't POH to window C~ 11,536 ft. No problems at window. Monitor well: static. Pump dry job. POH. ADT/ART = 10.81 hrs. POH from window C~1 i 1536'. PJSM wlSchlumberger DDIMW D and all hands for handling nukes. Laydown BHA. Bias unit washed out beneath two of the three pads. PJSM w/Schlumberger DD/MWD and all hands for handling nukes. PU BHA. TIH w/RSS to window at 11536'. Cut and slip drilling line. Change oil in top drive. TIH to 15272'. MU top drive. Downlink to RSS and program unit to drill, get MWD baseline info. Drill (115300' to 15372', 6932' TVD. 140 rpm., 8K tq., 270 gpm C~? 2160 psi. Up wt. 175K, dn. wt. 105K, rot. wt. 128K. ECDs 10.52 calc., 10.4 act. (Baseline high) ADT = 1.16 hrs. Difficulty in achieving climbing 6 deg. dogleg required by plan. DD attempted hi/lo wt. strategies w/100°1° bias on BSS. Town geo consulted and decision made to continue w/best possible build rate. Drill f/15372' to 15790' MD. 150 rpm., 11.5K tq. on 7.5K tq. off. 270 gpm ~ 2070 psi. Up wt. 178K, dn. wt. 105K, rot. wt. 130K. Fault crossed at 15790' +-. Incurred mud losses immediately of 50+- bbls/hr. Drill irom 15790' to 15910' MD, 6872' TVD. 265 gpm @ 1860 psi. 140 rpm, 12K tq. on. Up wt. 183K, dn. wt. 105K, rot. wt. 130K. WOB 17. ECDs: 10.46 calc./10.21 actual. Losses 180 bbls/hr. +-. Unable to heal losses while drilling ahead. Throw estimated at 52 ft. Drilled ahead to 15910' (= throw distance x 2+). Build and spot 50 bbl. pill w/45#/bbl LCM POH to 15654'--tight w/40K overpull. MU top drive and backream to 15272' and continue to POH. Lost 150 bbls. while pulling to 14602'. Take survey and check MWD. PU 39 jts 4" drill pipe and single in hole to 15910'. Build and spot 2nd 50 bbl LCM pill. POH to window at 11536' Service top drive and rig. Printed: 7/11/2005 10:19:48 AM i BP EXPLORATION Page 13 of 20 Operations Summary Report Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5/15/2005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: Date From - To j Hours j Task I Code I NPT j Phase ~ Description of Operations 6/16/2005 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Monitor well, taking fluid at 10.4 bbls/hr. Continue to build pit volumes to 680 bbls. + 200bb1s on truck + 290 bbl. load on standby at plant. Total losses from 12:00 to 00:00 = 912 bbls. ADT = 9.90 hrs. 6/17/2005 100:00 - 03:00 I 3.001 DRILL I N I DPRB I PROD1 03:00 - 04:30 I 1.501 DRILL { P I I PROD1 04:30 - 10:00 I 5.501 DRILL I N I RREP I PROD1 10:00 - 10:30 0.50 DRILL N RREP PROD1 10:30 - 13:30 3.00 DRILL N RREP PROD1 13:30 - 00:00 10.50 DRILL N RREP PROD1 6/18/2005. 00:00 - 05:30 5.50 DRILL N RREP PROD1 05:30 - 08:30 3.00 DRILL N RREP PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 12:00 3.00 DRILL N RREP PROD1 13:30 - 00:00 10.501 DRILL (N (RREP PROD1 6/19/2005 100:00 - 14:15 14.25 (DRILL I N I RREP PROD1 14:15 - 17:00 I 2.75 {DRILL I N I RREP I PROD1 17:00 - 19:45 2.75 DRILL N RREP PRODi 19:45 - 20:00 0.25 DRILL N RREP PROD1 20:00 - 20:45 0.75 DRILL N RREP PROD1 20:45 - 00:00 3.25 DRILL N RREP PROD1 00:00 - 04:30 4.501 DRILL (N (RREP PROD1 04:30 - 07:00 I 2.501 DRILL I N I RREP I PROD1 07:00 - 18:00 I 11.001 DRILL I N I RREP I PROD1 18:00 - 20:30 I 2.501 DRILL l N I RREP I PROD1 20:30 - 00:00 I 3.501 DRILL I N I RREP I PROD1 6/21/2005 100:00 - 12:00 I 12.001 DRILL I N I RREP I PROD1 TIH from 11536' to 15910'. Tight spot at 11950'. Weil taking 8 bbls/hr while tripping in hole. Downlink to RSS and drill from 15910' to 15,943'. Loss 290 bbls. PU wt. 178K, SO wt. 105K, Rot. wt. 130K. 270 gpm 2000 psi. Tq. on 8K, tq. off 7K, 140 rpm. TDS electrical malfunction. Short in service loop. Restrung temporary loop. TDS back in service. Smoke from top drive junction box. Shut down. Spot 50 bbl LCM pill to bottom hole. POH to above window ~ 11436'. No hole problems. 9.0 bblsfhr. losses. Replace old service loop. 3.5 bph staticaosses. Replace TDS service loop. Test TDS operating C~ 100%. 3.5 bph static fluid losses. RIH w/ 6 3/4" bit from window @ 11,536 ft. Drill from 15943' to 15951'. TDS malfunction requiring teardown/rebuild. POH to 11448' above window at 11,536'. Rig down TDS for removal w/crane and repair in Deadhorse. Circulate & cond mud 100gpm C~3 635 psi. Total mud losses f(24 hrs. 139 bbls. ADT.17 TDS removal and repair. WOW to pick TDS w/crane. Inspect chains and gears on draw works, change oil on same. General house keeping. Circ. surface to surface 460 bbls. 132 gpm max rate ~ 750 psi. Welder repair crack on 'Slinger' plates Replace chain on Lay Down machine. WOW to pick TDS w/crane. PJSM w/crane operators, all hands, tourpusher, WSL before lifting TDS. Pick TDS and remove to rack for transport to Deadhorse. Wait on TDS repair. Repair crack on Iron Roughneck Replace seat in #1 pump pulsation dampener Wait on TDS repair/replacement. Clean/service rig. Repair draw works brake linkage. Circ. well surface to surface 460 bbls ~ 130 gpm max., 750 psi. Rig maintenance. Clean rig. Change out #2 pump pulsation dampener seat. Circ. well surface to surface 462 bbls C~ 134 gpm max., 700 psi. Rig maintenance. Clean rig. Paint rig floor. Remove top drive baits from traveling blocks for inspection, service crown. - Wait on parts to repair top drive. - Prep exhaust stacks for painting. - Circulate across top of hole continually & surface to surface every 12 hrs @ 130 GPM 700 psi. Printed: 7/11/2005 10:19:48 AM BP EXPLORATfON Page 14 of 20 Operations Summary Report Legal Well Name: S -111 Common W ell Name: S-111 Spud Date: 5/15/2005 Event Nam e: DRILL+C OMPLE TE Start : 5/15/2005 End: Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 7/8/2005 Rig Name: NABOR S 7ES Rig Number: Date j From - To Hours I Task ! Code ~ NPT i Phase Description of Operations -- L-. _-_ - -- i----' ----~ ---' - ~ -- -------. _ ---- 6/21/2005 12:00 - 00:00 12.00 DRILL N RREP PROD1 -Received top drive parts and began repairing top drive at Nabors shop in Deadhorse. - Prep & paint boiler, motor, & tioga exhaust stacks. - Replace seat in #2 mud pump pulsation dampener. - Clean roof on sub module. - Circulate across top of hole continually & surface to surface every 12 hrs C 130 GPM 700 psi. - Fluid loss for last 24 hrs: 79 bbls. 6!2212005 00:00 - 12:00 12.00 DRILL N RREP PROD1 -Repairing top drive at Nabors shop in Deadhorse. - Grease & service choke manifold valves. - Replace pins on pipe handler grabber. - Prep BOP stack for painting. - Prep blocks for magna-flux. - Take on 290 bbls new mud in pits. - Circulate across top of hole continually & monitor losses. Circulate surface to surface every 12 hrs C~3 130 GPM 700 psi. 12:00 - 00:00 12.00 DRILL N RREP PROD1 -Repairing top drive at Nabors shop in Deadhorse. - Magna-flux blocks -okay. - Cleared plugged grease zerk on blocks. -Clean roof over pits. - Cleaning, scrubbing, & painting various areas on rig. - Losses for Last 24 hrs: 56 bbls. 6!2312005 00:00 - 12:00 12.00 DRILL N RREP PROD1 -Repairing top drive at Nabors shop in Deadhorse. - Set up herculite & containment area and clean outer walls on pit complex. - Paint blocks & rig floor. - Clean under rotary table & rig floor mats. - Circulate across top of hole continually & monitor losses. Circulate surface to surface every 12 hrs. at 130 GPM 700 psi. 12:00 - 00:00 12.00 DRILL N RREP PROD1 -Repairing top drive at Nabors shop in Deadhorse. - General housekeeping & painting. - Circulate across top of hole continually & monitor losses. Circulate surface to surface every 12 hrs at 130 GPM 675 psi. - Losses for last 24 hrs: 59 bbls. 6124!2005 00:00 - 12:00 12.00 DRILL N RREP PRODi -Repairing top drive at Nabors shop in Deadhorse. - Cleaning & painting on rig -mud manifold, choke manifold, cement lines, mud lines, derrick A legs & floors. - Circulate across top of hole continually & monitor losses. Circulate surface to surface every 12 hrs at 130 GPM 700 psi. 12:00 - 14:45 2.75 DRILL N RREP PROD1 -Cleaning & painting on rig. - Replace grease zerks on top drive link pins. - R!D headpin & hose. M!U spare saver sub in stump. 14:45 - 00:00 9.25 DRILL N RREP PROD1 -Repaired top drive arrived on location from Nabors Deadhorse shop. - PJSM with all personnel involved with "critical lift" of top drive to rig floor. - Lift top drive & set on rig floor. P/U top drive with blocks and stab onto upper torque tube. Install torque tube lower section. M/U quill to stump. Remove slings from blocks. Pin top drive to block links. Install service loop & rotary hose. - Losses for last 24 hrs: 46 bbls. 6/25/2005 00:00 - 02:00 2.00 DRILL N RREP PROD1 -Continue with installation of top drive - M!U lower IBOP & Printed: 7/11/2005 10:19:48 AM { BP EXPLORATION Page 15 of 20 Operations Summary Report Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5/1512005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABOBS ALASKA DRILLING f Rig Release: 7!8/2005 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To j Hours I Task ~~C Code NPT ~ Phase ~ Description of Operations 6/25/2005 100:00 - 02:00 2.001 DRILL ~N ~RREP~PRODi !torque washpipe packing. 02:00 - 04:30 I 2.501 BOPSURP 04:30 - 05:00 0.50 DRILL P 05:00 - 05:30 0.50 BOPSU P 05:30 - 09:45 4.25 BOPSU P 09:45 - 11:00 1.25 BOPSU P 11:00 - 13:00 2.00 DRILL N 13:00 - 20:00 7.00 DRILL N 20:00 - 21:30 1.50 DRILL P 21:30 - 00:00 2.50 DRILL N 6/26/2005 00:00 - 02:00 2.00 DRILL N 02:00 - 07:30 5.50 DRILL P 07:30 - 11:00 3.50 DRILL N 11:00 - 19:00 8.00 DRILL N 19:00 - 00:00 5.00 DRILL N 6/27/2005 00:00 - 08:00 8.00 DRILL N "Note: See remarks for top drive repairs /maintenance. PROD1 -Test choke manifold to 250 psi / 4,000 psi. Chart & hold for 5 minutes per test. Witness of test waived by AOGCC Rep. Jeff Jones & witnessed by WSL Mike Dinger. PRODi -Slip & cut drilling line. PROD1 -RIH & set storm packer ~ 60'. Test to 1,000 psi. PROD1 -Test BOPE to 250 psi / 4,000 psi per AOGCC & BP requirements. Chart & hold test for 5 minutes per test. Witness of test waived by AOGCC Rep. Jeff Jones & witnessed by WSL Duncan Ferguson. Annular preventer test pressure 250 psi J 3500 psi. PROD1 - RJD test equip't. - R1H & retrieve storm packer. RREP PROD1 -Circulate & condition mud C~ 270 GPM, 1680 psi. RREP PROD1 -RIH from 11,448' to 13647'. Wash & ream from 11,926' to ; 12,404' & clean uptight spot @ 12,202'. - CBU ~ 13,647 C«~ 195 GPM, 1125 psi. - Continue RIH from 13,647' to 15,847'. Hole slick. - Wash from 15,847' to 15,951' & stage up pumps to drilling rate. PROD1 -Drill directional in 6 314" hole from 15,951' to 15,964'. WOB 5-8K, 270 GPM, 2030 psi, 140 RPM, Tq off bottom 6K, Tq on bottom 7K, P/U wt 165K, S/0 wt i00K, Rot wt 130K. - ART 1.31 hrs, ADT 1.31 hrs. RREP PRODi -Troubleshoot & replace brake disc and calipers on top drive. Rack back one stand of 4" DP and circulate ~ 145 GPM, 950 psi while making repairs to top drive. Clear personne! and move pipe every 15-20 minutes. - Losses for last 24 hrs: 46 bbls. RREP PROD1 -Replace brake disc & calipers on top drive. Shim brake disc. Circulate ~ 145 GPM, 950 psi while making repairs & moving drill string periodically. PROD1 -Drill directional in 6 3/4" hole from 15,964' to 16,164'. WOB 8-10K, 270 GPM, 2050 psi, 140 RPM, Tq on bottom 10K, Tq off 6.5K. P/U wt 175K, S/O wt 100K, Rot wt 130K. - Stringing in Mix II & nut plug for losses while drilling. RREP PROD1 -Troubleshoot problems with top drive & determine traction motor needs changing out. - Circulating while troubleshooting & moving pipe periodically. RREP PROD1 -Pump out of hole to 14,800' due to swab & spot 35 bbl LCM pill @ loss zone. - POH from 14,800' to window. 20K overpull at 12,050' & 11, 950'. - M/U headpin & hose. - PJSM w/ Veco scaffolding crew & rog personnel. - Erect scaffolding on rig floor. RREP PROD1 -Remove traction motor & prepare replacement for installation. - Losses last 24 hrs: 184 bbls. RREP PROD1 -Install traction motor on top drive, hook up electrical, bleed brakes, & test. - RID scaffolding & hook up air hose & rotary hose. Printed: 7!1112005 10:19:48 AM BP EXPLORATION Page 16 of 20 Operations Summary Report Legal Well Name: S-111 Common Weli Name: S-111 Spud Date: 5/15/2005 Event Name: DRILL+COMPLETE Start: 5/15/2005 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/8/2005 Rig Name: NABORS 7ES Rig Number: Date j From - To ~ Hours ~~ Task C Code ~I NPT j Phase Description of Operations ~' ~ - -- -- J __ - 6/27!2005 00:00 - 08:00 B.OO rDRILL N RREP PROD1 08:00 - 10:00 2.00 DRILL N RREP PRODi -RIH washing down last stand. Work through tight spot ~ 10:00 - 00:00 I 14.001 DRILL I P 6/28/2005 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 12.00! DRILL I P 6!29/2005 ~ 00:00 - 07:30 ~ 7.50 ~ DRILL ~ P 12,404' with rotation - no pumps. PRODi - Drilf directional in 6 314" hole from 16,164' to 16,395'. WOB 8-12K, 270 GPM, 2270 psi, 140 RPM, Tq on bottom 9K Tq off bottom 7K, P!U wt 170K, S/O wt 105K, Rot wt 130K, Calc ECD 10.19 ppg, actual ECD 10.44 ppg. -ART 11.1 hrs, ADT 11.1 hrs. - Stringing in Mix II & nut plug to minimize losses. - Losses tapering off to 10 bbls / hr. Lost 140 bbs to formation over last 24 hrs. PROD1 -Drill directional in 6 314" hole from 16,395' to 16857' md. WOB 10-15K, 270 GPM, 2200 psi, 140 RPM, Tq on bottom 11 K, Tq off bottom 7K, P/U wt 175K, S/O wt 95K, Rot wt 130K. PROD1 PROD1 07:30 - 08:30 1.00 DRILL N DFAL PROD1 08:30 - 10:00 1.50 DRILL N DFAL PROD1 10:00 - 11:30 1.50 DRILL N RREP PROD1 11:30 - 18:00 6.50 DRILL N DFAL PROD1 18:00 - 00:00 I 6.001 DRILL I N I DFAL I PROD1 6/30/2005 00:00 - 01:30 1.50 DRILL N DFAL PRODi 01:30 - 02:30 1.00 DRILL N DFAL PROD1 02:30 - 04:00 { 1.501 DRILL I N I DFAL I PROD1 04:00 - 09:00 5.00 DRILL N DFAL PROD1 09:00 - 09:30 0.50 DRILL N RREP PROD1 -Drill directional in 63/4" hole from 16,857 to 17,473' md. WOB 10-15K, 270 GPM 2300 psi, 140 RPM, Tq on bottom 12.5K, Tq off bottom 8K, P/U wt 175K, S/O wt 95K, Rot wt 130K. Calc ECD 10.31 ppg, actual 10.57 ppg. - Lost 30 bbls mud @ 17,000' while crossing fault # 4. (Fault #4 with a 10' downward throw) - ART last 24 hrs: 15.43 hrs, ADT 15.43 hrs. - Losses to formation last 24 hrs: 274 bbls. -Drill directional in 6 3/4" hole from 17,473' to 17,760' md. WOB 10-15K, 270 GPM, 2320 psi, 140 RPM, Tq on bottom 12.5K, Tq off bottom 8K, P/U wt 175K, S/O wt 95K, Rot wt 130K. - ART 3.85 hrs, ADT 3.85 hrs - Unable to reach TD due to rotary steerabie power drive control unit failure. Discuss options w! Anchorage team & decision made to POH and continue drilling after swapping oui tools. - CBU @ 270 GPM, 2300 psi, 100 RPM. - Pump out of hole to 16,060' due to swabbing. - Troubleshoot & make temporary repairs to top drive. Electronics card for traction motor broke loose and shorted out. - Continue pumping out of hole to 11,448'. Periodically attempt to pull without pumps -still swabbing. - Backream & work through tight spot from 12,295' to i 2,010'. - Monitor well -pump dry & POH to BHA. - Losses to formation last 24 hrs: 150 bbls - Rack back collars & jars. UD BHA. - Download ADN & Impulse tool in pipeshed. - Service TD & lubricate rig while downloading BHA. - M/U 6 3/4" DSX111 PDC bit, bias unit, control collar, flex collar, receiver sub, XO, Impulse tool & PWD. Shallow hole test same. - PJSM - M!U ADN & Toad radioactive source. M/U flex collars & jars. - RIH w/ 4" DP filling every 30 stands. - Remove top drive traction motor electronic card & isolate Printed: 7/11/2005 10:19:48 AM BP EXPLORATION Page 17 of 20 Operations Summary Report Legal Well Name: S-111 Common W ell Name: S-111 Spud Date: 5115!2005 Event Nam e: DRILL+C OMPLE TE Start : 5/15/2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To i ~ Hours ~ Task ~ I Code ~ i NPT Phase i Description of Operations --- L I I 6/30/2005 09:00 - 09:30 0.50 DRILL N RREP PROD1 system. Check top drive RPM on both SCR's. 09:30 - 10:30 1.00 DRILL N DFAL PRODi -Pump & spot EMI-920 pill inside casing. 10:30 - 16:30 6.00 DRILL N DFAL PRODi - RIH w/ 4" DP filling every 30 stands. 16:30 - 17:30 1.00 DRILL N DFAL PRODi -Wash down last stand to 17,760' & displace EMI-920 pill out of hole. 17:30 - 00:00 6.50 DRILL P PRODi -Drill directional in 6 3/4" hole from 17,760' to 17,968' md. WOB 10-15K, 275 GPM, 2400 psi, Tq on bottom 10K, Tq off bottom 8K, P!U wt 175K, S/O wt 95K, Rot wt 130K. Calc ECD 10.43 ppg, actual 10.51 ppg. -ART 5.51 hrs, ADT 5.51 hrs. - Losses to formation last 24 hrs: 167 bbls 7/il2005 00:00 - 04:00 4.00 DRILL P PROD1 -Drill directional in 6 3/4" hole from 17,968' to TD ~ 18,090'. WOB 5- 15K, 275 GPM, 2400 psi, 140 RPM, Tq on bottom 11 K, Tq off bottom 8K, PIU wt 175K, S/O wt 95K, Rot wt 130K. - ART 3.51 hrs, ADT 3.5i hrs. 04:00 - 06:30 2.50 DRILL P PRODi -Circulate hi-vis sweep surface to surface 270 GPM, 2375 psi, 140 RPM & reciprocating string. - Calculated ECD 10.39 ppg, final ECD after circulation 10.45 PP9• 06:30 - 07:00 0.50 DRILL P PROD1 -Monitor well -static. Pump 3 stands out of hole. 07:00 - 12:00 5.00 DRILL P PROD1 -Perform madd pass white pumping out of hole from 17,856' to 16,963' ~ 250 GPM, 70 RPM. 12:00 - 19:30 7.50 DRILL P PROD1 -Pump out of hole due to swabbing. 250 GPM, 1500 psi. 19:30 - 22:00 2.50 DRILL P PROD1 -Ream / backream tight spots from 12,015' to 12,280'. Made several passes through area from 12,110' to 12,135'. Cleaned up until able to go through without rotation or pumps. - Continue pumping out of hole to window 22:00 - 00:00 2.00 DRILL P PRODi -Drop rabbit -monitor we{I -static. Puff stand -still swabbing. Continue pumping out of hole additional 10 stands. - Pull 2 stands without pumping to 10,396' - no swab. - Pump dry job. - Losses to formation last 24 hrs: 154 bbls 7!2/2005 00:00 - 02:30 2.50 DRILL P PROD1 - POH & rack back 4" DP from 10,396' to 4,468'. 02:30 - 05:30 3.00 DRILL P PROD1 - POH & UD 4" DP 1 x 1. 05:30 - 07:00 1.50 DRILL P PROD1 - UD jars & flex collars. - PJSM for handling radioactive source. - Pull source & UD BHA. - Clean & clear floor. 07:00 - 08:00 1.00 CASE P PROD1 - R/U to run 4 1/2" liner. 08:00 - 08:30 0.50 CASE P PROD1 -PJSM w/ all personnel involved in running 4 1/2" liner. 08:30 - 13:30 5.00 CASE P PROD1 - M/U float equip't w/ Bakerlok on pin ends of jts #2 & 3. Check floats -floats holding. M/U & run 80 jts 4 1/2" i2.6# L-80 Hydril 521 liner. M/U Tq 4,400 fUlbs & utilizing Jet Lube Seal Guard thread compound on connections. 13:30 - 14:00 0.50 CASE P PRODi -Install 15 centralizers & 30 stop rings in pipeshed on upcoming row of pipe to be run. 14:00 - 14:30 0.50 CASE P PROD1 -Run 15 jts 4 1/2" 12.6# L-80 Hydril 521 liner. 14:30 - 15:30 1.00 CASE P PROD1 -Install 33 centralizers & 66 stop rings in pipeshed on upcoming row of pipe to be run. 15:30 - 16:45 1.25 CASE P PROD1 -Run 33 jts 4 1/2" 12.6# L-80 Hydril 521 liner. 16:45 - 17:45 1.00 CASE P PROD1 -Install 30 centralizers & 60 stop rings in pipeshed on upcoming row of pipe to be run. Printed: 7/11J2005 10:19:48AM i BP EXPLORATION Page 18 of 20 Operations Summary Report Legal Well Name: S-111 Common W ell Name: S-111 Spud Date: 5/15/2005 Event Nam e: DRILL+C OMPLE TE Start : 5/15/2005 End: Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 7/8/2005 Rig Name: NABOB S 7ES Rig Number: Date ~ From - To ~ ~ ~ Hours Task I Code's NPT I~ Phase ~ Description of Operations i ~-- L - - ~ - --- - 712!2005 17:45 - 19:30 1.75 CASE P PRODi -Run 30 jts 4 1/2" 12.6# L-80 Hydril 521 liner. - Total of 161 jts ran 19:30 - 20:00 0.50 CASE P PRODi - M/U 7 5/8" x 5 1/2" liner hanger/ "HRD" ZXP packer. 20:00 - 21:00 1.00 CASE P PROD1 - M/U stand DP & circulate string volume C~3 6 BPM, 525 psi. P/U wt 90K, S/O wt 70K. 21:00 - 00:00 3.00 CASE P PROD1 -RIH w/ liner to top of window on 4" DP. - Circulate string volume @ 6 BPM, 770 psi. - Losses to formation last 24 hrs: 77 bbls 7/3/2005 00:00 - 00:30 0.50 CASE P PRODi -Circulate 1 string volume at top of window. 6 BPM, 770 psi, P/U wt 140K, S/O wt 100K, Rot wt 115K, 30 RPM. 00:30 - 05:00 4.50 CASE P PROD1 -RIH wf 4 1!2" liner on 4" DP in OH. Taking wt C~3 15,648' & 15,695' wf S/O wt 30K. Worked string through first tight spot after several attempts. Washed through tight spot C~ 15,695' w/ pump. 110 GPM, 660 psi. - Lost 72 bbls mud. while running casing. 05:00 - 05:30 0.50 CASE P PROD1 - M!U cementing head, valves, tee, & hoses. 05:30 - 09:30 4.00 CEMT P PROD1 -Stage up pump in preparation for cement job.'iCP @ 1.5 BPM 670 psi, FCP @ 6 BPM 1,100 psi. - PJSM for cementing 09:30 - 10:30 1.00 CEMT P PRODi -Pump 2 bbls fresh water & test lines to 4,000 psi. Pump 15 bbls CW-100, 50 bbis 9.9 ppg Mud Push I1, followed by 235 bbls (1038 sx) Class G cement w/ Glasblok. -Wash up cementers via tee, valve, & hose. 10:30 - 11:30 1.00 CEMT P PRODi -Drop wiper dart & displace cement w/ 100 bbl pert pill & 114 bbls of used flo-pro mud w/ rig pump C~ 6 BPM. Bump plug w/ 95°lo pump efficiency & increase pressure to 4,000 psi. - Set down 75K on hanger. - Bleed off pressure & check floats -floats holding - P/U 7' & release dog sub & set down 50K to set packer. Repeat sequence w/ rotation to ensure packer set. - Pressure up on DP to 1,000 psi & P/U string additional 15'. Circulate 30 bbls once packoff clears seal bore. P/U string additional 30' to clear packoff. - Full returns throughout cement job & displacement. 11:30 - 13:00 1.50 CEMT P PRODi -Circulate out excess cement ~ 400 GPM 1850 psi. - Approximately 60 bbls cement on B/U. 13:00 - 14:00 1.00 CEMT P PRODi -Remove hoses & tee. L/D cementing head. 14:00 - 15:30 1.50 CASE P PRODi -Displace well to 8.9 ppg brine C~3 12 BPM 2200 psi 15:30 - 17:00 1.50 CASE P PROD1 -Slip & cut 165' of drilling line. - Lubricate rig & service top drive. 17:00 - 21:00 4.00 CASE P PROD1 - POH w/ 4" DP. 21:00 - 23:00 2.00 CASE P PROD1 - POH & L/D 75 jts 4" DP 1 x 1. 23:00 - 23:30 0.50 CASE P PROD1 -Make service breaks & lJD Baker running tool. {dog sub sheared) 23:30 - 00:00 0.50 CASE P PROD1 - R/U & test 4 112" liner x 7 5/8" casing to 4,000 psi. Chart & hold for 30 minutes. 7/4/2005 00:00 - 00:30 0.50 CASE P PROD1 -Test 4 1!2" liner x 7 518" casing to 4000 psi. Chart & hold for 30 minutes -good test. - Bleed off & 6/D kill line. 00:30 - 03:00 2.50 CASE P PROD1 - PJSM w/ Schlumberger & rig crew. - M/U 40' perforation guns &RIH. Printed: 7/11/2005 10:19:48 AWt BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 7/4/2005 7!512005 7!6!2005 7/7/2005 From - To 03:00 -04:00 04:00 - 06:00 06:00 - 11:30 11:30 - 12:00 12:00 - 18:30 18:30 - 19:30 S-111 S-111 DRILL+COMPLETE NABOBS ALASKA DRILLING NABOBS 7ES Hours Task CodeLNPT yl 1.00 CASE P 2.00 CASE P 5.50 CASE P 0.50 CASE P 6.50 CASE P 1.00 CASE P Page 19 of 20 Spud Date: 5115/2005 Start: 5/15/2005 End: I Rig Release: 7/8/2005 Rig Number: - - - - - - Description of Operations Phase I - - PROD1 - M/U 18 jts 2 7/8" PAC DP &RIH. PROD1 - M/U 40' perforation guns &RIH. PROD1 - P/U 157 jts 2 7/8" PAC DP 1x1 &RIH. PROD1 - R/D 2 7/8" handling equip't & R/U 4" handling equip't. PROD1 -RIH w/ 2 7/8" perforation guns on 4" DP. PROD1 -PJSM on detonating perforation guns. - M/U top drive & tag landing collar on depth (~ 17,955'. P/U string 5" & close upper pipe rams. Pressure up on DP to 3000 psi & hold for 2 minutes. Bleed off pressure & open pipe rams. Guns detonated. - Monitor well -hole taking fluid. - Planned perforated intervals C 6 shots per foot: 16,180' - 16,250' 16,330' - 16,450' 16,550' - 16,590' 17,200' - 17,300' 17,520' - 17,950' 19:30 - 00:00 4.50 CASE P PROD1 - UD 4" DP while POH w/ perforation guns. - Losses since perforating: 48 bbls. 00:00 - 05:30 5.50 BUNCO RUNCMP UD 237 jts 4" DP while POH with perforation guns. 05:30 - 13:00 7.50 BUNCO RUNCMP UD 4" handling equip't & swap over to 2 7/8" handling equip't. UD 132 jts. 2 7/8" DP while POH w/ perforation guns. Losses C~ 5 bbls/hr. 13:00 - 19:00 6.00 BUNCO RUNCMP UD TCP guns. All shots fired. 19:00 - 21:00 2.00 BUNCO RUNCMP Rig down Schlumberger & clear rig floor. 21:00 - 21:30 0.50 BUNCO RUNCMP Pull and UD wear bushing. 21:30 - 22:00 0.50 BUNCO RUNCMP Make dummy run w/tubing hanger. 22:00 - 23:00 1.00 BUNCO RUNCMP R/U tubing running equipment. 23:00 - 23:30 0.50 BUNCO RUNCMP PJSM before running completion. 23:30 - 00:00 0.50 BUNCO RUNCMP PU and RIH w/completion tailpipe. 00:00 - 22:30 22.50 BUNCO RUNCMP RIH w/5-1/2" tbg. x 7-5/8" packer x 4-1/2" tailpipe completion. Ten jts 5-1/2" TCII would not make up properly per torque turn requirements. Jts backed out and found to have burrs in threads. Changed out one jt. Dressed nine other threads and saw proper makeup w/torque turn. 22:30 - 00:00 1.50 BUNCO RUNCMP Land and space out. Tag up at 11401. Space out w/ WLEG at i 1397'. Run in lock down screws. 00:00 - 02:15 2.25 BUNCO RUNCMP R/U and reverse circulate 100 bbls brine with 1 drum corrosion inhibitor and then 88 bbls clean brine at 3 bbls/min with 240 psi. 02:15 - 04:30 2.25 BUNCO DPRB RUNCMP PJSM. Pressure test lines to 4000. Drop ball and rod, wait 35 minutes for ball and rod to fall and attempt to pressure to 4000 psi to set packer. Ball did not fall to seat. Pump 10 bbls at 3 bbls/min. 280 psi. Did not seat. Wait 15 min. and try again, did not seat. Call for slick line unit to chase ball and rod to seat. 04:30 - 05:00 0.50 BUNCO DPRB RUNCMP Service and lubricate rig. 05:00 - 07:00 2.00 BUNCO DPRB RUNCMP Wait on slickline unit and clear rig floor. Printed: 7!11 /2005 10:19:48 AM BP EXPLORATION Page 20 of 20 Operations Summary Report Legal Well Name: S-111 Common Well Name: S-111 Spud Date: 5/15/2005 Event Name: DRILL+COMPLETE Start: 5!15!2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/8/2005 Rig Name: NABOBS 7ES Rig Number: ~ Date i Fram - To ~ , ~ ~ ~ Hours i Task j Code i NPT i Phase Description of Operations ---- ---! --- -- ~_ _ ~ __ _ __! __ _ 1_-- --' --- - - 7!7/2005 07:00 - 09:00 2.00 BUNCO DPRB RUNCMP PJSM. RU slick line unit. 09:00 - 14:00 5.00 BUNCO DPRB RUNCMP RIH with wireline to 11387' wireline depth, pressure up to confirm ball now on seat. RD lubricator. POH w/wireline. 14:00 - 16:00 2.00 BUNCO RUNCMP Set packer with 4000 psi. Hold pressure in tubing for 30 mins and record on chart. Bleed off to 1500 on tubimg side. Pressure up annulus to 3500 psi to test packer and hold for 30 min. Bleed psi on annulus to 0, bleed tubing psi to 0. Pressure up annulus to 2000 psi and shear DCK valve. Pump 2 bb{ brine both ways and confirm shear of DCK. 16:00 - 16:30 0.50 BUNCO DPRB RUNCMP RD wireline unit. 16:30 - 17:00 0.50 WHSUR P RUNCMP Install two way check valve in tubing hanger and test to 1000 psi from below. 17:00 - 18:30 1.50 WHSUR P RUNCMP ND BOP stack. Secure stack. 18:30 - 20:00 1.50 WHSUR P RUNCMP NU adaptor flange and test to 5000 psi. 20:00 - 22:00 2.00 WHSUR P RUNCMP NU tree and test to 5000 psi. 22:00 - 23:00 1.00 WHSUR P RUNCMP RU lubricator and lubricate two way check valve out of well. 23:00 - 00:00 1.00 WHSUR P RUNCMP PJSM. Rig up hot oil unit and pump diesel freeze protect. Pump 88 bbls., 2 bpm, 575 psi. 7/8/2005 00:00 - 02:00 2.00 WHSUR RUNCMP U-tube diesel and freeze protect annulus and tubing to 2200'. 02:00 - 04:00 2.00 WHSUR RUNCMP RU lubricator and install back pressure valve and test to 1000 psi. Install VR plugs on IA valves. Secure well. Release rig. Printed: 7/11/2005 10:19:48 AM TREE = 7 1 / 16" CNV WELLHEAD = FMC ACTUATOR = LEO' KB ELEV = CB. ELEV = 64.10' AMSL 35.60`AMSL KOP _ ._ _ 400' Max Angle = 96° @ 12,215' Datum MD = 11,624' Datum TVD = 6,880' ~ 5-1111 -~~~ hanger 7" X5 1(2" TGiltubing crossover 10 3/4", 45.5#, L- 80, BTC 4,708 Minimum ID = 3.813" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.88" 6 16180 -16250 O 07/04!05 2.88" 6 16330 -16450 O 07/04!05 2.88" 6 16550 -16590 O 07104/05 2.88" 6 17200 -17300 O 07/04/05 2.88" 6 17520 -17950 O 07/04(05 5 1!2", 17.0#, L-80, TGiltubing 11,223 Baker 7 5/8" X 4 1(2" S-3 Roduction Packer 11,340 Baker 7 5(8" X 4 1/2" Flex-Lock liner hngr, 11,3$7 ZXP pkr, w / TBS 4 1/2", 12.6#, L-80, TGiltubing WLEG 11,397 Baker Whip stock, (Top of w indow } 11,535 HES 7 518" EZSV 11,553 7 5/8", 29.7#, L-80, 12,195 BTGM 11,800 Pup W/ 'RA' Tag r_~- Pup W/'RA' Tag 16,$00 PupW!'RA'Tag PBTD 17,955 4 112", 12.6 #, L-80 Hydri1521 liner 18,040 DATE REV BY COMMENTS DATE REV BY COMMENTS 05/02105 DEW Proposed Comp. (Wp02b, 07) 06(01105 LV / DF Actual Completion PRUDHOE BAY UNCf WELL: 5-1111 PERMff No: 205-051 API No: 50-029-23257 BP Exploration (Alaska} GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 5,414 9,527 3,702 5,815 58 60 KBG-2 KBG-2 DCK DMY BK BK ~~~.~-0 ~,;;` 11,223 5 1!2" X 4 1/2" TGII tubing crossover 11,319 HES 4 1l2" 'X' nipple; I.D. = 3.813" 11,364 HES 4 1/2"'X' nipple; I.D. = 3.813" 11,385 HES 4 1i2"'X' nipple; I.D. = 3.813" i..I S-111 Survey Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: S•PAD / S-111 Well: S-111 Borehole: S-111 UWI/API#: 500292325700 Survey Name /Date: S-111 /June 30, 2005 Tort /AHD / DDI I ERD ratio: 479.964° / 15128.93 ft / 7.276 / 2.177 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70 2121.624, W 149 2 2.860 Location Grld WE Y/X: N 5980730.340 ftUS, E 618930.490 ftUS Grid Convergence Angle: +0.90966782° Grid Scale Factor: 0.99991607 Repo Schlaa~rger Survey / DLSComputation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 345.690° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 64.40 ft relative to MSL Sea Bed /Ground Level Elevation: 35.60 ft relative to MSL .Magnetic Declination:. . 24.718° Total Field Strength: 57588.258 nT Magnetic Dip: 80.881 ° geclinatiori Date.:. June 30, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True Nodh Total Corr Mag North -> True Nortft: +24.718° Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft 'ft ft ' ft de /100 ft ftUS ftUS ~.~~ First GYD GC SS Last GYD GC SS v.vv v.vV v.vv 100.00 0.67 43.93 200.00 0.73 19.31 258.00 1.01 22.64 349.00 1.52 17.00 438.00 1.63 344.77 528.00 1.80 341.86 620.00 2.55 338.43 714.00 3.96 336.62 808.00 4.97 332.16 904.00 7.85 326.42 1028.00 10.36 328.63 1090.00 11.79 331.47 1180.00 13.86 334.14 1280.00 15.33 335.85 First MWD+IFR+MS 1404.53 19.54 334.81 1499.49 25.21 331.98 1593.68 26.54 331.78 1687.93 30.86 329.24 1781.40 36.16 329.01 1876.90 39.00 329.27 1967.35 41.91 330.08 2061.33 42.94 329.92 -VY.VV V.VV v.VV v.vv V.UU V.UU V.UU V.UV JyOU/3U.34 35.60 100.00 0.31 0.58 0.58 0.42 0.41 0.67 5980730.77 135.59 199.99 1.15 1.79 1.77 1.44 1.02 0.30 5980731.80 193.58 257.98 1.86 2.67 2.63 2.26 1.34 0.49 5980732.62 284.56 348.96 3.53 4.68 4.62 4.16 2.00 0.58 5980734.53 373.53 437.93 5.81 7.06 6.81 6.51 2.02 0.99 5980736.88 463.49 527.89 8.50 9.75 9.17 9.09 1.24 0.21 5980739.44 555.42 619.82 11.97 13.24 12.36 12.36 0.04 0.83 5980742.70 649.27 713.67 17.25 18.58 17.41 17.29 -2.02 1.50 5980747.59 742.98 807.38 24.41 25.89 24.43 23.87 -5.21 1.14 5980754.12 838.37 902.77 34.65 35.60 34.72 33.01 -10.78 3.07 5980763.17 960.80 1025.20 53.30 56.22 ' 53.95 49.59 -21.27 2.04 5980779.58 1021.65 1086.05 64.77 -68.13 65.79 59.91 -27.20 2.47 5980789.81 1109.40 1173.80 84.25 88.10 `85.75 77.69 -36.29 2.39 5980807.44 1206.17 1270.57 109.01 113.30 110:94 100.53 -46.92 1.53 5980830.11 1324.95 1389.35 145.70 150.60 148.25 134.41 -62.53 3.39 5980863.73 1412.73 1477.13 180.97 186.73 184.36 166.66 -78.80 6.08 5980895.72 1497.47 1561.87 220.89 227:83 225.42 202.92 -98.18 1.42 5980931.65 1580.13 1644.53 264.53 273:07 270.58 24226 -120.51 4.76 5980970.64 1658.03 1722.43 313.97 324.66 322.03 286.53 -146.99 5.67 5961014.46 1733.71 1798.11 369.Sb 382.90 380:17 336.53 -176.85 2.98 5981063.99 1802.53 1866.93 426.20 441.58 438:80 387:18 -206.47 3.27 5981114.16 1871.90 1936.30 487.24 504.98. 502.17 442.0 _ ' "~3'7"""; ; 1:10 _ 581168.56 C i?,W avr ~~ ~ V V ..f Oltl`JJU.4`J N /U Z~I Ll.t)Z4 618930.89 N 70 21 21.628 618931.49 N 70 21 21.638 618931.79 N 70 21 21.646 618932.43 N 70 21 21.665 618932.40 N 70 21 21.688 618931.58 N 70 21 21.713 618930.33 N 70 21 21.746 618928.20 N 70 21 21.794 618924.90 N 70 21 21.859 618919.19 N 70 21 21.949 618908.44 N 70 21 22.112 618902.35 N 70 21 22.213 618892.97 N 70 21 22.388 618881.98 N 70 21 22.613 618865.84 N 70 21 22.946 618849.06 N 70 21 23.263 618829.11 N 70 21 23.620 618806.16 N 70 21 24.007 618778.99 N 70 21 24.442 618748.33 N 70 21 24.934 618717.91 N 70 21 25.432 618685.35 N 70 21 25.972 VV l4y Z Z.iSbU W 149 2 2.848 W 149 2 2.830 W 149 2 2.821 W 149 2 2.802 W 149 2 2.801 W 149 2 2.824 W 149 2 2.859 W 149 2 2.919 W 149 2 3.012 W 1495 W 149 2 W 149 5 W 149 2 3.921 W 149 2 4.232 W 149 2 4.688 W 149 2 5.164 W 149 2 5.730 W 149 2 6.383 W 149 2 7.157 W 149 2 8.030 W 149 2 8.896 W 149 2 9.823 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\S-111\5-111 current Generated 7112/2005 4:53 PM Page 1 of 9 Comments Measured inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure. ft de de ft ft ft ft it ft ft de /100 ft ftUS ftUS L IJ'1./Y Y/.VV JLO.JJ IyJ/.~/ LUUL,J/ 2248.34 50.22 328.08 1999.85 2064.25 V UU.VJ J/V.yO .000.11. 4y0./y -L/ I.yO 617.54 641.19 638.23 558.53 -308.84 690.68 717.01 714.03 624.48 -346.21 764.99 792.72 789.58 692.93 -378,52 840.57 868.93 .865.24 763.79 -406.54 917.49 946.03 941.31 837.01 -430.66 994.63 1023.20 1016.63 911.77 -449.68 1071.13 1099.82 1090.80 986.93 -464.55 1149.65 1.178.53 19 67.04 1064.38 -478.60 1228.99. .1258.10 1244.30 1142.76 -492.31 1310.01 1339.33 1323.52 1222.73 '-506.59 1392.86 1422.39 1404.80 1304.46 =521:39 1471.76 1501.52 1482.35 1382.38 -535.15 1553.46 1583.45 1562.82 1463.05 -549.44 1634.59 1664.82 1642.84 1543.23 -563.36 1714.66 1745.16 1721.91 1622.43 -576.80 1795.03 1825.73 1801.48 1701.70 -591.22 1878.10 1908.93 1883.87 1783.38 -607.07 1958.61 1989.59 1.963.79 1862:59 -622.28 2041.86 2072.96 2046.53 1944.35 ' -638.57 2124.02 2955.20 2128.28 2024.85 -655.42 2206.08 2237.33 2209.98 2105.21 =672.38 2289.12 2320:43 2292:69 2186'.48 -689.74 2370.84 2402.21 2374.13 2265.41 '' -707.01 2452.20 2483.63 2455.21 2346.04 -724.00 2533.02 2564.55 2535.76 2425.31 -740.23 2614.76 2646.42 2617.20 2505.66 -755.91 2654.74 2686.48,:. .2657.05: 2545.02 -763.39 2761.10 2793:13 .2763.02 2650.00 -782.15 2843.43 2875.75 2845.04 2731.51 -795.68 2924.87 2957.51 2926:22 2812.20 -808.86 3007.10 3040.08 3008.20 2893.73 -821.94 3086.97 3120.34 3087.84 2973.07 -834.04 3167.89 3201.78 3168.54 3053.75 -845.14 3249.60 3284.22 3250.04 3135.63 -854.73 3328.90 3364.43 3329.16 3215.45 -862.65 3407:03 3443.64 3407.15 3294.37 -869.35 4.4/ D`J8lLL4./U n~iunou.o/ IV /UZ"I Zt).bZy VV "14yZ lU.tS'I'I 3.46 5981283.85 618612.85 N 70 21 27.117 W 149 2 11.889 5.10 5981349.20 618574.44 N 70 21 27.766 W 149 2 12.981 3.64 5981417.11 618541.05 N 70 21 28.439 W 149 2 13.926 3.17 5981487.51 618511.91 N 70 21 29.136 W 149 2 14.746 2.72 5981560.34 618486.63 N 70 21 29.856 W 149 2 15.451 4.41 5981634.78 618466.43 N 70 21 30.591 W 149 2 16.007 1.38 5981709.69 618450.37 N 70 21 31.330 W 149 2 16.442 2.19 5981786.90 618435.09 N 70 21 32.092 W 149 2 16.853 0.83 5981865.05 618420.14 N 70 21 32.863 W 149 2 17.254 2.29 5981944.77 618404.60 N 70 21 33.649 W 149 2 1 0.71 5982026.25 618388.50 N 70 21 34.453 W 149 2 0.08 5982103.93 618373.51 N 70 21 35.219 W 149 2 18.507 0.28 5982184.36 618357.94 N 70 21 36.013 W 149 2 18.925 0.74 5982264.30 618342.75 N 70 21 36.801 W 149 2 19.332 0.92 5982343.27 618328.06 N 70 21 37.580 W 149 2 19.725 1.93 5982422.29 618312.38 N 70 21 38.360 W 149 2 20.147 1.17 5982503.71 618295.24 N 70 21 39.163 W 149 2 20.611 0.48 5982582.66 618278.78 N 70 21 39.942 W 149 2 21.055 1.35 5982664.14 618261.19 N 70 21 40.746 W 149 2 21.532 0.01 5982744.36 618243.07 N 70 21 41.538 W 149 2 22.025 0.61 5982824.43 618224.84 N 70 21 42.328 W 149 2 22.521 0.92 59$2905.41 618206.19 N 70 21 43.127 W 149 2 23.029 0.55 59$2985.05 618187.65 N 70 21 43.913 W 149 2 23.534 0.47 5983064.39 618169.40 N 70 21 44.697 W 149 2 24.031 0.56 5983143.39 618151.91 N 70 21 45.476 W 149 2 24.506 0.89 5983223.47 618134.96 N 70 21 46.266 W 149 2 24.965 0.79 5983262.70 618126.86 N 70 21 46.653 W 149 2 184 1.18 5983367.37 618106.44 N 70 21 47.686 W 149 2 0.12 5983448.64 618091.61 N 70 21 48.488 W 149 2 9 0.19 5983529.11 618077.16 N 70 21 49.281 W 149 2 26.514 0.45 5983610.41 618062.78 N 70 21 50.083 W 149 2 26.897 0.71 5983689.54 618049.43 N 70 21 50.863 W 149 2 27.251 0.95 5983770.03 618037.05 N 70 21 51.657 W 149 2 27.576 1.69 5983851.74 618026.16 N 70 21 52.462 W 149 2 27.857 1.05 5983931.41 618016.98 N 70 21 53.247 W 149 2 28.089 1.14 5984010.21 618009.03 N 70 21 54.023 W 149 2 28.285 2344.78 53.50 332.75 2059.42 2123.82 2438.24 54.72 336.67 2114.22 2178.62 2532.07 53.92 340.20 2168.96 2233.36 2627.85 53.32 343.35 2225.78 2290.18 2723.01 55.08 348.05 2281.47 2345.87 2816.27 55.41 349.56 2334.63 2399.03 2910.74 57.46 349.87 2386.86 2451.26 3004.77 58.15 350.29 2436.96 2501.36 3099.37 60.20 349.47 2485.43 2549.83 3195.33 59.70 350.00 2533.48 2597.88 3286.94 59.77 349.98 2579.66 2644.06 3381.89 59.51 349.92 2627.65 2692.05 3476.60 58.94 350.39 2676.11 2740.51 3570.82 58.07 350.35 2725.33 2789.73 3665.03 59.50 349.04 2774.15 2838.55 3761.05 60.62 348.99 2822.08 2886.48 3853.78 60.25 349.28 2867.83 2932.23 3949.40 61.11 348.18 2914.65 2979.05 4043.33 61.12 348.18 2960.03 3024.43 4136.88 61.67 347.99 3004.82 3069.22 4231.68 60.80 347.89 3050.44 3114.84 4325.59 60.31 347.72 3096.60 3161.00 4419.39 60.14 348.19 3143.18 3207.58 4512.55 60.46 348.67 3189.34 3253.74 4606.34 61.13 349.24 3235.10 3299.50 4652.01 61.49 349.24 3257.03 3321.43 4773.91 60.57 350.51 3316.07 3380.47 4868.80 60.52 350.63 3362.73 3427.13 4962.75 60.46 350.82 3409.01 3473.41 5057.85 60.05 350.95 3456.19 3520.59 5150.46 60.08 351.71 3502.41 3566.81 5244.62 59.67 352.63 3549.66 3614.06 5340.69 58.56 354.01 3598.98 3663.38 5435.12 57.74 354.66 3648.81 3713.21 5529.14 57.06 355.64 3699.47 3763.87 5624.51 57.71 355.22 3750.87 3815.27 5718.42 59.59 355.67 3799.73 3864.13 5813.42 60.12 355.51 3847.43 3911.83 5906.13 60.10 353.85 3893.64 3958.04 SurveyEditor Ver SP 1.0 Bid( doc40x_56 ) 3486.21 3523.97 3486.24 3374.45 -875.75 0.78 5984090.17 618001.35 N 70 21 54.811 W 149 2 28.472 3565.24 .3604.17 3565.24 3454.39 -882.12 2.04 5984169.99 617993.72 N 70 21 55.597 W 149 2 28.659 3646:17 3686.32 3646.19 3536.30 -888.44 0.58 5984251.79 617986.10 N 70 21 56.402 W 149 2 28.844 3725.56 3766.69 3725.64 3616.33 -895.89 1.55 5984331.68 617977.38 N 70 21 57.189 W 149 2 29.062 ~. , . ~ ~ ~ ~ V S-1 11\S-111\S-1 11\S-111 rrent ~ ~ ~ ~ ~~(~~~' G ~ t d 7/12/2005 4 53 PM 2 f cu - e nera e : Pag e o 9 . .. . s,. .., _ ' ~.E Comments Measured D inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude epth Section Departure ft de de ft ft ft ft Yt ft ft de 1100 ft ftUS ftUS uvvJ.JC uV.l-f JJG .JJ J~YV.VV 4VVJ.VV J(JVV./ I JUYO.JY JOVO.00 JOy/.J/ -BUJ./L 1.30 Vy0441L./J OI/y00.L0 IV /ULI .7/ .`J00 VV 14yL Ly.35U 6096.27 59.39 351 .94 3988.88 4053.28 3888.91 3931.26 3889.18 3779.52 -917.02 0.87 5984494.50 617953.66 N 70 21 58. 794 W 149 2 29.681 6189.94 59.29 351 .81 4036.64 4101.04 3969.02 4011.84 3969.39 3859.29 -928.41 0.16 5984574.07 617941.01 N 70 21 59. 579 W 149 2 30.014 6285.89 59.51 352 .35 4085.49 4149.89 4051.09 4094.42 4051.59 3941.09 -939.79 0.54 5984655.67 617928.33 N 70 22 0 .383 W 149 2 30.347 6379.85 59.65 352 .23 4133.06 4197.46 4131.58 4175.45 4132.22. 4021.38 -950.66 0.19 5984735.78 617916.19 N 70 22 1. 173 W 149 2 30.665 6474.84 59.88 352 .18 4180.89 4245.29 4213.12 4257.52 4213.92 4102.69 -961.79 0.25 5984816.89 617903.77 N 70 22 1. 973 W 149 2 30.991 6570.13 60.12 352 .54 4228.54 4292.94 4295.08 4340.04 4296.06 4184.48 -972.76 0.41 5984898.49 617891.50 N 70 22 2. 777 W 149 2 31.312 6663.31 60.43 352 .19 4274.74 4339.14 4375.45 442Q.96 4376.62 4264.68 -983.52 0.47 5984978.51 617879.48 N 70 22 3. 566 W 149 2 31.627 6758.68 60.21 351 .64 4321.96 4386.36 4457.82. 4503.82 4459.18 4346.72 -995.17 0.55 5985060.34 617866.53 N 70 22 4. 373 W 149 2 31.968 6852.70 59.78 351 .42 4368.98 4433.38 4538.82 4585.24 4540.36'. 4427.25 -1007.16 0.50 5985140.66 617853.26 N 70 22 5. 165 W 149 2 32.319 6946.12 59.23 350 .37 4416.39 4480.79 4618.98 4(165.73 4620.69 4506.73 -1019.90 1.13 5985219.92 617839.27 N 70 22 5. 946 W 149 2 3 7041.39 59.07 350 .13 4465.24 4529.64 4700.51 4747.52 4702.37 4587.34 -1033.75 0.27 5985300.30 617824.14 N 70 22 6. 739 W 149 2 33. 7137.02 58.82 350 .90 4514.58 4578.98 4782.15 4829.45 4784.17 4668.14 -1047.25 0.74 5985380.87 617809.36 N 70 22 7. 534 W 149 2 33.493 7232.52 58.32 350 .82 4564.37 4628.77 4863.30 4910.94 4865.51 4748.59 -1060.19 0.53 5985461.10 617795.14 N 70 22 8. 325 W 149 2 33.872 7326.67 58.30 351 .04 4613.83 4678.23 4943.08 4991.05 4945.47 4827.70 -1072.82 0.20 5985539.99 617781.26 N 70 22 9. 103 W 149 2 34.242 7419.55 58.46 351 .71 4662.53 4726.93 5021.78 5070.14 5024.38 4905.90 -1084.68 0.64 5985617.98 617768.16 N 70 22 9. 872 W 149 2 34.589 7514.82 58.46 351 .69 4712.36 4776.76 5102.53 5151.34 5105.36 49136.25 -1096.40 0.02 5985698.12 617755.16 N 70 22 10. 662 W 149 2 34.932 7609.96 58.71 352 .08 4761.95 4826.35 5183.25 5232.53 5186.33 5066.63 -1107.86 0.44 5985778.31 617742.43 N 70 22 11. 453 W 149 2 35.268 7703.91 59.14 352 .73 4810.45 4874.85 5263.17 5313.00 5266.53 5146.39 -1118.50 0.75 5985857.88 617730.53 N 70 22 12. 237 W 149 2 35.579 7798.23 59.15 353 .33 4858.82 4923.22 5343.47 5393.97 5347.16 5226.76 -1128.32 0.55 5985938.08 617719.43 N 70 22 13. 028 W 149 2 35.867 7894.94 58.72 352 .47 4908.73 4973.13 5425.66 5476.81. 5429:68 5308.96 -1138.56 0.88 5986020.10 617707.89 N 70 22 13. 836 W 149 2 36.167 7990.23 58.56 352 .46 4958.32 5022.72 5506.46 5558:18 5510.79 5389.63 -1149.23 0.17 5986100.58 617695.94 N 70 22 14. 629 W 149 2 36.479 8085.44 58.48 352 .72 5008.03 5072.43 5587.07 5639.37 5591:73 5470.15 -1159.70 0.25 5986180.92 617684.20 N 70 22 15. 421 W 149 2 36.786 8181.11 58.59 353 .05 5057.97 5122.37 5668.03. 5720.97 5673.04 5551.12 -1169.81 0.32 5986261.72 617672.81 N 70 22 16. 218 W 149 2 37.082 8276.38 58.45 352 .70 5107.72 5172.12 5748.64 5802.22 5754.01 5631.74 -1179.89 0.35 5986342.16 617661.45 N 70 22 17. 010 W 149 2 37.377 8370.59 57.98 351 .87 5157.35 5221.75 5828.19 5882.30 5833.89 5711.10 -1190.64 0.90 5986421.33 617649.44 N 70 22 17. 791 W 149 2 37.692 8464.52 58.03 352 .19 5207.11 5271.51 5907.36 5961.97 5913:38 5789.99 -1201.68 0.29 5986500.03 617637.15 N 70 22 18. 567 W 149 2 38.016 8558.10 57,86 351 .12 5256.78 5321.18 5986.24 6041..28 5992.55 5868.46 -1213.19 0.99 5986578.30 617624.40 N 70 22 19. 338 W 149 2 53 8652.36 57.76 352 .45 5307.00 5371.40 6065.56 6121.05 6072.18 5947,41 -1224.59 1.20 5986657.05 617611.75 N 70 22 20. 115 W 149 2 6 8747.42 58.33 352 .16 5357.31 5421.71 6145.68 6201.70 6152.64 6027:34 -1235.39 0.65 5986736.79 617599.68 N 70 22 20. 901 W 149 2 3 8841.28 59.20 352 .21 5405.98 5470.38 6225.42. 6281.96 6232.73 6106.85 -1246.30 0.93 5986816.11 617587.51 N 70 22 21. 683 W 149 2 39.322 8937.02 60.26 351 .95 5454.24 5518.64 6307.59 6364.64 6315.25 6188.74 -1257.70 1.13 5986897.81 617574.81 N 70 22 22. 488 W 149 2 39.656 9030.86 60.17 351 .67 5500.85 5565.25 6388.57 6446:09 6396.56 6269.36 -1269.30 0.28 5986978.22 617561.94 N 70 22 23. 281 W 149 2 39.996 9126.25 59.99 351 .70 5548.43 5612.83 6470,79 6528.76 6479.11 6351.:17 -1281.26 0.19 5987059.82 617548.68 N 70 22 24. 086 W 149 2 40.346 9221.66 59.83 351 .33 5596.27 5660.67 6552.92 5611.31 6561:56 6432:81 -1293.44 0.38 5987141.26 617535.21 N 70 22 24. 889 W 149 2 40.703 9315.42 59.56 351 .28 5643.58 5707.98 6633.48 6692.26 6642.42 6512.83 -1305.67 0.29 5987221.06 617521.70 N 70 22 25. 676 W 149 2 41.061 9409.72 59.66 351 .54 5691.29 5755.69 6714.41 6773.60 6723.67. 6593.26 -1317.82 0.26 5987301.28 617508.28 N 70 22 26. 467 W 149 2 41.417 9504.00 59.63 351 .61 5738.93 5803.33 6795.34 6854.96.: 6804.93: 6673.74' -1329.74 0.07 5987381.56 617495.09 N 70 22 27. 258 W 149 2 41.767 9598.44 59.89 352 .19 5786.49 5850.89 6876.45 6936:55 6886.39 6754:51 -1341.24 0.60 5987462.13 617482.31 N 70 22 28. 052 W 149 2 42.103 9691.65 59.80 352 .11 5833.32 " 5897.72 6956.53 7017.15 6966:85 6834:35 -1352.25 0.12 5987541.78 617470.04 N 70 22 28. 838 W 149 2 42.426 9785.13 59.71 352 .96 5880.40 5944.80 7036.71 7097.90 7047.43. 6914.42 -1362 7 ~ r5~877~1.6 617458.28 N 70 22 29. 625 W 149 2 42.733 s ,~ ~ `Z kr _ SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\S-111\S-111 current Generated 7/12/2005 4:53 PM Page 3 of 9 y r Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea TVD ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de N ft ft ft ft tt ft de /100 ft ftUS ftUS Tie-In Survey Tp Whpstck (Inc only) Bs Whpstck (Inc only) End of Mill (Inc Only) Blind (Inc only) 9877.65 59.31 352.79 5927.35 5991.75 7115.81 7177.63 7.126:97 6993.54 -1372 .63 0.46 5987700.60 617447.13 N 70 22 30.403 W 149 2 43.023 9972.07 58.61 352.96 5976.03 6040.43 7196.08 7258.53 7207.67 7073.81 -1382. 66 0.76 5987780.70 617435.83 N 70 22 31.193 W 149 2 43.317 10066.96 58.44 353.70 6025.58 6089.98 7276.29 7339.45 7288.36 7154.19 -1392. 06 0.69 5987860.91 617425.15 N 70 22 31.983 W 149 2 43.592 10160.49 57.98 354.15 6074.85 6139.25 7354.97 7418.95 7367.57 7233.24 -1400. 48 0.64 5987939.82 617415.49 N 70 22 32.761 W 149 2 43.839 10253.87 58.08 354.88 6124.29 6188.69 7433.24 7498.17 7446.43 7312.09 -1408. 05 0.67 5988018.53 617406.66 N 70 22 33.536 W 149 2 44.061 10349.49 58.38 355.74 6174.64 6239.04 7513.39 7579.46 7527.25 7393.11 -1414. 69 0.83 5988099.43 617398.73 N 70 22 34.333 W 149 2 44.256 10444.31 58.31 355.62 6224.40 6288.80 7592.88 7660.17 7607.45 7473.60 -1420. 77 0.13 5988179.80 617391.38 N 70 22 35.124 W 149 2 44.434 10538.49 58.10 355.99 6274.02 6338.42 7671,68 7740.22 7686.97 7553.43 -1426. 63 0.40 5988259.52 617384.26 N 70 22 35.909 W 149 2 44.606 10632.35 58.00 356.19 6323.69 6388.09 7750.02 7819.86 7766.08 7632.89 -1432. 06 0.21 5988338.87 617377.56 N 70 22 36.691 W 149 2 44.765 10726.50 58.17 356.30 6373.46 6437.86 7828.58 7899.78: 7845.41 7712.63 -1437. 29. 0.21 5988418.52 617371.07 N 70 22 37.475 W 149 2 44.919 10821.23 58.54 356.07 6423.16 6487.56 7907.88 7980.43 7925.51 7793.10 -1442. 66 0.44 5988498.88 617364.42 N 70 22 38.267 W 149 2 4~ 10916.86 59.27 355.82 6472.55 6536.95 7988.46 8062.31 8006.88 7874.78 -1448. 45 0.80 5988580.46 617357.34 N 70 22 39.070 W 149 2 45. 11012.14 59.33 355.76 6521.20 6585.60 8069.12 8144.24 8088.33 7956.49 -1454. 46 0.08 5988662.05 617350.03 N 70 22 39.873 W 149 2 45.423 11106.68 59.68 353.97 6569.18 6633.58 8149.53 8225.70 8169.46 8037.62 -1461. 76 1.67 5988743.05 617341.45 N 70 22 40.671 W 149 2 45.637 11201.94 59.82 353.02 6617.17 6681.57 8231.06 8307.99 8251.57 8119.38 -1471. 08 0.87 5988824.64 617330.83 N 70 22 41.475 W 149 2 45.910 11296.04 60.42 351.93 6664.05 6728.45 8312.07 8389.58 8333.06 8200.26 -1481. 77 1.19 5988905.34 617318.86 N 70 22 42.271 W 149 2 46.223 11390.27 62.80 352.27 6708.85 6773.25 8394.45 8472.47 8415.88 8282.37 -1493. 16 2.55 5988987.25 617306.17 N 70 22 43.078 W 149 2 46.557 11484.93 65.11 352.56 6750.41 6814.81 8478.90 8557.51 8500.84 8366.66 -1504. 38 2.46 5989071.35 617293.61 N 70 22 43.907 W 149 2 46.886 11536.00 66.53 352.71 6771.32 6835.72 8525.15 8604.10 8547.37 8412.87 -1510. 35 2.79 5989117.45 617286.91 N 70 22 44.362 W 149 2 47.061 11549.00 68.28 351.50 6776.32 6840.72 8537.08 8696.10 8559.36 8424.75 -1512. 00 15.97 5989129.31 617285.07 N 70 22 44.479 W 149 2 47.109 11562.39 67:19 351.50 6781.39 6845.79 11573.96 67.11 350.90 6785.89 6850.29 11602.82 68.23 349.44 6796.85 6861.25 11635.27 70.31 347.82 6808.34 6872.74 11666.52 71.82 346.29 6818.48 6882.88 8549.40 8628.49 6571.75 8437.01 -1513.83 8.14 5989141.53 617283.04 N 70 22 44.599 W 149 2 47.163 8560.02 8639.16 8582.41 8447.55 -1515.46 4.83 5989152.04 617281.24 N 70 22 44.703 W 149 2 47.211 8586.63 8665.85 8609.10 8473.85 -1520.02 6.08 5989178.26 617276.27 N 70 22 44.961 W 149 2 47.344 8616.93 8696:20 8639.44 8503.60 -1526.01 7.93 5989207.91 617269.81 N 70 22 45.254 W 149 2 47.520 8646.48 8725.76 8668.96 8532.40 -1532.63 6.69 5989236.61 617262.73 N 70 22 45.537 W 149 2 47.714 8677.12 8756:39 8699.51 8562.06 -1540.29 6.04 5989266.14 617254.60 N 70 22 45.829 W 149 2 47.938 8707.81 8787:09 8730.05 8591.58 -1548.76 7.36 5989295.51 617245.67 N 70 22 46.119 W 149 2 48.186 8743.65 8823.08 8765.60 8625.56 -1560.57 13.55 5989329.30 617233.32 N 70 22 46.453 W 149 2 32 8768.5 8846.27 8790.16 8648.73 -1570.43 11.93 5989352.31 617223.10 N 70 22 46.681 W 149 1 8800.31 8880.60 8821.42 8678.02 -1584.12 4.39 5989381.38 617208.95 N 70 22 46.969 W 149 2 1 8836.54 8917.64 8857.04 8711.23 -1600.55 5.51 5989414.31 617192.00 N 70 22 47.296 W 149 2 49.702 8867.77 8949.90 8887.66 8739.50 -1616.08 10.84 5989442.33 617176.02 N 70 22 47.574 W 149 2 50.157 8898.58 8982.30 8917.73 8766.87 -1633.39 11.18 5989469.42 617158.27 N 70 22 47.843 W 149 2 50.664 8927.41 9013.15 8945.79 8792.09 -1651.1.5 8.34 5989494.36 617140.11 N 70 22 48.091 W 149 2 51.184 8959.17 9048.02 8976.58 8819.31 -1672.93 15.15 5989521.23 617117.91 N 70 22 48.359 W 149 2 51.822 8983.89 9076.15 9000.43 8839.96 -1692.03 12.34 5989541.56 617098.49 N 70 22 48.562 W 149 2 52.381 9010.75 9107.72 9026.25 13869.88 -1714.75 11.30 5989563.12 617075.43 N 70 22 48.777 W 149 2 53.046 9039.19 9142.71 9053.48 8884.40 -1741.50 14.23 5989585.21 617048.32 N 70 22 48.999 W 149 2 53.829 9062.14 9172.28 9075.37, 8902.03 -1765.24 9.58 5989602.46 617024.30 N 70 22 49.172 W 149 2 54.524 9085:18 9203.37 9097.28 8919.21 -1791.'~r ~ ~;p~... ~8~~. 616998.13 N 70 22 49.341 W 149 2 55.282 ' A~Vf ~ a 4V~~ S-1 11\S-111\S-1 11\S-111 current _ Ge nerated 7/12/2 005 4:53 PM Page 4 of 9 F ~ 11698.65 73.09 344.75 6828.16 6892.56 Last Blind (Inc Only) 11730.59 74.94 343.24 6836.96 6901.36 MWD+IFR+MS 11767.70 76.84 338.44 6846.01 6910.41 11793.51 77.93 335.49 6851.65 6916.05 11826.51 78.93 334.42 6858.27 6922.67 11864.17 80.40 332.93 6865.02 6929.42 11896.84 81.44 329.50 6870.18 6934.58 11929.57 82.13 325.87 6874.86 6939.26 11960.66 83.76 323.84 6878.68 6943.08 11995.68 85.62 318.85 6881.92 6946.32 12023.87 86.85 315.59 6883.77 6948.17 12055.47 88.40 312.37 6885.08 6949.48 12090.46 90.42 307.82 6885.44 6949.84 12120.04 91.86 305.38 6884.85 6949.25 12151.15 92.61 301.71 6883.64 6948.04 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Comments Measured h Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole. Closure NS EW DLS Northing Easting Latitude Longitude Dept Section Departure ft de de ft ft ft ft 8 ft ft de /100 ft ftUS ftUS is io~.4i aw.va ~yo.uo 00o i.io oa4o. ~o a-~u~.oa atoo.o.s y.,~_its.~ts uyao:[y -ltSly.l l 1L.11 5yt5yb:i4.tSb blbyby.yL N /U1"L 4y.4yy W 14y 2 56.101 12216.97 96.40 294.87 6878.69 6943.09 9129.46 9268.99 9'1.39.15 8950:16 -1848.97 11.77 5989649.25 616939.83 N 70 22 49.645 W 149 2 56.975 12234.31 97.26 293.33 6876.63 6941.03 9140.16 9286.20 9149.22 8957.19 -1864.68 10.12 5989656.03 616924.01 N 70 22 49.714 W 149 2 57.435 12269.82 97.58 291.35 6872.04 6936.44 9161.18 9321.42 9169.01 8970.57 -1897.25 5.60 5989668.89 616891.24 N 70 22 49.846 W 149 2 58.388 12302.84 97.29 289.51 6867.77 6932.17 9179.84 9354.16 97 86:58 8982.00 -1927.93 5.59 5989679.83 616860.38 N 70 22 49.958 W 149 2 59.286 12335.54 97.13 289.30 6863.66 6928.06 9197.84 9386.60 9203.58 8992.78 -1958.53 0.80 5989690.12 616829.62 N 70 22 50.064 W 149 3 0.182 12365.23 96.85 289.11 6860.05 6924.45 9214.12 9416.07 9219.01 9002.47 -1986.36 1.14 5989699.37 616801.64 N 70 22 50.159 W 149 3 0.996. Tie-In Survey 12398.64 96.55 289.39 6856.15 6920.55 9232.46 9449.25 9236.49 9013.41 -2017.69 1.22 5989709.81 616770.15 N 70 22 50.267 W 149 3 1.913 MWD+IFR+MS 12428.37 96.65 284.18 6652.68 6917.08 9247:..70 9A78.78 9251.01 9021.94.. -2045.95 17.43 5989717.89 616741.76 N 70 22 50.351 W 149 3 2.740 12459.46 93.85 286.71 6849.78 6914.18 9263.06 9509.73 9265.69. 9030.:18. -2075.78 12.60 5989725.65 616711.80 N 70 22 50.432 W 149 3 3.614 12492.43 93.55 285.48 6847.65 6912.05 9279.71 9542:63 9281.71 9039:30 -2107.39 3.83 5989734.27 616680.05 N 70 22 50.521 W 149 3 4 12524.34 93.72 286.06 6845.63 6910.03 9295.68 9574.48 9297.13 9047.96 -2138.03 1.89 5989742.44 616649.28 N 70 22 50.606 W 149 3 12556.14 93.89 286.08 6843.52 6907.92 9311.72 9606.21 9312.74 9056.74 -2168.52 0.54 5989750.74 616618.65 N 70 22 50.693 W 149 3 12588.27 94.23 286.05 6841.25 6905.65 9327.93 9638.26 9328.57 9065.61 -2199.32 1.06 5989759.11 616587.72 N 70 22 50.780 W 149 3 7.230 12619.83 93.10 285.96 6839.23 6903.63 9343.83 9669.75 9344:1.9 9074.29 -2229.60 3.59 5989767.32 616557.31 N 70 22 50.865 W 149 3 8.116 12650.78 90.42 287.05 6838.28 6902.68 9359.67 9700.68 9359.84 9083.08 -2259.25 9.35 5989775.63 616527.52 N 70 22 50.951 W 149 3 8.984 12682.86 90.15 285.48 6838.12 6902.52 9375.99 9732.76 9376.03 9092.07 -2290.05 4.97 5989784.12 616496.59 N 70 22 51.040 W 149 3 9.885 12715.08 89.33 284.68 6838.26 6902.66 9391.80 9764.98 9391.80 9100.45 -2321.16 3.56 5989792.01 616465.36 N 70 22 51.122 W 149 3 10.796 12747.60 90.18 284.47 6838.40 6902.80 9407.51 9797.50 9407.55 9108.63 -2352.63 2.69 5989799.69 616433.76 N 70 22 51.202 W 149 3 11.717 12779.98 91.45 284.93 6837.94 6902.34 9423.21 9829.88 9423.38 9.118.85 -2383.95 4.17 5989807.41 616402.32 N 70 22 51.283 W 149 3 12.634 12812.08 91.73 286.40 6837.05 6901.45 9439.24 9861.96 9439.62 9125.51 -2414.84 4.66 5989815.58 616371.30 N 70 22 51.368 W 149 3 13.538 12843.39 90.46 284.86 6836.45 6900.85 9454.86 9893.27 9455.52 9133.94 -2444.99 6.37 5989823.53 616341.02 N 70 22 51.451 W 149 3 14.421 12874.62 90.84 285.57 6836.10 6900.50 9470.25 9924.50 9471.27 9142.14 -2475.12 2.58 5989831.25 616310.77 N 70 22 51.532 W 149 3 15.303 12907.13 90.66 285.27 6835.67 6900.07 9486.37 9957.00 9487.84 9150.78 -2506.46 1.08 5989839.39 616279.30 N 70 22 51.616 W 149 3 16.220 12938.19 90.90 284.52 6835.25 6899.65 9501.53 9988.06 9503.51 9158.77 -2536.47 2.54 5989846.90 616249.16 N 70 22 51.695 W 149 3 17.098 12970.50 90.84 287.01 6834.76 6899.16 9517.72 10020.37 9520.30 9167.54 -2567.56 7.71 5989855.18 616217.94 N 70 22 51.781 W 149 3 18.008 13002.71 90.87 287.24 6834.28 6898.68 9534.51 10052.57 9537.78 9177.03 -2598.34 0.72 5989864.17 616187.02 N 70 22 51.874 W 149 3 18.909 13033.92 91.08 286.51 6833.75 6898.15 9550.67 10083.78 9554.66 9186.08 -2628.20 2.43 5989872.76 616157.02 N 70 22 51.963 W 149 3 19.783 13069.22 91.04 286.45 6833.10 6897.50 9568.74 10119.07 9573.64 9196..1.0 -2662.04 0.20 5989882.23 616123.03 N 70 22 52.062 W 149 3 20.774 13100.09 90.12 288.33 6832.78 6897.18 9584.96 10149.94 9590.73 9205.32 -2691.50 6.78 5989890.98 616093.43 N 70 22 52.152 W 149 3~6 13130.90 89.64 288.98 6832.85 6897.25 9601.72 10180.75 9608.42 9215.18 -2720.69 2.62 5989900.37 616064.09 N 70 22 52.249 W 149 3 22.491 13165.46 90.15 288.31 6832.91 6897.31 9620.52 10215.31 9628.33 9226.23 -2753.44 2.44 5989910.90 616031.17 N 70 22 52.358 W 149 3 23.449 13196.57 89.77 288.81 6832.93 6897.33 9637.41 10246.42 9646.28 9236.13 -2782.93 2.02 5989920.33 616001.53 N 70 22 52.455 W 149 3 24.313 13226.96 89.05 288.35 6833.25 6897.65 9653.91 10276.81 9663.89 9245.81 -2811.73 2.81 5989929.56 615972.58 N 70 22 52.550 W 149 3 25.156 13261.14 89.46 290.53 6833.69 6898.09 9672.89 10310.99 9684:19 9257.18 -2843.96 6.49 5989940.42 615940.18 N 70 22 52.662 W 149 3 26.099 13292.00 88.33 289.14 6834.29 6898.69 9690.21 10341.84 9702.75 9267.65 -2872.98 5.80 5989950.42 615911.00 N 70 22 52.765 W 149 3 26.949 13322.13 88.54 287.52 6835.11 6899.51 9706.46 10371:96 9720.30 9277.13 -2901.57 5.42 5989959.44 615882.26 N 70 22 52.858 W 149 3 27.786 13354.47 88.71 289.79 6835.88 6900.28 9724.05 10404.29 9739.34 9287.47 -2932.20 7.04 5989969.29 615851.47 N 70 22 52.959 W 149 3 28.682 13386.65 88.16 293.29 6836.76 6901.16 9742.8$ 10436.46 9759.64 9299.27 -2962.12 11.01 5989980.62 615821.38 N 70 22 53.075 W 149 3 29.558 13415.89 87.20 297.56 6837.95 6902.35 9761.55 10465.67 9779.62 9311.81 -2988.50 14.96 5989992.74 615794.80 N 70 22 53.198 W 149 3 30.330 13449.37 87.44 300.02 6839.51 6903.91 9784.40 10499.12 9$03.94 9327.92 -30€1T B't ` ~ 7 37 '. 5+(~90~0.38 ~„ 615765.25 N 70 22 53.357 W 149 3 31.188 SurveyEditor Ver SP 1.0 Bld( doc40x_56) 5-1111S-111\S-111\5-111 current ~. ., Gen ,. erated 7/12/2 005 4:53 PM Page 5 of 9 ., Comments Measured inclination Azimuth SulrSea TV0 ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de /100 ft ftUS ftUS I J4oU.oy 13512.30 13544.60 13575.81 13607.85 13640.56 13671.98 13703.66 13736.09 13767.10 13799.11 13831.27 13864.02 13895.63 oo. J r 87.72 87.13 87.58 87.61 88.67 90.77 90.56 89.94 89.88 89.94 89.70 89.91 90.90 JU4.lo 004U.oo OyUD.UO yoU/.10 IUOJV.4I `JtlLtl.U4 `J344.0`J -3U44.LL 306.76 6841.74 6906.14 9831.41 10562.01 9853.56 9363.15 -3069.85 305.78 6843.19 6907.59 9856.33 10594.27 9879.82 9382.24 -3095.87 305.75 6844.63 6909.03 9880.24 10625.45 9905.07 9400.46 -3121.17 308.38 306.87 306.13 308.93 306.67 307.10 303.12 301.46 299.90 298.22 6845.97 6847.04 6847.19 6846.82 6846.68 6846.73 6846.78 6846.88 6846.99 6846.77 13923.83 90.26 306.39 6846.48 13969.77 88.08 306.86 .6847.15 13988.40 87.13 309.41 6847.93 14019.76 86.45 310.37 6849.68 14050.69 87.88 305.73 6851.21 14083.95 90.80 304.64 6851,60 14114.15 90.15 305.83 6851.35 14146.59 90.57 305.75 6851.14 14179.49 90.43 308.74 6850.85 14210.83 88.88 310.61 6851.04 14242.70 67.47 313.56 6852.06 14275.25 86.37 312.60 6853.81 14307.23 87.15 311.42 6855.61 14338.51 88.82 307.99 6856.72 14370.67 88.85 307.17 6857.37 14401.89 88.49 304.14 6858.09 14434.38 87.96 303.89 6859.10 14464.83 88.17 302.10 6860.13 14497.99 89.34 303.01 6860.85 14530.28 90.30 303.55 6860.95 14561.85 87.06 307.95 6861.68 14593.76 85.73 306.73 6863.68 14625.25 85.53 304.62 6866.08 14657.70 87.64 304.55 6868.02 14689.04 89.33 301,21 6868.85 14721.28 89.67 301.45 6869.13 14753.04 89.19 297.41 6869.44 6910.37 9905.25 6911.44 9930.99 6911.59 9955.34 6911.22 9980.24 6911.08 10005.84 6911.13 10030.00 6911.18 10054.31 6911.28 10077.67 6911.39 10100.83 6911.17 10122.53 6910.88 10143.01 6911.55 10178.67 6912.33 10193.43 6914.08 10218.82 6915.61 10243.27 6916.00 10268.56 6915.75 10291..54 6915.54 10316.42 6915.25 10342.19 6915.44 10367.53 6916.46 10394.06 6918.21 10421.44 6920.01 10448.01 6921.12 10473.30 6921.77 10498.fiQ 6922.49 10522.49 6923.50 10546.75 6924.53 10569.11 6925.25 10593.31 6925.35 10617.15 6926.08 10641.34 6928.08 10666.31 6930.48 10690.36 6932.42 10714.76 6933.25 10737.74 6933.53 10760.79 6933.84 10782.74 10657.46 10690.15 10721.57 10753.25 10785.68 10816.69 10848.70 108&0.86 10913.61. 10945.22 10973.42 11019.35 11037.96 11069.27 11100.16 11133.42 11.163.62 11.196.06 11228.95 11260.29 11292.15 11324.65 11356.58 11387.84 11419.99 11451.20 11483.68 11514.11 11547.26 11579.55 11611,11 11642.95 11674.35 11706.74 11738.07 11770.31 11802.07 9931.44 9958.59 9984.37 10010.71. 10037:79 10063.44 10089.38 10114.53 10139.59 10:1:.63.24 10185.38 10223.57 10239.33 10266.35 10292.52 10319.81 10344.64 10371.52 10399.27 1 Q426.41 10454.67 10483.78 10512.13 10539.31. 1 Q568.88 10592.71 10619.30 10643:94 10670.66 10696.96 10723.45 10750.69 10777.08 10804.01 10829.54 10$55.34 10880.14 9419.75 -3146.71 9439.71 -3172.60 9458.40 -3197.86 9477.70 -3222.98 9497.57 -3248.60 9516.18 -3273.40 9534.59 -3299.58 9551.77. -3326.77 9568.48 -3354.93 9583.83 -3382.56 9598.89 -3406.37 9626.29 -3443.24 9637.78 -3457.88 9657.86 -3481.90 9676.90 -3506.22 9696.06 -3533.40 9713.48 -3558.06 9732.45 -3584.38 9752.36 -3610.56 9772.37 -3634.68 9793.71 -3658.32 9895.91 -3682.06 9837.28 -3705.78 9857.25 -3729.83 9876,$6 -3755.31 9895.05 -3780.67 9913.21 -3807.59 9929.79 -3833.11 9947.63 -3861.05 9965.34 -3888.05 9983.78 -3913.65 10003.09 -3938.97 10021.40 -3964.48 10039.79 -3991.14 10056.79 -4017.45 10073.56 -4044.99 10089.16 -4072.64 15.4t5 ~99UUL4./L 1i15/St5.5/ N /U LL 5;5.5L1 W 149 3 :i1.9(i2 6.59 5990042.77 615712.65 N 70 22 53.703 W 149 3 32.712 3.54 5990061.45 615686.34 N 70 22 53.891 W 149 3 33.474 1.45 5990079.26 615660.76 N 70 22 54.070 W 149 3 34.214 8.20 5990098.14 615634.91 N 70 22 54.259 W 149 3 34.962 5.64 5990117.69 615608.71 N 70 22 54.456 W 149 3 35.720 7.09 5990135.97 615583.16 N 70 22 54.639 W 149 3 36.460 8.86 5990154.86 615557.74 N 70 22 54.829 W 149 3 37.195 7.23 5990174.33 615531.81 N 70 22 55.024 W 149 3 37.946 1.40 5990192.54 615506.72 N 70 22 55.207 W 149 3 38.672 12.44 5990210.53 615480.25 N 70 22 55.388 W 149 3 3 5.22 5990227.27 615452.80 N 70 22 55.557 W 149 3 4 4.81 5990243.53 615424.37 N 70 22 55.721 W 149 3 41. 6.17 5990258.44 615396.51 N 70 22 55.872 W 149 3 41.868 29.06 5990273.12 615372.46 N 70 22 56.020 W 149 3 42.565 4.85 5990299.93 615335.17 N 70 22 56.289 W 149 3 43.644 14.60 5990311.19 615320.35 N 70 22 56.402 W 149 3 44.073 3.75 5990330.88 615296.01 N 70 22 56.600 W 149 3 44.776 15.68 5990349.53 615271.40 N 70 22 56.787 W 149 3 45.489 9.37 5990368.25 615243.92 N 70 22 56.975 W 149 3 46.284 4.49 5990385.28 615218.98 N 70 22 57.146 W 149 3 47.007 1.32 5990403.83 615192.37 N 70 22 57.333 W 149 3 47.777 9.10 5990423.32 615165.88 N 70 22 57.528 W 149 3 48.544 7.75 5990442.94 615141.44 N 70 22 57.725 W 149 3 49.250 10.25 5990463.90 615117.47 N 70 22 57.935 W 149 3 49.942 4.48 5990485.72 615093.39 N 70 22 58.153 W 149 3 50.637 4.42 5990506.71 615069.33 N 70 22 58.363 W 149 3 51.332 12.19 5990526.29 615044.97 N 70 22 58.559 W 149 3 52.036 2.55 5990545.49 615019.18 N 70 22 58.752 W 149 3~3 9.77 5990563.27 614993.54 N 70 22 58.931 W 149 3 5 1.80 5990581.01 614966.34 N 70 22 59.109 W 149 3 54.313 5.92 5990597.17 614940.56 N 70 22 59.272 W 149 3 55.061 4.47 5990614.56 614912.34 N 70 22 59.448 W 149 3 55.879 3.41 5990631.85 614885.07 N 70 22 59.622 W 149 3 56.669 17.30 5990649.87 614859.18 N 70 22 59.803 W 149 3 57.419 5.65 5990668.78 614833.56 N 70 22 59.993 W 149 3 58.160 6.71 5990686.68 614807.77 N 70 23 0.173 W 149 3 58.907 6.51 5990704.64 614780.82 N 70 23 0.353 W 149 3 59.688 11.94 5990721.23 614754.25 N 70 23 0.520 W 149 4 0.458 1.29 5990737.55 614726.45 N 70 23 0.685 W 149 4 1.265 12.81 5990752.71 614698.55 N 70 23 0.838 W 149 4 2.074 SurveyEditor Ver SP 1.0 Bld( doc40x_56) 'S-111\S-1.11\S-111\S-111 current Generated 7/12/2005 4:53 PM Page 6 of 9 Comments Measured Inclination Azimuth Sub-Sea ND 7Vp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departpre ft de de ft ft ft fE ft ft ft de 1100 ft ftUS ftUS iwi oo.LO ~u.oL L50.LU oooa.ou oa33.yu ivou3.r 1 l Io34.LO lUau4.L1 lU-IU3.43 -4lV"1.51 b.l/ DyyU/bb.bZ b14669.4b N /U L3 U .9/9 W 14942.920 14817.17 92.59 293.44 6868.60 6933.00 10823.63 11866.18 10927.34 10116.57 -4130.59 8.27 5990779.19 614640.18 N 70 23 1 .108 W 149 4 3.771 14846.64 93.22 293.21 6867.11 6931.51 10841.60 11895.61 10948.36 10128.22 -4157.61 2.28 5990790.42 614612.98 N 70 23 1 .222 W 149 4 4.562 14878.28 93.10 293.26 6865.36 6929.76 10860.85 11927.21 10970.94 10140.69 -4186.64 0.41 5990802.41 614583.76 N 70 23 1 .345 W 149 4 5.412 14911.64 92.00 296.81 6863.88 6928.28 10881.98 11960.53 10995.52 10154.79 -4216.83 11.13 5990816.03 614553.35 N 70 23 1 .483 W 149 4 6.296 14942.92 89.62 297.52 6863.44 6927.84 10902.69 11991.81 11019,39 10169.07 -4244.66 7.94 5990829.87 614525.30 N 70 23 1 .623 W 149 4 7.111 14973.54 89.98 297.91 6863.54 6927.94 10923.19 12022.43 11042.99 10183.31 -4271.76 1.73 5990843.67 614497.98 N 70 23 1 .763 W 149 4 7.905 14998.47 89.34 296.68 6863.69 6928.09 10939.74 12047.36 11062.12 10194.74 -4293.92 5.56 5990854.75 614475.65 N 70 23 1 .876 W 149 4 8.553 15039.94 88.28 296.33 6864.55 6928.95 10966.84 12088.82 11093.60. 10213.24 -4331.02 2.69 5990872.66 614438.26 N 70 23 2 .057 W 149 4 9.640 15070.76 88.70 296.21 6865.37 6929.77 10986.88' 12119.63 11116.96' 10226.88 -4358.65 1.42 5990885.86 614410.42 N 70 23 2 .191 W 149 4 10.449 15102.35 88.77 295.21 6866.06 6930.46 11007.19 12151.21 11140.74 10240.58 -4387.10 3.17 5990899.10 614381.75 N 70 23 2 .326 W 149 4 11 15133.88 89.13 291.93 6866.64 6931.04 11026.54 12182.73 11163.72 10253.1 B -4415.99 10.46 5990911.25 614352.67 N 70 23 2 .450 W 149 4 1 15165.92 89.62 291.27 6866.99 6931.39 11045.33 12214.77 11186.36 10264.98 -4445.78 2.57 5990922.56 614322.70 N 70 23 2 .566 W 149 4 1 . 15198.42 89.83 291.63 6867.15 6931.55 11064.33 12247.27 11209.31 10276.86 -4476.03 1.28 5990933.97 614292.27 N 70 23 2 .682 W 149 4 13.886 15228.71 89.88 290.53 6867.22 6931.62 11081.87 12277.56 11230.61 10287.75 -4504.29 3.64 5990944.41 614263.84 N 70 23 2 .789 W 149 4 14.713 First MWD+IFR: AK 15262.57 89.85 288.19 6867.30 6931.70 11100.64 12311.42 11253.73 10298.98 -4536.23 6.91 5990955.12 614231.72 N 70 23 2 .899 W 149 4 15.649 15294.92 89.19 287.72 6867.57 6931.97 11117.91 12343.77 11275.28 10308.95 -4567.01 2.50 5990964.61 614200.80 N 70 23 2 .997 W 149 4 16.550 15326.46 89.59 288.38 6867.91 6932.31 11134.79 12375.31 11296.39 10318.72 -4596.99 2.45 5990973.90 614170.66 N 70 23 3 .093 W 149 4 17.428 15357.92 90.00 286.01 6868.02 6932.42 11151.23 124b6.77 11317.14 10328.02 -4627.05 7.65 5990982.72 614140.47 N 70 23 3 .184 W 149 4 18.307 15390.46 90.93 285.92 6867.76 6932.16 11167.63 12439.31 11338.92 10336.97 -4658.33 2.87 5990991.17 614109.05 N 70 23 3 .272 W 149 4 19.223 15420.87 92.19 287.58 6866.93 6931.33 11183.32 12469.70 11358.09 10345.13 -4687.44 6.85 5990999.47 614079.81 N 70 23 3 .358 W 149 4 20.076 15453.63 92.88 286.88 6865.48 6929.88 11200.43 12502.43 11379.85 10355.43 -4718.69 3.00 5991008.66 614048.41 N 70 23 3 .453 W 149 4 20.991 15486.47 93.13 284.98 6863.76 6928.16 11216.95 12535.23 11401.14 10364:43 -4750.23 5.83 5991017.16 614016.74 N 70 23 3 .542 W 149 4 21.914 15518.09 94.71 286.77 6861.60 6926.00 11232.81 12566.77 11421.65 10373.05 -4780.57 7.54 5991025.31 613986.26 N 70 23 3 .626 W 149 4 22.802 15549.81 96.52 285.70 6858.49 6922.89 11248.85 1259$.34 11442.38 10381.88 -4810.88 6.62 5991033.65 613955.82 N 70 23 3 .713 W 149 4 23:690 15581.50 97.70 286.12 6854.57 6918.97 11264.68 12629.78 11.462.94 10390.50 -4841.12 3.95 5991041.79 613925.45 N 70 23 3 .798 W 149 4 24.575 15613.60 98.07 287.06 6850.17 6914.57 11281.01 12661.58 11484.06 10399.58 -4871.59 3.12 5991050.38 613894.84 N 70 23 3 .887 W 149 4 25.467 15645.05 97.48 287.80 6845.91 6910.31 11297.40 12692.74 11505.15 10408.91, -4901.32 2.99 5991059.24 613864.97 N 70 23 3 .978 W 149 4 26.338 15677.49 97.69 288.12 6841.63 6906.03 11314.57 12724.90 11527.17 10418.83 -4931.91 1.17 5991068.67 613834.23 N 70 23 4 .076 W 149 4 3 15709.84 97.75 289.37 6837.29 6901.69 11332.05 12756.95 11549.49 10429.13 -4962.27 3.83 5991078.48 613803.72 N 70 23 4 .177 W 149 4 2 ~ 15741.04 98.07 289.30 6832.99 6897.39 11349.18 12787.86 11571.28 10439.36 -4991.43 1.05 5991088.25 613774.40 N 70 23 4 .277 W 149 4 28.976 15773.04 97.98 289.74 6828.53 6892.93 11366.82 12819.54 11.593.74 10449.95 -5021.29 1.39 5991098.36 613744.37 N 70 23 4 .381 W 149 4 29.851 15805.58 98.26 291.28 6823.93 6888.33 11385.21 12851.76 11617.00 10461.23 -5051.46 4.76 5991109.17 613714.03 N 70 23 4 .492 W 149 4 30.734 15837.23 98.03 291.32 6819.44 6883.84 11403.45 12883.09 11639.96 10472.62 -5080.65 0.74 5991120.08 613684.67 N 70 23 4 .604 W 149 4 31.589 15869.39 97.97 292.04 6814.97 6879.37 11422.1.7 12914.93 11663.48 10484.38 -5110.25 2.22 5991131.37 613654.89 N 70 23 4 .719 W 149 4 32.455 15901.76 97.96 293.16 6810.48 6874.88 11441.42 12946.99 11687.54 10496.70 -5139.84 3.43 5991143.22 613625.11 N 70 23 4 .840 W 149 4 33.322 15933.94 96.48 295.46 6806.44 6870.84 11461.34 12928.92 11712.1(1 10509.84 -5168.93 8.45 5991155.90 613595.81 N 70 23 4 .969 W 149 4 34.174 15965.94 94.82 295.52 6803.29 6867.69 11481.73 13010.76 11737.16 10523.55 -5197.68 5.19 5991169.14 613566.86 N 70 23 5 .104 W 149 4 35.016 Last MWD+IFR: AK 15995.93 93.85 294.97 6801.02 6865.42 11500.77 13040.66 11760.58 10536.30 -5224.72 3.72 5991181.47 613539.61 N 70 23 5 .229 W 149 4 35.808 MWD+IFR+MS 16031.66 91.88 298.40 6799.23 6863.63 11524.18 13076.35 11789.'12 10552.32 -5256.60 11.06 5991196.98 613507.49 N 70 23 5 .386 W 149 4 36.741 16063.43 89.42 297.80 6798.87 6863.27 11545.60 13108.11 11815:02 10567.28 -5284.62 7.97 5991211.49 613479.24 N 70 23 5 .533 W 149 4 37.562 -°° + *~ ~ t ~ ~~, f _ '.. SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-1 11\S-111\S-111\S-111 current p~ rr ~~ rr +~Ut7 S p Ge d ~ Z~~~ nerated 7/12/2005 4:53 PM Pa e 7 of 9 9 r. ~. Comments Measured Depth Inclination Azimuth Sub-Sea TVD TVD Vertical Section Along Hole Departure Closure NS EW DLS Northing Easting Latitude Longitude ft de de ft ft k ft ft ft ' ft de /100 k kUS ftUS Ivval.4o oo.r~ ca/.o4 veyy.~3 16124.19 88. 85 298.00 6800.02 16160.51 89. 86 299.80 6800.43 16189.28 89. 81 302.17 6800.51 16220.90 88. 29 303.11 6801.03 16253.28 87. 76 302.74 6802.15 16285.08 87. 50 302.45 6803.47 16319.40 87.09 303.42 6805.08 16351.98 86.83 303.11 6806.81 16379.64 86.39 303.49 6808.45 16415.48 86.36 303.73 6810.71 16445.04 85.44 305.23 6812.83 16475.59 83.97 305.41 6815.65 16510.79 83.25 305.55 6819.56 16539.82 82.66 304.50 6823.13 16572.85 81.93 304.10 6827.55 16607.65 82.04 305.03 6832.41 16638.86 82.13 304.87 6836.70 16666.32 82.50 304.78 6840.38 16702.97 82.61 305.71 6845.12 16731.87 83.14 307.10 6846.71 16763.41 83.16 306.74 6852.47 16794.33 82.93 306.52 6856.22 16826.20 83.56 306.09 6859.96 16858.19 84.88 306.04 6863.19 16889.85 86.25 307.16 6865.63 16921.49 87.04 307.81 6867.49 16953.75 87.78 306.96 6868.94 16983.99 88.72 307.29 6869.87 17012.00 89.64 307.22 6870.27 17050.03 89.23 307.94 6870.64 17080.74 89.72 307.98 6870.92 17116.90 90.09 307.22 6870.98 17144.89 90.25 306.94 6870.90 17176.12 90.56 306.88 6870.68 17208.50 90.37 307.53 6870.42 17240.72 90.07 306.34 6870.29 17276.87 .89.39 306.17 6870.46 17305.06 89.05 306.69 6870.85 17335.79 89.51 306.44 6871.23 17370.83 90.70 306.81 6871.17 OOOJ. / 3 I 1004.4U 6864.42 11586.39 6864.83 11611.26 6864.91 11631.70 6865.43 11654.81 6866.55 11678.56 6867.87 11701.77 6869.48 11726.94 6871.21 11750.95. 6872.85 11771.35 6875.11 11797.89 6877.23 11820.07 6880.05 11843.25 6883.96 11869.96 6887.53 11891.82 6891.95 11916.37 6896.81 11942.33 6901.10 11965.75 6904.78 11986.33 6909.52 12013.99 6913.11 12036.18 6916.87 12060.60 6920.62 12084.43 6924.36 12108.89 6927.59 12133.41 6930.03 12157.91 6931.89 12182.72 6933.34 12208.01 6934.27 12231.65 6934.67 12253.59 6935.04 12283:51 6935.32 12307.7 6935.38 12336.25 6935.30 12358.:12 6935.08 12382.47 6934.82 12407.81 6934.69 12432.94 6934.86 12460.86 6935.25 12482.69 6935.63 12506.52 6935.57 12533.73 l 3'130. 14 lTtl6/. tSL 1U3L5U.30 -OSUy.41 13168.86 11864.50 10595.69 -5338.32 13205.18 11894.49 10613.24 -5370.12 13233:95 11918:85 10628.05 -5394.78 13265.56 11946.12 10645.10 -5421.40 13297.92 11974.13 10662.69 -5448.56 13329.70 12001.56 10679.$0. -5475.33 13363.98 12031.29 10698.44 -5504.10 13396.51. 12059.6t 10716.29 -5531.31 13424.12` 12083.67 10731.45 -5554.39 13459.89 12114.96 10751.25 -5584.17 13489.38 12140.98 10767.94 -5608.48 13519.80 12168.05 10785.52 -5633.30 13554.78 12199.25. 10805.83 -5661.78 13583.59 12224.85 10822.36 -5685.38 13616.32 12253.77 10840.81 -5712.42 13650.78 12284.30 10860.36 -5740.79 13681.69 13708.90 13745.25 13773.92 13805.24 13835.93 13867.58 13899.40 13930.97 13962.55 13994.78 14025.01 14053.01 14Q91.04 14:121.75 14157.91 14185.90 14217.13 14249.51 14281.73 14317.88 14346.06 14376.79 1441..1.83 12311.81 12336.01 12368.46 12394:34 12422.74 12450.52 12479.10 12507.81 12536.41 12565:25 12594.67 12622.22 12647.78 12882.59 12710.t3Q 12743.93 12769.49 12797.99 12827.61 12857.03 12889.89 12915.56 12943.513 12975.57 10878.07 -5766.13 10893.61 -5788.47 10914.58 -5818.15 10931.60 -5841.23 10950.41 -5866.26 10968.72 -5890.89 10987.46 -5916.40 11006.20 -5942.13 11025.02 -5967.47 11.044.24 -5992.53 11063.80 -6018.14 11082.05 -6042.24 11099:00. -6064.53 11122..19 -6094.66 11141.1)$ -6118.88 11163.14 -6147.53 11180.02 -6169.86 11.198.78 -6194.83 11218.35 -6220.61 11.237.71 -6246.37 11259.09 -6275.52 11275.83 -6298.20 11294.14 -6322.88 11315.04 -6351.00 L.4/ 5aa1[[4.1ts b13454.L5 N /U 23 S.fiEi2 W 149 4 38.288 0.61 5991239.04 613425.10 N 70 23 5.812 W 149 4 39.134 5.68 5991256.08 613393.03 N 70 23 5.985 W 149 4 40.065 8.24 5991270.49 613368.14 N 70 23 6.130 W 149 4 40.788 5.65 5991287.12 613341.25 N 70 23 6.298 W 149 4 41.567 2.00 5991304.27 613313.81 N 70 23 6.470 W 149 4 42.363 1.22 5991320.96 613286.78 N 70 23 6.639 W 149 4 43.147 3.07 5991339.14 613257.72 N 70 23 6.822 W 149 4 43.990 1.24 5991356.55 613230.24 N 70 23 6.997 W 149 4 44.786 2.10 5991371.34 613206.92 N 70 23 7.146 W 149 4 45.462 0.67 5991390.66 613176.83 N 70 23 7.340 W 149 4 4 5.94 5991406.96 613152.26 N 70 23 7.504 W 149 4 4~ 4.85 5991424.15 613127.17 N 70 23 7.677 W 149 4 47.774 2.08 5991444.00 613098.37 N 70 23 7.877 W 149 4 48.608 4.13 5991460.15 613074.52 N 70 23 8.039 W 149 4 49.299 2.51 5991478.17 613047.19 N 70 23 8.220 W 149 4 50.091 2.67 5991497.26 613018.51 N 70 23 8.412 W 149 4 50.922 0.58 5991514.57 612992.90 N 70 23 8.586 W 149 4 51.664 1.39 5991529.75 612970.32 N 70 23 8.739 W 149 4 52.319 2.53 5991550.24 612940.31 N 70 23 8.945 W 149 4 53.188 5.11 5991566.89 612916.96 N 70 23 9.112 W 149 4 53.864 1.14 5991585.30 612891.64 N 70 23 9.297 W 149 4 54.597 1.03 5991603.22 612866.72 N 70 23 9.477 W 149 4 55.319 2.39 5991621.55 612840.92 N 70 23 9.661 W 149 4 56.066 4.13 5991639.87 612814.90 N 70 23 9.845 W 149 4 56.820 5.58 5991658.29 612789.27 N 70 23 10.030 W 149 4 57.562 3.23 5991677.11 612763.91 N 70 23 10.219 W 149 4 58.296 3.49 5991696.26 612738.00 N 70 23 10.411 W 149 4 46 3.29 5991714.12 612713.61 N 70 23 10.590 W 149 42 3.29 5991730.72 612691.06 N 70 23 10.757 W 149 5 2.18 5991753.42 612660.56 N 70 23 10.985 W 149 5 1.288 1.60 5991771.93 612636.05 N 70 23 11.170 W 149 5 1.997 2.34 5991793.53 612607.06 N 70 23 11.387 W 149 5 2.837 1.15 5991810.05 612584.46 N 70 23 11.553 W 149 5 3.491 1.01 5991828.40 612559.20 N 70 23 11.737 W 149 5 4.222 2.09 5991847.57 612533.11 N 70 23 11.929 W 149 5 4.978 3.81 5991866.51 612507.05 N 70 23 12.120 W 149 5 5.732 1.94 5991887.42 612477.57 N 70 23 12.330 W 149 5 6.586 2.20 5991903.80 612454.63 N 70 23 12.494 W 149 5 7.250 1.70 5991921.71 612429.66 N 70 23 12.674 W 149 5 7.973 3.56 5991942.16 612401.22 N 70 23 12.879 W 149 5 8.797 SurveyEditor Ver SP 1.0 Bld( doc40x_56) '5-111\S-111\S-111\S-111 current Generated 7/12!2005 4:53 PM Page 8 of 9 ,. G Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 it ftUS itUS I/~v~..// /I.J~/ ./V/./G vV/V.J.7 VJJY.JJ ILJJU.~V IYYYJ.J/ I'JVVJ.VV 1IJJY.:]V -VJ/V.J/ J.UV :J~y ISO I.LI 17429.97 91.90 307.57 6869.82 6934.22 12580.16 14470.96 13029.91 11350.98 -6397.94 2.08 5991977.35 17466.49 92.90 306.37 6868.29 6932.69 12608.62 14507.44 13063.34 11372.92 -6427.09 4.27 5991998.83 17498.04 92.93 306.11 6866.69 6931.09 12632.96 14538.95" 13092A7 11391.55 -6452.51 0.63 5992017.05 17527.77 93.81 305.25 6864.94 6929.34 12655.69 14568.63 13119.02 11408.86 -6476.61 4.14 5992033.97 17562.24 94.90 305.13 6862.33 6926.73 12681.82 14603.00 13150.12 11428.67: -6504.70 3.18 5992053.33 17591.14 95.02 304.93 6859.83 6924.23 12703.66 14631.79 13176.15 11445.20 -6528.28 0.80 5992069.48 17624.13 94.63 303.51 6857.05 6921.45 12728.29 14664.67 ' 13205.68 . 11463.68 -6555.46 4.45 5992087.53 17658.52 94.21 303.80 6854.40 6918.80 12753.76 14698.95 , 13236`.36 11482.68 -6584.00 1.48 5992106.07 17687,92 93.79 304.34 6852.35 6916.75 12775.69 14728.28; 1.3262.70 11499.11 -6608.30 2.32 5992122.11 17718.78 93.34 304.34 6850.43 6914.83 12798.89 14759.08 13290.44 11516.49. -6633.73 1.46 5992139.08 MWD+IFR: AK 17751.10 92.67 302.50 6848.74 6913.14 12822.69 14791.36 13319.30 11534.26 -6660.66 6.05 5992156.42 17783.52 93.04 302.15 6847.12 6911.52 12846.23 14823.74 13347.98 11551.58 -6688.03 1.57 5992173.30 17816.08 94.84 301.81 6844.88 6909.28 12869.71 14856.22 13376.68 11568.78 -6715.58 5.63 5992190.06 17847.20 96.41 301.22 6841.83 6906.23 12891.92 14887.19 13403.95 11584.97 -6741.98 5.39 5992205.83 17879.49 96.78 300.32 6838.13 6902.53 12914.63 14919.26 13432.00 11601.38 -6769.54 3.00 5992221.80 17910.59 96.02 299.00 6834.66 6899.06 12936.09 14950.17 13458.75 11616.67 -6796.40 4.87 5992236.66 17945.43 95.49 299.90 6831.17 6895.57 12960.06 14984.83 13488.72. 11633.72 -6826.58 2.99 5992253.22 17977.58 95.51 300.01 6828.08 6892.48 12982..40 15016.84:. 1.3516.54 11649.69 -6854.31 0.35 5992268.76 18005.15 94.77 299.33 6825.61 6890.01 13001.47 15044.29 13540.36 11663.29 -6878.17 3.64 5992281.97 Last MWD+IFR: AK 18049.45 94.16 299.45 6822.17 6886.57 13031.98 15088.46 13578.60 11684.96 -6916.65 1.40 5992303.02 TD (Projected) 18090.00 92.90 299.14 6819.67 6884.07 13059.89 15128.93 13613.63 11704.76 -6951.94 3.20 5992322.26 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees incli nation. ) MWD +IFR + MS - (In-field referenced MWD with mutt-station analys is and correction applied in post-processing. Assumes a BHA sag corre ction is applied to enhance inclinati on accuracy. ) MWD +IFR: AK [Alaska] - (In-field referenced MWD in Alaska. Model takes account of increased violence of magnetic field disturbances in Alask: Assumes a BHA sag correction is appl ied to enhance inclination. accuracy.) Legal Descriation: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4526 FSL 4497 FEL S35 T12N R12E UM 5980730.34 618930.49 BHL : 388 FSL 873 FEL S16 T12N R12E U M 5992322.26 611.794.21 O ILJ/O.34 IV /U L3 -13.U/U VV l4y D y.04b 612353.71 N 70 23 13.232 W 149 5 10.173 612324.22 N 70 23 13.448 W 149 5 11.027 612298.51 N 70 23 13.631 W 149 5 11.771 612274.14 N 70 23 13.801 W 149 5 12.477 612245.74 N 70 23 13.995 W 149 5 13.300 612221.91 N 70 23 14.158 W 149 5 13.991 612194.44 N 70 23 14.339 W 149 5 14.787 612165.60 N 70 23 14.526 W 149 5 15.623 612141.05 N 70 23 14.687 W 149 5 16.335 612115.35 N 70 23 14.858 W 149 5 17 612088.13 N 70 23 15.033 W 149 51 612060.50 N 70 23 15.203 W 149 5 18.671 612032.68 N 70 23 15.372 W 149 5 19.478 612006.03 N 70 23 15.531 W 149 5 20.251 611978.22 N 70 23 15.692 W 149 5 21.058 611951.12 N 70 23 15.842 W 149 5 21.845 611920.67 N 70 23 16.009 W 149 5 22.729 611892.70 N 70 23 16.166 W 149 5 23.542 611868.63 N 70 23 16.300 W 149 5 24.240 611829.81 N 70 23 16.512 W 149 5 25.368 611794.21 N 70 23 16.707 W 149 5 26.402 • ~`, ~ - ~~ ~ ~~ SurveyEditor Ver SP 1.0 Bld( doc40x_56) 'S-111\S`111\S-111\5-111 curre'ht, "`" ~ ~ Generated 7/12/2005 4:53 PM Page 9 of 9 ~ ,yt; ~., ~ . w ~~ .~ w w~ w w ... ~- ~ i i ra ~ ~urveV rcepori Client: BP Exploration Alaska Vertical Section Azimuth: 345.690° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 fi Structure I Slot: S-PAD / S-111 TVD Reference Datum: Rotary Table Well: S-111 TVD Reference Elevation: 64.40 ft relative to MSL Borehole: S-111 P61 Sea Bed /Ground Level Elevation: 35.60 ft relative io MSL UWI/API#: 500292325770 Magnetic Declination: 24.62° Survey Name /Date: S-111 PBt /May 24, 2005 Total Field Strength: 57627.222 nT Tort IAHD / DDI / ERD ratio: 140.634° / 9223.94 ft / 6.348 / 1.299 Magnetic Dip: 80.849° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: 14•May-05 Location LaULong: N 70 21 21.624, W 149 2 2.860 Magnetic Declination Model: BGGM 2004 Location Grid NIE Y/X: N 5980730.340 ftUS, E 618930.490 ftUS North Reference: True North Grid Convergence Angle: +0.90966782° Total Corr Mag North -> True North: +24.605° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head v.VU u.uu v.vv u.vv u.vu u.uu oaaursu.3w 0.31 0.58 0.58 0.42 0.41 0.67 5980730.77 1.15 1.79 1.77 1.44 1.02 0.30 5980731.80 1.86 2.67 2.63 2.26 1.34 0.49 5980732.62 3.53 4.68 4.82 4.16 2.00 0.58 5980734.53 5.81 7.06 6.81 6.51 2.02 0.99 5980736.88 8.50 9.75 9.17 9.09 1.24 0.21 5980739.44 11.97 13.24 12.36 12.36 0.04 0.83 5980742.70 17.25 18.58 17.41 17.29 -2.02 1.50 5980747.59 24.41 25.89 24.43 23.87 -5.21 1.14 5980754.12 34.65 36.60 34.72 33.01 -10.78 3.07 5980763.17 53.30 56.22 53.95 49.59 -21.27 2.04 5980779.58 64.77 68.13 65.79 59.91 -27.20 2.47 5980789.81 84.25 88.10 85.75 77.69 -36.29 2.39 5980807.44 109.01 113.30 110.94 100.53 -46.92 1.53 5980830.11 145.70 150.60 148.25 134.41 -62.53 3.39 5980863.73 180.97 186.73 184.36 166.66 -78.80 6.08 5980895.72 220.89 227.83 225.42 202.92 -98.18 1.42 5980931.65 264.53 273.07 270.58 242.26 -120.51 4.76 5980970.64 313.97 324.66 322.03 286.53 -146.99 5.67 5981014,48 369.80 382.90 380.17 336.53 -176.85 2.98 5981063.99 426.20 441.58 438.80 387.18 -206.47 3.27 5981114,16 487.24 504.98 502.17 442.09 - ~ `' ~'6Q' f 59811F~8,56 n t ., i~ .' Comments Measured Depth Inclination Azimuth Sub-Sea TVD TVp Vertical Section Along Hole Departure Closure NS EW DLS Northing Easting Latitude Longitude ft d de ft ft ft ft ft ft h de /100 ft ftUS ftUS ~~~~ v. V.VV -VY.YV V.VV First GYD GC SS 100.00 0.67 43.93 35.60 100.00 200.00 0.73 19.31 135.59 199.99 258.00 1.01 22.64 193.58 257.98 349.00 1.52 17.00 284.56 348.96 438.00 1.63 344.77 373.53 437.93 528.00 1.80 341.86 463.49 527.89 620.00 2.55 338.43 555.42 619.82 714.00 3.96 336.62 649.27 713.67 808.00 4.97 332.16 742.98 807.38 904.00 7.85 326.42 838.37 902.77 1028.00 10.36 328.63 960.80 1025.20 1090.00 11.79 331.47 1021.65 1086.05 1180.00 13.86 334.14 1109.40 1173.80 Last GYD GC SS 1280.00 15.33 335.85 1206.17 1270.57 First MWD+IFR+MS 1404.53 19.54 334.81 1324.95 1389.35 1499.49 25.21 331.98 1412.73 1477.13 1593.68 26.54 331.78 1497.47 1561.87 1687.93 30.86 329.24 1580.13 1644.53 1781.40 36.16 329.01 1658.03 1722.43 1876.90 39.00 329.27 1733.71 1798.11 1967.35 41.91 330.08 1802.53 1866.93 2061.33 42.94 329.92 1871.90 1936.30 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) • bltl`JJV.4`J N /U L1 Z~I.bL4 VV "14`J Z Z.t36U 618930.89 N 70 21 21.628 W 149 2 2.848 618931.49 N 70 21 21.638 W 149 2 2.830 618931.79 N 70 21 21.646 W 149 2 2.821 618932.43 N 70 21 21.665 W 149 2 2.802 618932.40 N 70 21 21.688 W 149 2 2.801 618931.58 N 70 21 21.713 W 149 2 2.824 618930.33 N 70 21 21.746 W 149 2 2.859 618928.20 N 70 21 21.794 W 149 2 2.919 618924.90 N 70 21 21.859 W 149 2 3.012 618919.19 N 70 21 21.949 W 149 ~~ 618908.44 N 70 21 22.112 W 149 618902.35 N 70 21 22.213 W 149 2 5 618892.97 N 70 21 22.388 W 149 2 3.921 618881.98 N 70 21 22.613 W 149 2 4.232 618865.84 N 70 21 22.946 W 149 2 4.688 618849.06 N 70 21 23.263 W 149 2 5.164 618829.11 N 70 21 23.620 W 149 2 5.730 618806.16 N 70 21 24.007 W 149 2 6.383 618778.99 N 70 21 24.442 W 149 2 7.157 618748.33 N 70 21 24.934 W 149 2 8.030 618717.91 N 70 21 25.432 W 149 2 8.896 618685.35 N 70 21 25.972 W 149 2 9.823 S-11115-111\S-111PB11S-111PB1 Generated 6/6/20052:40 PM Page 1 of4 3, Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft tt de 100 ft ftUS ftUS .!Y 2248.34 2344.78 2438.24 2532.07 2627.85 2723.01 2816.27 2910.74 3004.77 3099.37 3195.33 3286.94 3381.89 3476.60 3570.82 3665.03 Y/.VV 50.22 53.50 54.72 53.92 53.32 55.08 55.41 57.46 58.15 60.20 59.70 59.77 59.51 58.94 58.07 59.50 1071.13 1149.65 1228.99 1310.01 1392.66 1471.76 1553.46 1634.59 1714.66 1795.03 1878.10 1958.61 2041.86 2124.02 2206.08 2289.12 2370.84 2452.20 2533.02 2614.76 JL V.JJ 1.7J/.~/ LVVL.J/ JJV.JJ J/V..70 VOO.11 328.08 1999.85 2064.25 617.54 641.19 638.23 332.75 336.67 340.20 343.35 348.05 349.56 349.87 350.29 349.47 350.00 349.98 349.92 350.39 350.35 349.04 2059.42 2114.22 2168.96 2225.78 2281.47 2334.63 2386.86 2436.96 2485.43 2533.48 2579.66 2627.65 2676.11 2725.33 2774.15 2123.82 690. 68 717.01 714.03 2178.62 764. 99 792.72 789.58 2233.36 840. 57 868.93 865.24 2290.18 917. 49 946.03 941.31 2345.87 994. 63 1023.20 1016.63 2399.03 2451.26 2501.36 2549.83 2597.88 2644.06 2692.05 2740.51 2789.73 2838.55 3761. 05 60.62 348.99 2822.08 2886.48 3853. 78 60.25 349.28 2867.83 2932.23 3949. 40 61.11 348.18 2914.65 2979.05 4043. 33 61.12 348.18 2960.03 3024.43 4136. 88 61.67 347.99 3004.82 3069.22 4231. 68 60.80 347.89 3050.44 3114.84 4325. 59 60.31 347.72 3096.60 3161.00 4419. 39 60.14 348.19 3143.18 3207.58 4512. 55 60.46 348.67 3189.34 3253.74 4606. 34 61.13 349.24 3235.10 3299.50 4652.01 4773.91 4868.80 4962.75 5057.85 5150.46 5244.62 5340.69 5435.12 5529.14 5624.51 5718.42 5813.42 5906.13 61.49 349.24 3257.03 3321.43 2654.74 60.57 350.51 3316.07 3380.47 2761.10 60.52 350.63 3362.73 3427.13 2643.43 60.46 350.82 3409.01 3473.41 2924.87 60.05 350.95 3456.19 3520.59 3007.10 60.08 59.67 58.56 57.74 57.06 351.71 352.63 354.01 354.66 355.64 3502.41 3566.81 3086.97 3549.66 3614.06 3167.89 3598.98 3663.38 3249.60 3648.81 3713.21 3328.90 3699.47 3763.87 3407.03 57.71 59.59 60.12 60.10 SurveyEditor Ver SP 1.0 Bid( doc40x_56 355.22 355.67 355.51 353.85 1099.82 1178.53 1258.10 1339.33 1422.39 1501.52 1583.45 1664.82 1745.16 1825.73 1908.93 1989.59 2072.96 2155.20 2237.33 2320.43 2402.21 2483.63 2564.55 2646.42 2686.48 2793.13 2875.75 2957.51 3040.08 3120.34 3201.78 3284.22 3364.43 3443.64 1090.80 1167.04 1244.30 1323.52 1404.80 1482.35 1562.82 1642.84 1721.91 1801.48 1883.87 1963.79 2046.53 2128.28 2209.98 2292.69 2374.13 2455.21 2535.76 2617.20 2657.05 2763.02 2845.04 2926.22 3008.20 3087.84 3168.54 3250.04 3329.16 3407.15 4y0.ly -L/ I.yb 4.4! D~t5lLL4./U 558. 53 -308.84 3.46 5981283.85 624. 48 -346.21 5.10 5981349.20 692. 93 -378.52 3.64 5981417.11 763. 79 -406.54 3.17 5981487.51 837. 01 -430.66 2.72 5981560.34 911. 77 -449.68 4.41 5981634.78 986. 93 -464.55 1.38 5981709.69 1064. 38 -478.60 2.19 5981786.90 1142. 76 -492.31 0.83 5981865.05 1222. 73 -506.59 2.29 5981944.77 1304. 46 -521.39 0.71 5982026.25 1382. 38 -535.15 0.08 5982103.93 1463. 05 -549.44 0.28 5982184.36 1543. 23 -563.36 0.74 5982264.30 1622. 43 -576.80 0.92 5982343.27 1701. 70 -591.22 1.93 5982422.29 1783.38 1862.59 1944.35 2024.85 2105.21 2186.48 2266.41 2346.04 2425.31 2505.66 2545.02 2650.00 2731.51 2812.20 2893.73 2973.07 3053.75 3135.63 3215.45 3294.37 3750.87 3815.27 3486.21 3523.97 3486.24 3374.45 3799.73 3864.13 3565.24 3604.17 3565.24 3454.39 3847.43 3911.83 3646.17 3686.32 3646.19 3536.30 3893.64 3958.04 3725.56 3766.69 3725.64 3616.33 S-111\S-111\S-111 P61\S-111 PB1 -607.07 1.17 5982503.71 -622.28 0.48 5982582.66 -638.57 1.35 5982664.14 -655.42 0.01 5982744.36 -672.38 0.61 5982824.43 -689.74 0.92 5982905.41 -707.01 0.55 5982985.05 -724.00 0.47 5983064.39 -740.23 0.56 5983143.39 -755.91 0.89 5983223.47 -763.39 0.79 5983262.70 -782.15 1.18 5983367.37 -795.68 0.12 5983448.64 -808.86., 0.19 5983529.11 -821.94 0.45 5983610.41 -834.04 0.71 5983689.54 -845.14 0.95 5983770.03 -854.73 1.69 5983851.74 -862.65 1.05 5983931.41 -869.35 1.14 5984010.21 -875.75 0.78 5984090.17 -882.12 2.04 5984169.99 -888.44 0.58 5984251.79 -895.89 1.55 5984331.68 ~,il~~ r ~~~ ~i,~G ~, ~ ~UU~ bltlbOU.b/ IV /U Z1 Lb.bZ`J VV "14`J~ Z 9U.t519 618612.85 N 70 21 27.117 W 149 2 11.889 618574.44 N 70 21 27.766 W 149 2 12.981 618541.05 N 70 21 28.439 W 149 2 13.926 618511.91 N 70 21 29.136 W 149 2 14.746 618486.63 N 70 21 29.856 W 149 2 15.451 618466.43 N 70 21 30.591 W 149 2 16.007 618450.37 N 70 21 31.330 W 149 2 16.442 618435.09 N 70 21 32.092 W 149 2 16.853 618420.14 N 70 21 32.863 W 149 2 17.254 618404.60 N 70 21 33.649 W 149 2 17 618388.50 N 70 21 34.453 W 149 2 1 618373.51 N 70 21 35.219 W 149 2 18.507 618357.94 N 70 21 36.013 W 149 2 18.925 618342.75 N 70 21 36.801 W 149 2 19.332 618328.06 N 70 21 37.580 W 149 2 19.725 618312.38 N 70 21 38.360 W 149 2 20.147 618295.24 N 70 21 39.163 W 149 2 20.611 618278.78 N 70 21 39.942 W 149 2 21.055 618261.19 N 70 21 40.746 W 149 2 21.532 618243.07 N 70 21 41.538 W 149 2 22.025 618224.84 N 70 21 42.328 W 149 2 22.521 618206.19 N 70 21 43.127 W 149 2 23.029 618187.65 N 70 21 43.913 W 149 2 23.534 618169.40 N 70 21 44.697 W 149 2 24.031 618151.91 N 70 21 45.476 W 149 2 24.506 618134.96 N 70 21 46.266 W 149 2 24.965 618126.86 N 70 21 46.653 W 149 2 2 84 618106.44 N 70 21 47.686 W 149 2 618091.61 N 70 21 48.488 W 149 2 618077.16 N 70 21 49.281 W 149 2 26.514 618062.78 N 70 21 50.083 W 149 2 26.897 618049.43 N 70 21 50.863 W 149 2 27.251 618037.05 N 70 21 51.657 W 149 2 27.576 618026.16 N 70 21 52.462 W 149 2 27.857 618016.98 N 70 21 53.247 W 149 2 28.089 618009.03 N 70 21 54.023 W 149 2 28.285 618001.35 N 70 21 54.811 W 149 2 28.472 617993.72 N 70 21 55.597 W 149 2 28.659 617986.10 N 70 21 56.402 W 149 2 28.844 617977.38 N 70 21 57.189 W 149 2 29.062 Generated 6/6/2005 2:40 PM Page 2 of 4 Comments Measured D Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude epth Section Departure ft de de ft ft ft ft ft ft it de I1D0 ft ftUS ftUS 6096 .27 59 .39 351 .94 6189 .94 59 .29 351 .81 6285 .89 59 .51 352 .35 6379 .85 59 .65 352 .23 6474 .84 59 .88 352 .18 6570.13 6663.31 6758.68 6852.70 6946.12 7041.39 7137.02 7232.52 7326.67 7419.55 7514.82 7609.96 7703.91 7798.23 7894.94 7990.23 8085.44 8181.11 8276.38 8370.59 8464.52 8558.10 8652.36 8747.42 8841.28 60.12 60.43 60.21 59.78 59.23 352.54 352.19 351.64 351.42 350.37 8937.02 9030.86 9126.25 9221.66 9315.42 JuT V.VV TVVJ.VV JUVV.I I JUY V.JY JV VV.UV JV5/.J/ 3988.88 4036.64 4085.49 4133.06 4180.89 4228.54 4274.74 4321.96 4368.98 4416.39 4053.28 4101.04 4149.89 4197.46 4245.29 4292.94 4339.14 4386.36 4433.38 4480.79 3888.91 3969.02 4051.09 4131.58 4213.12 4295.08 4375.45 4457.82 4538.82 4618.98 4700.51 4782.15 4863.30 4943.08 5021.78 3931.26 3889.18 3779.52 4011.84 3969,39 3859.29 4094.42 4051.59 3941.09 4175.45 4132.22 4021.38 4257.52 4213.92 4102.69 59.07 350.13 4465.24 4529.64 58.82 350.90 4514.58 4578.98 58.32 350.82 4564.37 4628.77 58.30 351.04 4613.83 4678.23 58.46 351.71 4662.53 4726.93 5506.46 5587.07 5668.03 5748.64 5828.19 5907.36 5986.24 6065.56 6145.68 6225.42 6307.59 6388.57 6470.79 6552.92 6633.48 6714.41 6795.34 6876.45 6956.53 7036.71 58.46 351. 69 4712.36 4776.76 5102.53 5151. 34 58.71 352. 08 4761.95 4826.35 5183.25 5232. 53 59.14 352. 73 4810.45 4874.85 5263.17 5313. 00 59.15 353. 33 4858.82 4923.22 5343.47 5393. 97 58.72 352. 47 4908.73 4973.13 5425.66 5476. 81 58.56 58.48 58.59 58.45 57.98 58.03 57.86 57.76 58.33 59.20 60.26 60.17 59.99 59.83 59.56 352.46 352.72 353.05 352.70 351.87 352.19 351.12 352.45 352.16 352.21 351.95 351.67 351.70 351.33 351.28 9409.72 59.66 351.54 9504.00 59.63 351.61 9598.44 59.89 352.19 9691.65 59.80 352.11 9785.13 59.71 352.96 SurveyEditor Ver SP 1.0 Bid( doc40x_56 ) 4958.32 5022.72 5008.03 5072.43 5057.97 5122.37 5107.72 5172.12 5157.35 5221.75 5207.11 5271.51 5256.78 5321.18 5307.00 5371.40 5357.31 5421.71 5405.98 5470.38 5454.24 5518.64 5500.85 5565.25 5548.43 5612.83 5596.27 5660.67 5643.58 5707.98 5691.29 5755.69 5738.93 5803.33 5786.49 5850.89 5833.32 5897.72 5880.40 5944.80 4340.04 4420.96 4503.82 4585.24 4665.73 4747.52 4829.45 4910.94 4991.05 5070.14 5558.18 5639.37 5720.97 5802.22 5882.30 5961.97 6041.28 6121.05 6201.70 6281.96 6364.64 6446.09 6528.76 6611.31 6692.26 6773.60 6854.96 6936.55 7017.15 7097.90 4296.06 4376.62 4459.18 4540.36 4620.69 4702.37 4784.17 4865.51 4945.47 5024.38 5105.36 5186.33 5266.53 5347.16 5429.68 5510.79 5591.73 5673.04 5754.01 5833.89 5913.38 5992.55 6072.18 6152.64 6232.73 6315.25 6396.56 6479.11 6561.56 6642.42 6723.67 6804.93 6886.39 6966.85 7047.43 S-111\S-111\S-111P61\S-111 -y VJ./ G -917.02 -928.41 -939.79 -950.66 -961.79 I.JO JyO~F'F IL./D 0.87 5984494.50 0.16 5984574.07 0.54 5984655.67 0.19 5984735.78 0.25 5984816.89 4184.48 -972.76 0.41 5984898.49 4264.68 -983.52 0.47 5984978.51 4346.72 -995.17 0.55 5985060.34 4427.25 -1007.16 0.50 5985140.66 4506.73 -1019.90 1.13 5985219.92 4587.34 -1033.75 0.27 5985300.30 4668.14 -1047.25 0.74 5985380.87 4748.59 -1060.19 0.53 5985461.10 4827.70 -1072.82 0.20 5985539.99 4905.90 -1084.68 0.64 5985617.98 4986.25 -1096.40 0.02 5985698.12 5066.63 -1107.86 0.44 5985778.31 5146.39 -1118.50 0.75 5985857.88 5226.76 -1128.32 0.55 5985938.08 5308,96 -1138.56 0.88 5986020.10 5389.63 -1149.23 0.17 5986100.58 5470.15 -1159.70 0.25 5986180.92 5551.12 -1169.81 0.32 5986261.72 5631.74 -1179.89 0.35 5986342.16 5711.10 -1190.64 0.90 5986421.33 5789.99 -1201.68 0.29 5986500.03 5868.46 -1213.19 0.99 5986578.30 5947.41 -1224.59 1.20 5986657.05 6027.34 -1235.39 0.65 5986736.79 6106.85 -1246.30 0.93 5986816.11 6188.74 -1257.70 1.13 5986897.81 6269.36 -1269,30 0.28 5986978.22 6351.17 -1281,26 0.19 5987059.82 6432.81 -1293.44 0.38 5987141.26 6512.83 -1305.67 0.29 5987221.06 6593.26 -1317.82. 0.26 5987301.28 6673.74 -1329.74. 0.07 5987381.56 6754.51 -1341.24 0.60 5987462.13 6834.35 -1352.25 0.12 5987541.78 6914.42 -1362.74 0.79 5987621.67 ~,_ - D i /yOD.LO IV /U CI D/.`JDD VV l4`J Z Z`J~.3~U 617953.66 N 70 21 58.794 W 149 2 29.681 617941.01 N 70 21 59.579 W 149 2 30.014 617928.33 N 70 22 0.383 W 149 2 30.347 617916.19 N 70 22 1.173 W 149 2 30.665 617903.77 N 70 22 1.973 W 149 2 30.991 617891.50 N 70 22 2.777 W 149 2 31.312 617879.48 N 70 22 3.566 W 149 2 31.627 617866.53 N 70 22 4.373 W 149 2 31.968 617853.26 N 70 22 5.165 W 149 2 32.319 617839.27 N 70 22 5.946 W 149 2 32 617824.14 N 70 22 6.739 W 149 2 33 617809.36 N 70 22 7.534 W 149 2 33.493 617795.14 N 70 22 8.325 W 149 2 33.872 617781.26 N 70 22 9.103 W 149 2 34.242 617768.16 N 70 22 9.872 W 149 2 34.589 617755.16 N 70 22 10.662 W 149 2 34.932 617742.43 N 70 22 11.453 W 149 2 35.268 617730.53 N 70 22 12.237 W 149 2 35.579 617719.43 N 70 22 13.028 W 149 2 35.867 617707.89 N 70 22 13.836 W 149 2 36.167 617695.94 N 70 22 14.629 W 149 2 36.479 617684.20 N 70 22 15.421 W 149 2 36.786 617672.81 N 70 22 16.218 W 149 2 37.082 617661.45 N 70 22 17.010 W 149 2 37.377 617649.44 N 70 22 17.791 W 149 2 37.692 617637.15 N 70 22 18.567 W 149 2 38.016 617624.40 N 70 22 19.338 W 149 2 38.353 617611.75 N 70 22 20.115 W 149 2 617599.68 N 70 22 20.901 W 149 2 617587.51 N 70 22 21.683 W 149 2 39.322 617574.81 N 70 22 22.488 W 149 2 39.656 617561.94 N 70 22 23.281 W 149 2 39.996 617548.68 N 70 22 24.086 W 149 2 40.346 617535.21 N 70 22 24.889 W 149 2 40.703 617521.70 N 70 22 25.676 W 149 2 41.061 617508.28 N 70 22 26.467 W 149 2 41.417 617495.09 N 70 22 27.258 W 149 2 41.767 617482.31 N 70 22 28.052 W 149 2 42.103 617470.04 N 70 22 28.838 W 149 2 42.426 617458.28 N 70 22 29.625 W 149 2 42.733 Generated 6/6/2005 2:40 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure f- de de ft k k ft ft ft ft de /100 ft ftUS ftUS 9877.65 59.31 352.79 5927.35 5991.75 7115.81 7177.63 7126.97 6993.54 -1372.63 0.46 5987700.60 617447.13 N 70 22 30.403 W 149 2 43. 023 9972.07 58.61 352.96 5976.03 6040.43 7196.08 7258.53 7207.67 7073.81 -1382.66 0.76 5987780.70 617435.83 N 70 22 31.193 W 149 2 43. 317 10066.96 58.44 353.70 6025.58 6089.98 7276.29 7339.45 7288.36 7154.19 -1392.06 0.69 5987860.91 617425.15 N 70 22 31.983 W 149 2 43. 592 10160.49 57.98 354.15 6074.85 6139.25 7354.97 7418.95 7367.57 7233.24 -1400.48 0.64 5987939.82 617415.49 N 70 22 32.761 W 149 2 43. 839 10253.87 58.08 354.88 6124.29 6188.69 7433.24 7498.17 7446.43 7312.09 -1408.05 0.67 5988018.53 617406.66 N 70 22 33.536 W 149 2 44. 061 10349.49 58.38 355.74 6174.64 6239.04 7513.39 7579.46 7527.25 7393.11 -1414.69 0.83 5988099.43 617398.73 N 70 22 34.333 W 149 2 44. 256 10444.31 58.31 355.62 6224.40 6288.80 7592.88 7660.17 7607.45 7473.60 -1420.77 0.13 5988179.80 617391.38 N 70 22 35.124 W 149 2 44. 434 10538.49 58.10 355.99 6274.02 6338.42 7671.68 7740.22 7686.97 7553.43 -1426.63 0.40 5988259.52 617384.26 N 70 22 35.909 W 149 2 44. 606 10632.35 58.00 356.19 6323.69 6388.09 7750.02 7819.86 7766.06 7632.89 -1432.06 0.21 5988338.87 617377.56 N 70 22 36.691 W 149 2 44. 765 10726.50 58.17 356.30 6373.46 6437.86 7828.58 7899.78 7845.41 7712.63 -1437.29 0.21 5988418.52 617371.07 N 70 22 37.475 W 149 2 44. 919 10821.23 58.54 356.07 8423.16 6487.56 7907.88 7980.43 7925.51 7793.10 -1442.66 0.44 5988498.88 617364.42 N 70 22 38.267 W 149 2 4 10916.86 59.27 355.82 6472.55 6536.95 7988.46 8062.31 8006.88 7874.78 -1448.45 0.80 5988580.46 617357.34 N 70 22 39.070 W 149 2 45. 11012.14 59.33 355.76 6521.20 6585.60 8069.12 8144.24 8088.33 7956.49 -1454.46 0.08 5988662.05 617350.03 N 70 22 39.873 W 149 2 45. 423 11106,68 59.68 353.97 6569.18 6633.58 8149.53 8225.70 8169.46 8037.62 -1461.76 1.67 5988743.05 617341.45 N 70 22 40.671 W 149 2 45. 637 11201.94 59.82 353.02 6617.17 6681.57 8231.06 8307.99 8251.57 8119.38 -1471.08 0.87 5988824.64 617330.83 N 70 22 41.475 W 149 2 45. 910 11296.04 60.42 351.93 6664.05 6728.45 8312.07 8389.58 8333.06 8200.26 -1481.77 1.19 5988905.34 617318.86 N 70 22 42.271 W 149 2 46. 223 11390.27 62.80 352.27 6708.85 6773.25 8394.45 8472.47 8415.88 8282.37 -1493.16 2.55 5988987.25 617306.17 N 70 22 43.078 W 149 2 46. 557 11484.93 65.11 352.56 6750.41 6814.81 8478.90 8557.51 8500.84 8366.66 -1504.38 2.46 5989071.35 617293.61 N 70 22 43.907 W 149 2 46. 886 11579.98 67.80 352.84 6788.37 6852.77 8565.38 8644.64 8587.86 8453.09 -1515.45 2.84 5989157.58 617281.17 N 70 22 44.757 W 149 2 47. 211 11675.30 67.32 352.39 6824.76 6889.16 8652.84 8732.74 8675.85 8540.46 -1526.77 0.67 5989244.75 617268.46 N 70 22 45.617 W 149 2 47. 542 11767.86 66.94 352.41 6860.73 6925.13 8737.54 8818.03 8761.06 8624.99 -1538.05 0.41 5989329.09 617255.84 N 70 22 46.448 W 149 2 47. 873 11861.14 66.58 352.84 6897.54 6961.94 8822.62 8903.74 8846.67 8709.99 -1549.06 0.57 5989413.90 617243.49 N 70 22 47.284 W 149 2 48. 196 11955.88 66.52 353.33 6935.24 6999.64 8908.81 8990.65 8933.45 8796.28 -1559.52 0.48 5989499.99 617231.66 N 70 22 48.132 W 149 2 48. 502 12050.04 66.90 353.51 6972.47 7036.87 8994.52 9077.14 9019.78 8882.19 -1569.43 0.44 5989585.74 617220.39 N 70 22 48.977 W 149 2 48. 793 Last MWD+IFR+MS 12144.59 66.47 354.35 7009.89 7074.29 9080.45 9163.97 9106.41 8968.53 -1578.61 0.93 5989671.91 617209.84 N 70 22 49.826 W 149 2 49. 062 TD (Projected) 12210.00 66.47 354.35 7036.00 7100.40 9139.73 9223.94 9166.21 9028.21 -1584.52 0.00 5989731.49 617202.99 N 70 22 50.413 W 149 2 49.235 ,r -_ ...~ ~ 2 Ili j~~ SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\S-111 P61\5-111 P81 Generated 6/6/2005 2:40~PM Page 4 of 4 . ,. S-111PB2 Survey Report Report Date: 10-Jun-05 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 345.690° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: S-PAD / S-111 TVD Reference Datum: Rotary Table Well: S-111 TVD Reference Elevation: 64.40 fi relative to MSL Borehole: S-111 PB2 Sea Bed /Ground Level Elevation: 35.60 ft relative to MSL UWIIAPI#: 500292325771 MagneBc Declination: 24.740° Survey Name /Date: S-111 PB2 /June 10, 2005 Total Field Strength: 57587.827 nT Tort I AHD I DDI I ERD ratio: 234.007° / 9836.17 ft / 6.627 / 1.415 Magnetic Dip: 80.880° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 10, 2005 Location LaUlong: N 70 2121.624, W 149 2 2.860 Magnetic Declination Model: BGGM 2005 Location Grid NIE Y/X: N 5980730.340 fiUS, E 618930.490 fiUS North Reference: True North Grid Convergence Angle: +0.90966782° Total Corr Mag North -> True North: +24.740° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS RIC U.VV V.VV U.UU -04.4U U.VU U.UV U.UV V.UU U.UU First GYD GC SS 100.00 0.67 43.93 35.60 100.00 0.31 0.58 0.58 0.42 200.00 0.73 19.31 135.59 199.99 1.15 1.79 1.77 1.44 258.00 1.01 22.64 193.58 257.98 1.86 2.67 2.63 2.26 349.00 1.52 17.00 284.56 348.96 3.53 4.68 4.62 4.16 438.00 1.63 344.77 373.53 437.93 5.81 7.06 6.81 6.51 528.00 1.80 341.86 463.49 527.89 8.50 9.75 9.17 9.09 620.00 2.55 338.43 555.42 619.82 11.97 13.24 12.36 12.36 714.00 3.96 336.62 649.27 713.67 17.25 18.58 17.41 17.29 808.00 4.97 332.16 742.98 807.38 24.41 25.89 24.43 23.87 904.00 7.85 326.42 838.37 902.77 34.65 36.60 34.72 33.01 1028.00 10.36 328.63 960.80 1025.20 53.30 56.22 53.95 49.59 1090.00 11.79 331.47 1021.65 1086.05 64.77 68,13 65.79 59.91 1180.00 13.86 334.14 1109.40 1173.80 84.25 88.10 85.75 77.69 Last GYD GC SS 1280.00 15.33 335.85 1206.17 1270.57 109.01 113.30 110.94 100.53 First MWD+IFR+MS 1404.53 19.54 334.81 1324.95 1389.35 145.70 150.60 148.25 134.41 1499.49 25.21 331.98 1412.73 1477.13 180.97 186.73 184.36 166.66 1593.68 26.54 331.78 1497.47 1561.87 220.89 227.83 225.42 202.92 1687.93 30.86 329.24 1580.13 1644.53 264.53 273.07 270.58 242.26 1781.40 36.16 329.01 1658.03 1722.43 313.97 324.66 322.03 286.53 1876.90 39.00 329.27 1733.71 1798.11 369.80 382.90 380.17 336.53 1967.35 41.91 330.08 1802.53 1866.93 426.20 441.58 438.80 387.18 2061.33 42.94 329.92 1871.90 1936.30 487.24 504.98 502.17 442.09 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\S-111P62\S-111P62 V.UU U.UU DytlU/3U.34 b~lt5`JJU.4`J N /U Z1 Z1.bZ4 VV 14~J'LL.tStiU 0.41 0.67 5980730.77 618930.89 N 70 21 21.628 W 149 2 2.848 1.02 0.30 5980731.80 618931.49 N 70 21 21.638 W 149 2 2.830 1.34 0.49 5980732.62 618931.79 N 70 21 21.646 W 149 2 2.821 2.00 0.58 5980734.53 618932.43 N 70 21 21.665 W 149 2 2.802 2.02 0.99 5980736.88 618932.40 N 70 21 21.688 W 149 2 2.801 1.24 0.21 5980739.44 618931.58 N 70 21 21.713 W 149 2 2.824 0.04 0.83 5980742.70 618930.33 N 70 21 21.746 W 149 2 2.859 -2.02 1.50 5980747.59 618928.20 N 70 21 21.794 W 149 2 2.919 -5.21 1.14 5980754.12 618924.90 N 70 21 21.859 W 149 2 3.012 -10.78 3.07 5980763.17 618919.19 N 70 21 21.949 W 149 5 -21.27 2.04 5980779.58 618908.44 N 70 21 22.112 W 149 2 ~ -27.20 2.47 5980789.81 618902.35 N 70 21 22.213 W 149 2 655 -36.29 2.39 5980807.44 618892.97 N 70 21 22.388 W 149 2 3.921 -46.92 1.53 5980830.11 618881.98 N 70 21 22.613 W 149 2 4.232 -62.53 3.39 5980863.73 618865.84 N 70 21 22.946 W 149 2 4.688 -78.80 6.08 5980895.72 618849.06 N 70 21 23.263 W 149 2 5.164 -98.18 1.42 5980931.65 618829.11 N 70 21 23.620 W 149 2 5.730 -120.51 4.76 5980970.64 618806.16 N 70 21 24.007 W 149 2 6.383 -146.99 5.67 5981014.48 618778.99 N 70 21 24.442 W 149 2 7.157 -176.85 2.98 5981063.99 618748.33 N 70 21 24.934 W 149 2 8.030 -206.47 3.27 5981114.16 618717.91 N 70 21 25.432 W 149 2 8.896 -238 17 1/:~(l• ~,'~6 3~6 ~ -18685.35 N 70 21 25.972 W 149 2 9.823 ~ ,, _ . < F '~~.*bf ~, 1 ~,U~J Generated 6/20/2 005 2:39 PM Page 1 of 5 Comments Measured Depth Inclination Azimuth Sub-Sea TVD TVD Vertical Section Along Hole Departure Closure NS EW DLS Northing Easting Latitude Longitude ft de de ft ft ft ft ft ft ft de 1100 ft ftUS kUS L IJY.IY Y/.VV JLO.:J:J I~Jl.~/ GUUL.J! 2248.34 50.22 328.08 1999.85 2064.25 2344.78 2438.24 2532.07 2627.85 2723.01 2816.27 2910.74 3004.77 3099.37 3195.33 3286.94 3381.89 3476.60 3570.82 3665.03 53.50 332.75 2059.42 2123.82 54.72 336.67 2114.22 2178.62 53.92 340.20 2168.96 2233.36 53.32 343.35 2225.78 2290.18 55.08 348.05 2281.47 2345.87 55.41 57.46 58.15 60.20 59.70 59.77 59.51 58.94 58.07 59.50 3761.05 3853.78 3949.40 4043.33 4136.88 4231.68 4325.59 4419.39 4512.55 4606.34 60.62 60.25 61.11 61.12 61.67 60.80 60.31 60.14 60.46 61.13 JOU.OJ U/U.~O JOO . I I 617.54 641.19 638 .23 690.68 717.01 714 .03 764.99 792.72 789 .58 840.57 868.93 865 .24 917.49 946.03 941 .31 994.63 1023.20 1016 .63 1071.13 1099.82 1090 .80 1149.65 1178.53 1167 .04 1228.99 1258.10 1244 .30 1310.01 1339.33 1323 .52 1392.86 1422.39 1404 .80 1471 .76 1501.52 1482. 35 1553 .46 1583.45 1562 .82 1634 .59 1664.82 1642. 84 1714 .66 1745.16 1721. 91 1795 .03 1825.73 1801. 48 1878.10 1958.61 2041.86 2124.02 2206.08 2289.12 2370.84 2452.20 2533.02 2614.76 2654.74 2761.10 2843.43 2924.87 3007.10 349.56 349.87 350.29 349.47 350.00 349.98 349.92 350.39 350.35 349.04 348.99 349.28 348.18 348.18 347.99 347.89 347.72 348.19 348"67 349.24 2334.63 2386.86 2436.96 2485.43 2533.48 2579.66 2627.65 2676.11 2725.33 2774.15 2822.08 2867.83 2914.65 2960.03 3004.82 3050.44 3096.60 3143.18 3189.34 3235.10 2399.03 2451.26 2501.36 2549.83 2597.88 2644.06 2692.05 2740.51 2789.73 2838.55 2886.48 2932.23 2979.05 3024.43 3069.22 3114.84 3161.00 3207.58 3253.74 3299.50 4652.01 61.49 349.24 3257.03 3321.43 4773.91 60.57 350.51 3316.07 3380.47 4868.80 60.52 350.63 3362.73 3427.13 4962.75 60.46 350.82 3409.01 3473.41 5057.85 60.05 350.95 3456.19 3520.59 5150.46 5244.62 5340.69 5435.12 5529.14 5624.51 5718.42 5813.42 5906.13 60.08 351.71 3502.41 3566.81 3086.97 59.67 352.63 3549.66 3614.06 3167.89 58.56 354.01 3598.98 3663.38 3249.60 57.74 354.66 3648.81 3713.21 3328.90 57.06 355.64 3699.47 3763.87 3407.03 57.71 355.22 3750.87 3815.27 3486.21 59.59 355.67 3799.73 3864.13 3565.24 60.12 355.51 3847.43 3911.83 3646.17 60.10 353.85 3893.64 3958.04 3725.56 1908.93 1989.59 2072.96 2155.20 2237.33 2320.43 2402.21 2483.63 2564.55 2646.42 2686.48 2793.13 2875.75 2957.51 3040.08 3120.34 3201.78 3284.22 3364.43 3443.64 3523.97 3604.17 3686.32 3766.69 1883.87 1963.79 2046.53 2128.28 2209.98 2292.69 2374.13 2455.21 2535.76 2617.20 2657.05 2763.02 2845.04 2926.22 3008.20 3087.84 3168.54 3250.04 3329.16 3407.15 3486.24 3565.24 3646.19 3725.64 4`JO. / y 558.53 624.48 692.93 763.79 837.01 911.77 986.93 1064.38 1142.76 1222.73 1304.46 -L/l.yb 4.4/ byb"IZL4./U -308.84 3.46 5981283.85 -346.21 -378.52 -406.54 -430.66 -449.68 -464.55 -478.60 -492.31 -506.59 -521.39 -535.15 -549.44 -563.36 -576.80 -591.22 5.10 5981349.20 3.64 5981417.11 3.17 5981487.51 2.72 5981560.34 4.41 5981634.78 1.38 5981709.69 2,19 5981786.90 0.83 5981865.05 2.29 5981944.77 0,71 5982026.25 1382.38 0.08 5982103.93 1463.05 0.28 5982184.36 1543.23 0.74 5982264.30 1622.43 0.92 5982343.27 1701.70 1.93 5982422.29 1783.38 -607.07 1.17 5982503.71 1862.59 -622.28 0.48 5982582.66 1944.35 -638.57 1.35 5982664.14 2024.85 -655.42 0.01 5982744.36 2105.21 -672.38 0.61 5982824.43 2186.48 -689.74 0.92 5982905.41 2266.41 -707.01 0.55 5982985.05 2346.04 -724.00 0.47 5983064.39 2425.31 -740.23 0.56 5983143.39 2505.66 -755.91 0.89 5983223.47 2545.02 -763.39 0.79 5983262.70 2650.00 -782.15 1.18 5983367.37 2731.51 -795.68 0.12 5983448.64 2812.20 -808.86 0.19 5983529.11 2893.73 -821.94 0.45 5983610.41 2973.07 -834.04 0.71 5983689.54 3053.75 -845.14 0.95 5983770.03 3135.63 -854.73 1.69 5983851.74 3215.45 -862.65 1.05 5983931.41 3294.37 -869.35 1.14 5984010.21 3374.45 -875.75 0.78 5984090.17 3454.39 -882.12 2.04 5984169.99 3536.30 -888.44 0.58 5984251.79 3616.33 _ _ ,~5 Sri _~~ . ~ - 4`.5~z X84331.68 - y,~ !~', i,' ~ ~, ~ ~zl ~~ b"ItlbbU.b/ N /U Z1 Lli.bZy VV 14yZ 1U.ti11 618612.85 N 70 21 27.117 W 149 2 11.889 618574.44 N 70 21 27.766 W 149 2 12.981 618541.05 N 70 21 28.439 W 149 2 13.926 618511.91 N 70 21 29.136 W 149 2 14.746 618486.63 N 70 21 29.856 W 149 2 15.451 618466.43 N 70 21 30.591 W 149 2 16.007 618450.37 N 70 21 31.330 W 149 2 16.442 618435.09 N 70 21 32.092 W 149 2 16.853 618420.14 N 70 21 32.863 W 149 2 17.254 618404.60 N 70 21 33.649 W 149 2 1 618388.50 N 70 21 34.453 W 149 2 1~ 618373.51 N 70 21 35.219 W 149 2 18.507 618357.94 N 70 21 36.013 W 149 2 18.925 618342.75 N 70 21 36.801 W 149 2 19.332 618328.06 N 70 21 37.580 W 149 2 19.725 618312.38 N 70 21 38.360 W 149 2 20.147 618295.24 N 70 21 39.163 W 149 2 20.611 618278.78 N 70 21 39.942 W 149 2 21.055 618261.19 N 70 21 40.74,6 W 149 2 21.532 618243.07 N 70 21 41.538 W 149 2 22.025 618224.84 N 70 21 42.328 W 149 2 22.521 618206.19 N 70 21 43.127 W 149 2 23.029 618187.65 N 70 21 43.913 W 149 2 23.534 618169.40 N 70 21 44.697 W 149 2 24.031 618151.91 N 70 21 45.476 W 149 2 24.506 618134.96 N 70 21 46.266 W 149 2 24.965 618126.86 N 70 21 46.653 W 149 2 2 184 618106.44 N 70 21 47.686 W 149 2~2 618091.61 N 70 21 48.488 W 149 2 9 618077.16 N 70 21 49.281 W 149 2 26.514 618062.78 N 70 21 50.083 W 149 2 26.897 618049.43 N 70 21 50.863 W 149 2 27.251 618037.05 N 70 21 51.657 W 149 2 27.576 618026.16 N 70 21 52.462 W 149 2 27.857 618016.98 N 70 21 53.247 W 149 2 28.089 618009.03 N 70 21 54.023 W 149 2 28.285 618001.35 N 70 21 54.811 W 149 2 28.472 617993.72 N 70 21 55.597 W 149 2 28.659 617986.10 N 70 21 56.402 W 149 2 28.844 .617977.38 N 70 21 57.189 W 149 2 29.062 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\S-111PB2\S-111PB2 Generated 6/20!2005 2:39 PM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea ND TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de de ft ft k tt it k ft de 1100 ft f1US kUS VVVV.JL VV. IM J:JL.JJ J~4 V.OV 6096.27 59.39 351.94 6189.94 59.29 351.81 6285.89 59.51 352.35 6379.85 59.65 352.23 6474.84 59.88 352.18 6570.13 60.12 352.54 6663.31 60.43 352.19 6758.68 60.21 351.64 6852.70 59.78 351.42 6946.12 59.23 350.37 7041.39 59.07 350.13 7137.02 58.82 350.90 7232.52 58.32 350.82 7326.67 58.30 351.04 7419.55 58.46 351.71 7514.82 58.46 351.69 7609.96 58.71 352.08 7703.91 59.14 352.73 7798.23 59.15 353.33 7894.94 58.72 352.47 7990.23 58.56 352.46 8085.44 58.48 352.72 8181.11 58.59 353.05 8276.38 58.45 352.70 8370.59 57.98 351.87 8464.52 58.03 352.19 8558.10 57.86 351.12 8652.36 57.76 352.45 8747.42 58.33 352.16 8841.28 59.20 352.21 8937.02 60.26 351.95 9030.86 60.17 351.67 9126.25 59.99 351.70 9221.66 59.83 351.33 9315.42 59.56 351.28 9409.72 59.66 351.54 9504.00 59.63 351.61 9598.44 59.89 352.19 9691.65 59.80 352.11 9785.13 59.71 352.96 3988.88 4036.64 4085.49 4133.06 4180.89 4228.54 4274.74 4321.96 4368.98 4416.39 4465.24 4514.58 4564.37 4613.83 4662.53 4712.36 4761.95 4810.45 4858.82 4908.73 4958.32 5008.03 5057.97 5107.72 5157.35 5207.11 5256.78 5307.00 5357.31 5405.98 5454.24 5500.85 5548.43 5596.27 5643.58 5691.29 5738.93 5786.49 5833.32 5880.40 4VUU.VV 4053.28 4101.04 4149.89 4197.46 4245.29 4292.94 4339.14 4386.36 4433.38 4480.79 4529.64 4578.98 4628.77 4678.23 4726.93 JOUV./ I 3888.91 3969.02 4051.09 4131.58 4213.12 4295.08 4375.45 4457.82 4538.82 4618.98 4700.51 4782.15 4863.30 4943.08 5021.78 J040.U4 3931.26 4011.84 4094.42 4175.45 4257.52 4340.04 4420.96 4503.82 4585.24 4665.73 4747.52 4829.45 4910.94 4991.05 5070.14 30U0.00 30U/.U/ -`9UU./L 3889.18 3969.39 4051.59 4132.22 4213.92 3779.52 -917.02 3859.29 -928.41 3941.09 -939.79 4021.38 -950.66 4102.69 -961.79 4296.06 4376.62 4459.18 4540.36 4620.69 4702.37 4784.17 4865.51 4945.47 5024.38 4776.76 5102.53 5151. 34 5105.36 4826.35 5183.25 5232. 53 5186.33 4874.85 5263.17 5313. 00 5266.53 4923.22 5343.47 5393. 97 5347.16 4973.13 5425.66 5476. 81 5429.68 5022.72 5072.43 5122.37 5172.12 5221.75 5271.51 5321.18 5371.40 5421.71 5470.38 5518.64 5565.25 5612.83 5660.67 5707.98 5755.69 5803.33 5850.89 5897.72 5944.80 5506.46 5587.07 5668.03 5748.64 5828.19 5907.36 5986.24 6065.56 6145.68 6225.42 6307.59 6388.57 6470.79 6552.92 6633.48 6714.41 6795.34 6876.45 6956.53 7036.71 5558.18 5639.37 5720.97 5802.22 5882.30 5961.97 6041.28 6121.05 6201.70 6281.96 6364.64 6446.09 6528.76 6611.31 6692.26 6773.60 6854.96 6936.55 7017.15 7097.90 5510.79 5591.73 5673.04 5754.01 5833.89 5913.38 5992.55 6072.18 6152.64 6232.73 6315.25 6396.56 6479.11 6561.56 6642.42 6723.67 4184.48 -972.76 4264.68 -983.52 4346.72 -995.17 4427.25 -1007.16 4506.73 -1019.90 4587.34 -1033.75 4668.14 -1047.25 4748.59 -1060.19 4827.70 -1072.82 4905.90 -1084.68 4986.25 -1096.40 5066.63 -1107.86 5146.39 -1118.50 5226.76 -1128.32 5308.96 -1138.56 5389.63 -1149.23 5470.15 -1159.70 5551.12 -1169.81 5631.74 -1179.89 5711.10 -1190.64 5789.99 -1201.68 5868.46 -1213.19 5947.41 -1224.59 6027.34 -1235.39 6106.85 -1246.30 6188.74 -1257.70 6269.36 -1269.30 6351.17 -1281.26 6432.81 -1293.44 6512.83 -1305.67 6593.26 -1317.82 6804.93 , 6 ~ g - 4 . ~ ~ ~ ~'3 6 .~, ~;8 " :~5 ~~J 25 7047.3 ~~**6 14 2~rtt1~62.74 i..sts ~`JZ344IL./~ bl/ybb.Lb N /UL'I 5/.ytStS W "149119.3bU 0.87 5984494.50 617953.66 N 70 21 58.794 W 149 2 29.681 0.16 5984574.07 617941.01 N 70 21 59.579 W 149 2 30.014 0.54 5984655.67 617928.33 N 70 22 0.383 W 149 2 30.347 0.19 5984735.78 617916.19 N 70 22 1.173 W 149 2 30.665 0.25 5984816.89 617903.77 N 70 22 1.973 W 149 2 30.991 0.41 5984898.49 617891.50 N 70 22 2.777 W 149 2 31.312 0.47 5984978.51 617879.48 N 70 22 3.566 W 149 2 31.627 0.55 5985060.34 617866.53 N 70 22 4.373 W 149 2 31.968 0.50 5985140.66 617853.26 N 70 22 5.165 W 149 2 32.319 1.13 5985219.92 617839.27 N 70 22 5.946 W 149 2 3 0.27 5985300.30 617824.14 N 70 22 6.739 W 149 2 3 0.74 5985380.87 617809.36 N 70 22 7.534 W 149 2 33.493 0.53 5985461.10 617795.14 N 70 22 8.325 W 149 2 33.872 0.20 5985539.99 617781.26 N 70 22 9.103 W 149 2 34.242 0.64 5985617.98 617768.16 N 70 22 9.872 W 149 2 34.589 0.02 5985698.12 617755.16 N 70 22 10.662 W 149 2 34.932 0.44 5985778.31 617742.43 N 70 22 11.453 W 149 2 35.268 0.75 5985857.88 617730.53 N 70 22 12.237 W 149 2 35.579 0.55 5985938.08 617719.43 N 70 22 13.028 W 149 2 35.867 0.88 5986020.10 617707.89 N 70 22 13.836 W 149 2 36.167 0.17 5986100.58 617695.94 N 70 22 14.629 W 149 2 36.479 0.25 5986180.92 617684.20 N 70 22 15.421 W 149 2 36.786 0.32 5986261.72 617672.81 N 70 22 16.218 W 149 2 37.082 0.35 5986342.16 617661.45 N 70 22 17.010 W 149 2 37.377 0.90 5986421.33 617649.44 N 70 22 17.791 W 149 2 37.692 0.29 5986500.03 617637.15 N 70 22 18.567 W 149 2 38.016 0.99 5986578.30 617624.40 N 70 22 19.338 W 149 2 3 353 1.20 5986657.05 61761175 N 70 22 20.115 W 149 2~6 0.65 5986736.79 617599.68 N 70 22 20.901 W 149 2 3 0.93 5986816.11 617587.51 N 70 22 21.683 W 149 2 39.322 1.13 5986897.81 617574.81 N 70 22 22.488 W 149 2 39.656 0.28 5986978.22 617561.94 N 70 22 23.281 W 149 2 39.996 0.19 5987059.82 617548.68 N 70 22 24.086 W 149 2 40.346 0.38 5987141.26 617535.21 N 70 22 24.889 W 149 2 40.703 0.29 5987221.06 617521.70 N 70 22 25.676 W 149 2 41.061 0.26 5987301.28 617508.28 N 70 22 26.467 W 149 2 41.417 0.07 5987381.56 617495.09 N 70 22 27.258 W 149 2 41.767 0.60 5987462.13 617482.31 N 70 22 28.052 W 149 2 42.103 0.12 5987541.78 617470.04 N 70 22 28.838 W 149 2 42.426 0.79 5987621.67 61745828 N 70 22 29.625 W 149 2 42.733 A~tn --R ~ ~; - ~G~ .... SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\5=~~'~ i~'~2\S-111PB2 Generated 6/20/2005 2:39 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de it ft ft ft ft ft ft de 1100 ft itUS ftUS Tie-In Survey Top Whpstck (Inc only) Bse Whpstck (Inc only) End of Mill (Inc Only) Blind (Inc only) Last Blind (Inc Only) M W D+IFR+MS 9877.65 59.31 352.79 5927.35 5991.75 7115.81 7177.63 7126.97 9972.07 58.61 352.96 5976.03 6040.43 7196.08 7258.53 7207.67 10066.96 58.44 353.70 6025.58 6089.98 7276.29 7339.45 7288.36 10160.49 57.98 354.15 6074.85 6139.25 7354.97 7418.95 7367.57 10253.87 58.08 354.88 6124.29 6188.69 7433.24 7498.17 7446.43 10349.49 10444.31 10538.49 10632.35 10726.50 10821.23 10916.86 11012.14 11106.68 11201.94 11296.04 11390.27 11484.93 11484.93 11536.00 58.38 355.74 6174.64 6239.04 7513 .39 7579.46 7527.25 58.31 355.62 6224.40 6288.80 7592 .88 7660.17 7607.45 58.10 355.99 6274.02 6338.42 7671 .68 7740.22 7686.97 58.00 356.19 6323.69 6388.09 7750 .02 7619.86 7766.06 58.17 356.30 6373.46 6437.86 7828 .58 7899.78 7845.41 58.54 356.07 6423.16 6487.56 59.27 355.82 6472.55 6536.95 59.33 355.76 6521.20 6585.60 59.68 353.97 6569.18 6633.58 59.82 353.02 6617.17 6681.57 60.42 351.93 6664.05 6728.45 62.80 352.27 6708.85 6773.25 65.11 352.56 6750.41 6814.81 65.11 352.56 6750.41 6814.81 66.53 352.71 6771.32 6835.72 6993.54 -1372.63 7073.81 -1382.66 7154.19 -1392.06 7233.24 -1400.48 7312.09 -1408.05 7393.11 -1414.69 7473.60 -1420.77 7553.43 -1426.63 7632.89 -1432.06 7712.63 -1437.29 7907.88 7980.43 7925.51 7793.10 -1442.66 7988.46 8062.31 8006.88 7874.78 -1448.45 8069.12 8144.24 8088.33 7956.49 -1454.46 8149.53 8225.70 8169.46 8037.62 -1461.76 8231.06 8307.99 8251.57 8119.38 -1471.08 0.46 5987700.60 0.76 5987780.70 0.69 5987860.91 0.64 5987939.82 0.67 5988018.53 0.83 5988099.43 0.13 5988179.80 0.40 5988259.52 0.21 5988338.87 0.21 5988418.52 0.44 5988498.88 0.80 5988580.46 0.08 5988662.05 1.67 5988743.05 0.87 5988824.64 8312.07 8389.58 8333.06 8200.26 -1481. 77 1.19 5988905.34 8394.45 8472.47 8415.88 8282.37 -1493. 16 2.55 5988987.25 8478.90 8557.51 8500.84 8366.66 -1504. 38 2.46 5989071.35 8478.90 8557.51 8500.84 8366.66 -1504. 38 0.75 5989071.35 8525.15 8604.10 8547.37 8412.87 -1510. 35 2.79 5989117.45 617447.13 N 70 22 30.403 W 149 2 43.023 617435.83 N 70 22 31.193 W 149 2 43.317 617425.15 N 70 22 31.983 W 149 2 43.592 617415.49 N 70 22 32.761 W 149 2 43.839 617406.66 N 70 22 33.536 W 149 2 44.061 617398.73 N 70 22 34.333 W 149 2 44.256 617391.38 N 70 22 35.124 W 149 2 44.434 617384.26 N 70 22 35.909 W 149 2 44.606 617377.56 N 70 22 36.691 W 149 2 44.765 617371.07 N 70 22 37.475 W 149 2 44.919 617364.42 N 70 22 38.267 W 149 2 4~ 617357.34 N 70 22 39.070 W 149 2 4 . 617350.03 N 70 22 39.873 W 149 2 45.423 617341.45 N 70 22 40.671 W 149 2 45.637 617330.83 N 70 22 41.475 W 149 2 45.910 61731$.86 N 70 22 42.271 W 149 2 46.223 617306.17 N 70 22 43.078 W 149 2 46.557 617293.61 N 70 22 43.907 W 149 2 46.886 617293.61 N 70 22 43.907 W 149 2 46.886 617286.91 N 70 22 44.362 W 149 2 47.061 11549.00 68.28 351.50 6776.32 6840.72 8537.08 8616.10 8559.36 8424.75 -1512.00 15.97 5989129. 31 617285.07 N 70 22 44.479 W 149 2 47.109 11562.39 67.19 351.50 6781.39 6845.79 8549.40 8628.49 8571.75 8437.01 -1513.83 8.14 5989141 .53 617283.04 N 70 22 44.599 W 149 2 47.163 11573.96 67.11 350.90 6785.89 .6850.29 8560.02 8639.16 8582.41 8447.55 -1515.46 4.83 5989152 .04 617281.24 N 70 22 44.703 W 149 2 47.211 11602.82 68.23 349.44 6796.85 6861.25 8586.63 8665.85 8609.10 8473.85 -1520.02 6.08 5989178. 26 617276.27 N 70 22 44.961 W 149 2 47.344 11635.27 70.31 347.82 6808.34 6872.74 8616.94 8696.20 8639.44 8503.60 -1526.01 7.93 5989207 .91 617269.81 N 70 22 45.254 W 149 2 47.520 11666.52 71.82 346.29 6818.48 6882.88 8646.48 8725.76 8668.96 8532.40 -1532.63 6.69 5989236 .61 617262.73 N 70 22 45.537 W 149 2 47.714 11698.65 73.09 344.75 6828.16 6892.56 8677.12 8756.39 8699.51 8562.06 -1540.29 6.04 5989266. 14 617254.60 N 70 22 45.829 W 149 2 8 11730.59 74.94 343.24 6836.96 6901.36 8707.81 8787.09 8730.05 8591.58 -1548.76 7.36 5989295 .51 617245.67 N 70 22 46.119 ~ W 149 2 6 11767.70 76.84 338.44 6846.01 6910.41 8743.65 8823.08 8765.59 8625.56 -1560.57 13.55 5989329 .30 617233.32 N 70 22 46.453 W 149 2 48.532 11793.51 77.93 335.49 6851.65 6916.05 8768.55 8848.27 8790.16 8648.73 -1570.43 11.93 5989352. 31 617223.10 N 70 22 46.681 W 149 2 48.821 11826.51 78.93 334.42 6858.27 6922.67 8800.31 8880.60 8821.42 8678.02 -1584.12 4.39 5989381 .38 617208.95 N 70 22 46.969 W 149 2 49.221 11864.17 80.40 332.93 6865.02 6929.42 8836.54 8917.64 8857.04 8711.23 -1600.55 5.51 5989414 .31 617192.00 N 70 22 47.296 W 149 2 49.702 11896.84 81.44 329.50 6870.18 6934.58 8867.77 8949.90 8887.66 8739.50 -1616.08 10.84 5989442 .33 617176.02 N 70 22 47.574 W 149 2 50.157 11929.57 82.13 325.87 6874.86 6939.26 8898.58 8982.30 8917.73 8766.87 -1633.39 11.18 5989469 .42 617158.27 N 70 22 47.843 W 149 2 50.664 11960.66 83.76 323.84 6878.68 6943.08 8927.41 9013.15 8945.79 8792.09 -1651.15 8.34 5989494 .36 617140.11 N 70 22 48.091 W 149 2 51.184 11995.68 85.62 318.85 6881.92 6946.32 8959.17 9048.02 8976.58 8819.31 -1672.93 15.15 5989521 .23 617117.91 N 70 22 48.359 W 149 2 51.822 12023.87 86.85 315.59 6883.77 6948.17 8983.89 9076.15 9000.43 8839.96 -1692.03 12.34 5989541 .56 617098.49 N 70 22 48.562 W 149 2 52.381 12055.47 88.40 312.37 6885.08 6949.48 9010.75 9107.72 9026.25 8861.88 -1714.75 11.30 5989563 .12 617075.43 N 70 22 48.777 W 149 2 53.046 12090.46 90.42 307.82 6885.44 6949.84 9039.19 9142.71 9053.48 8884.,0 '.~7~1 ~ ~4"3~'"~5989585 .21 617048.32 N 70 22 48.999 W 149 2 53.829 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-1111S-111\S-111 PB2\S-111 P62 Generated 6!2012005 2:39 PM Page 4 of 5 ;~E Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ttUS iG icv.v-r a ~.ov ovo.oo voo•t.oo OhYy.GO ywG. i9 y ~ rG.co yur O.Jr OyvG.uJ - I roO.L4 `J.OLS O`Jtl~JbuZ.4n 12151.15 92.61 301.71 6883.64 6948.04 9085.18 9203.37 9097.28 8919.21 -1791.15 12.03 5989619.22 12183.47 94.09 298.08 6881.75 6946.15 9107.68 9235.63 9118.58 8935.29 -1819.11 12.11 5989634.86 12216.97 96.40 294.87 6878.69 6943.09 9129.46 9268.99 9139.15 8950.16 -1848.97 11.77 5989649.25 12234.31 97.26 293.33 6876.63 6941.03 9140.16 9286.20 9149.22 8957.19 -1864.68 10.12 5989656.03 12269.82 97.58 291.35 6872.04 6936.44 9161.18 9321.42 9169.01 8970.57 -1897.25 5.60 5989668.89 12302.84 97.29 289.51 6867.77 6932.17 9179.84 9354.16 9186.58 8982.00 -1927.93 5.59 5989679.83 12335.54 97.13 289.30 6863.66 6928.06 9197.84 9386.60 9203.58 8992.78 -1958.53 0.80 5989690.12 12365.23 96.85 289.11 6860.05 6924.45 9214.12 9416.07 9219.01 9002.47 -1986.36 1.14 5989699.37 12398.64 96.55 289.39 6856.15 6920.55 9232.46 9449.25 9236.49 9013.41 -2017.69 1.22 5989709.81 12430.43 96.82 288.48 6852.45 6916.85 9249.77 9480.83 9253.05 9023.66 -2047.55 2.97 5989719.58 12462.82 97.16 287.55 6848.51 6912.91 9266.96 9512.97 9269.55 9033.60 -2078.12 3.04 5989729.04 12494.47 97.68 286.16 6844.42 6908.82 9283.20 9544.36 9285.19 9042.70 -2108.16 4.65 5989737.66 12526.43 98.15 289.12 6840.02 6904.42 9299.95 9576.01 9301.42 9052.29 -2138.32 9.29 5989746.77 12558.70 98.57 286.81 6835.33 6899.73 9317.00 9607.94 9318.03 9062.14 -2168.69 7.20 5989756.13 12590.39 98.81 283.29 6830.54 6894.94 9332.35 9639.27 9333.02 9070.27 -2198.94 11.01 5989763.78 12622.52 98.04 284.06 6825.83 6890.23 9347.27 9671.05 9347.64 9077.79 -2229.82 3.37 5989770.81 12654.21 95.67 284.10 6822.05 6886.45 9362.23 9702.51 9362.39 9085.44 -2260.34 7.48 5989777.97 12686.11 92.49 285.70 6819.78 6884.18 9377.75 9734.33 9377.79 9093.62 -2291.08 11.15 5989785.66 12718.30 88.60 285.45 6819.47 6883.87 9393.79 9766.51 9393.79 9102.26 -2322.08 12.11 5989793.81 Last MWD+IFR+MS 12750.22 87.98 285.32 6820.43 6884.83 9409.59 9798.41 9409.63 9110.73 -2352.84 1.98 5989801.79 TD (Projected) 12788.00 87.98 285.32 6821.76 6886.16 9428.26 9836.17 9428.46 9120.70 -2389.26 0.00 5989811.18 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata - gyro single shots --Gyrodata gyro orientation surveys. Not to be run above 70 degrees incl ination. ) MWD +IFR + MS - (In-field referenced MWD w ith mull-station analysis and correction applied in post-pro cessing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4526 FSL 4497 FEL S35 T12N R12E UM 5980730.34 618930.49 BHL : 3086 FSL 1594 FEL S22 T12N R12E UM 5989811.18 616396.95 b"I /UZ4.3V IV /U ZZ 4y."I /Z VV 14`J~ Z b4.b'L4 616998.13 N 70 22 49.341 W 149 2 55.282 616969.92 N 70 22 49.499 W 149 2 56.101 616939.83 N 70 22 49.645 W 149 2 56.975 616924.01 N 70 22 49.714 W 149 2 57.435 616891.24 N 70 22 49.846 W 149 2 58.388 616860.38 N 70 22 49.958 W 149 2 59.286 616829.62 N 70 22 50.064 W 149 3 0.182 616801.64 N 70 22 50.159 W 149 3 0.996 616770.15 N 70 22 50.267 W 149 3 1.913 616740.12 N 70 22 50.368 W 149 3 616709.40 N 70 22 50.465 W 149 3 616679.23 N 70 22 50.555 W 149 3 4.561 616648.92 N 70 22 50.649 W 149 3 5.444 616618.40 N 70 22 50.746 W 149 3 6.333 616588.03 N 70 22 50.826 W 149 3 7.219 616557.04 N 70 22 50.899 W 149 3 8.122 616526.40 N 70 22 50.975 W 149 3 9.016 616495.54 N 70 22 51.055 W 149 3 9.916 616464.41 N 70 22 51.140 W 149 3 10.823 616433.52 N 70 22 51.223 W 149 3 11.723 616396.95 N 70 22 51.321 W 149 3 12.789 • ~"'~ „~ ~a%~ ~U~ SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-111\S-111\S-111 PB2\S-111 P62 Generated 6/20/2005 2:39 PM Page 5 of 5 SCHLUMBERGER Survey report. 1-Jul-2005 10:10:12 Client .................... BP Exploration (Alaska) Inc. Field...... ................ Aurora Well ...................... S-111 API number ...............: 50-029-23257-00 Engineer .................: Davies Rig :...................... Nabors 7ES State :.................... Alaska Page 1 of 13 Spud date: ...............: 14-May-2005 Last survey date.........: O1-Jul-05 Total accepted surveys...: 331 MD of first survey.......: 0.00 ft MD of last survey........: 18090.00 ft ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 35.60 ft KB above permanent.......: 0.00 ft DF above permanent.......: 64.40 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 Vsect Origin to target: 345.69 degrees [(c)2005 IDEAL ID9 1C 02] ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 29-May-2005 Magnetic field strength..: 1152.55 HCNT Magnetic dec (+E/W-).....: 24.60 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Criteria --------- Reference G ..............: 1002.68 meal Reference H ..............: 1152.55 HCNT Reference Dip ............: 80.85 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-) 6.00 HCNT ,..Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)...... 24.60 degrees Grid. convergence (+E/W-).. 0.00 degrees Total az corr (+E/W-)....: 24.60 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 • • Ci ~'~ ~ SCHLUMBERGER Survey Report 1-Jul-2005 10:10:.12 Page 2 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (f t) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 329.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.67 43.93 100.00 100.00 0.31 0.42 0.41 0.58 43.93 0.67 GYR 3 200.00 0.73 19.31 100.00 199.99 1.15 1.44 1.02 1.77 35.30 0.30 GYR 4 258.00 1,01 22.64 58.00 257.98 1.86 2.26 1.34 2.63 30.64 0.49 GYR 5 349.00 1.52 17.00 91.00 348.96 3.53 4.16 2.00 4.62 25.71 0.58 GYR 6 438.00 1.63 344.77 89.00 437.93 5.81 6.51 2.02 6.81 17.20 0.99 GYR 7 528.00 1.80 341.86 90.00 527.89 8.50 9.09 1.24 9.17 7.76 0.21 GYR 8 620.00 2.55 338.43 92.00 619.82 11.97 12..36 0.04 12.36 0.17 0.83 GYR 9 714.00 3.96 336.62 94.00 713.67 17.25 17.29 -2.02 17.41 353.33 1.50 GYR 10 808.00 4.97 332.16 94.00 807.38 24.41 23.87 -5.21 24.43 347.69 1.14 GYR I1 904.00 7.85 326.42 96.00 902.77 34.65 .33.01 -10.78 34.72 341.91 3.07 GYR 12 1028.00 10.36 328.63 124.00 1025.20 53.30 49.59 -21.27 53.95 336.78 2.04 GYR 13 1090.00 11.79 331.47 62.00 1086.05 64.77 59.91 -27.20 65.79 335.58 2.47 GYR 14 1180.00 13.86 334.14 90.00 1173.80 84.25 .77.69 -36.29 85.75 334.96 2.39 GYR 15 1280.00 15.33 335.85 100.00 1270.57 109.01 100.53 -46.92 110.94 334.98 1.53 GYR 16 1404,53 19.54 334.81 124.53 1389.35 145.70 134.41 -.62.53 148.25 335.05 3.39 MWD_IFR _MS 17 1499.49 25.21 331.98 94.96 1477.13 180.97 166.66 -78.80 184.36 334.69 6.08 MWD_IFR _MS 18 1593,68 26.54 331.78 94.19 1561.87 220.89 202.92 -98.18 225.42 334.18 1.42 MWD_IFR _MS 19 1687.93 30.86 329.24 94.25 1644.53 264.53 242.26 -120.51 270.58 333.55 4.76 MWD_IFR _MS 20 1781.40 36.16 329.01 93.47 1722.43 313.97 286.53 -146.99 322.03 332.84 5.67 MWD IFR MS 21 1876.90 39.00 329.27 95.50 1798.11 369.80 336.53 -176.85 380.17 332.28 2.98 MWD_IFR _MS 22 1967.35 41.91 330.08 90.45 1866.93 426.20 387.18 -206.47 438.80 331.93 3.27 MWD_IFR _MS 23 2061.33 42.94 329.92 93.98 1936.30 487.24 442.09 -238.17 502.17 331.69 1.10 MWD_IFR _MS 24 2154.74 47.00 328.55 93.41 2002.37 550.53 498.79 -271.96 568.11 331.40 4.47 MWD_IFR _MS 25 2248.34 50.22 328.08 93.60 2064.25 617.54 558.53 -308.84 638.23 331.06 3.46 MWD IFR MS 26 2344.78 53.50 332.75 96.44 2123.82 690.68 624.48 -346.21 714.03 331.00 5.10 MWD_IFR _MS 27 2438.24 54.72 336.67 93.46 2178.62 764,99 692.93 -378.52 789.58 331.35 3.64 MWD_IFR _MS 28 2532.07 53.92 340.20 93.83 2233.36 .840.57. 763.79 -406.54 865.24 331.98 3.17 MWD_IFR _MS 29 2627.85 53.32 343.35 95.78 2290.18 917.49 .837.01 -430.66 941.31 332.77 2.72 MWD_IFR _MS 30 2723.01 55.08 348.05 95.16 2345.86 994.63. 911.77 -449.68 1016.63 333.75 4.41 MWD IFR MS • • [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-2005 10:10:12 Page 3 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 31 2816.27 55.41 349.56 93.26 2399.03 1071.13 986.93 -464.55 1090.80 334.79 1.38 MWD _IFR _MS 32 2910.74 57.46 349.87 94.47 2451.26 1149.65 1064.38 -478.60 1167.04 335.79 2.19 MWD _IFR _MS 33 3004.77 58.15 350.29 94.03 2501.36 1228.99 1142.76 -492.31 1244.30 336.69 0.83 MWD _IFR _MS 34 3099.37 60.20 349.47 94.60 2549.83 1310.01 1222.73 -506.59 1323.52 337.50 2.29 MWD _IFR _MS 35 3195.33 59.70 350.00 95.96 2597.88 1392.86 1304.46 -521.39 1404.80 338.21 0.71 MWD IFR MS 36 3286.94 59.77 349.98 91.61 2644.06 1471.76 1382'..38 -5.35.15 1482.35 338.84 0.08 MWD_ IFR _MS 37 3381.89 59.51 349.92 94.95 2692.05 1553.46 1463.05 -549.44 1562.82 339.42 0.28 MWD_ IFR_ MS 38 3476.60 58.94 350.39 94.71 2740.51 1634.59 1543.23. -563.36 1642.84 339.95 0.74 MWD_ IFR_ MS 39 3570.82 58.07 350.35 94.22 2789.73 1714.66 1622.43 -576.80 1721.91 340.43 0.92 MWD_ IFR_ MS 40 3665.03 59.50 349.04 94.21 2838.55 .1795.03 1701.70. -591.22 1801.48 340.84 1.93 MWD IFR MS 41 3761.05 60.62 348.99 96.02 2886.48 1878.10 1783.38 -607.07 1883.87 341.20 1.17 MWD_ IFR_ MS 42 3853.78 60.25 349.28 92.73 2932.23 1958.61 1862.59. -622.28 1963.79 341.53 0.48 MWD_ IFR_ MS 43 3949.40 61.11 348.18 95.62 2979.05 2041.86 ' 1944.35 -638.57 2046.53 341.82 1.35 MWD_ IFR_ MS 44 4043.33 61.12 348.18 93.93 3024.43 2124.02 2024.85 -655.42 2128.28 342.06 0.01 MWD_ IFR_ MS 45 4136.88 61.67 347.99 93.55 3069.22 2206.08 2105.21 -672.38 2209.98 342.29 0.61 MWD IFR MS 46 4231.68 60.80 347.89 94.80 3114.83 2289.12 2186.48 -689.74 2292.69 342.49 0.92 MWD_ IFR_ MS 47 4325.59 60.31 347.72 93.91 3161.00 2370.84 2266.41 -707.01 2374.13 342.67 0.55 MWD_ IFR_ MS 48 4419.39 60.14 348.19 93.80 3207.58 2452.20 2346.04 -724.00 2455.21 342.85 0.47 MWD_ IFR_ MS 49 4512.55 60.46 348.67 93.16 3253.74 2533.02 2425.31 -740.23 2535.76 .343.03 0.56 MWD_ IFR_ MS 50 4606.34 61.13 349.24 93.79 3299.50 2614.76 2505.66 -755.92 2617.20 343.21 0.89 MWD IFR MS 51 4652.01 61.49 349.24 45.67 3321.43 2654.74 2545.02 -763.39 2657.05 343.30 0.79 MWD_ IFR_ MS 52 4773.91 60.57 350.51 121.90 3380.47 2761,10 2650.00. -782.15 2763.02 343.56 1.18 MWD_ IFR_ MS 53 4868.80 60.52 350.63 94.89 3427.13 2843.43. 2731.51 -795.68 2845.04 343.76 0.12 MWD_ IFR_ MS 54 4962.75 60.46 350.82 93.95 3473.41 2924.87 2812.20 -808.86 2926.22 343.95 0.19 MWD_ IFR_ MS 55 5057.85 60.05 350.95 95.10 3520.59 3007.11 2893.73 -821.94 3008.20 344.14 0.45 MWD IFR MS 56 5150.46 60.08 351.71 92.61 3566.81 3086.97 2973.07 -834.04 3087.84 344.33 0.71 MWD_ IFR_ MS 57 5244.62 59.67 352.63 94.16 3614.06 3167.89 3053.75 -845.14 3168.54 344.53 0.95 MWD_ IFR ^ MS 58 5340.69 58.56 354.01 96.07 3663.38 3249.6:0 3135.63 -854.73 3250.04 344.75 1.69 MWD_ IFR MS 59 5435.12 57.74 354.66 94.43 3713.21 3328.90 3215.45 -862.65 3329.16 344.98 1.05 MWD_ IFR_ MS 60 5529.14 57.06 355.64 94.02 3763.87 3407.03 3294.37 -869.35 3407.15 345.22 1.14 MWD IFR MS .~ • [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-2005 10:10:.12 Page 4 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5624.51 57.71 355.22 95.37 3815.27 3486.21 3374.45 -875.75 3486.24 345.45 0.78 MWD _IFR _MS 62 5718.42 59.59 355.67 93.91 3864.13 3565.24 3454.39 -882.12 3565.24 345.68 2.04 MWD _IFR _MS 63 5813.42 60.12 355.51 95.00 3911.83 3646.17 3536.30 -888.44 3646.19 345.90 0.58 MWD _IFR _MS 64 5906.13 60.10 353.85 92.71 3958.04 3725.56 3616.33 -895.89 3725.65 346.09 1.55 MWD _IFR _MS 65 6000.52 60.14 352.35 94.39 4005.06 3806.71 3697.57 -905.72 3806.89 346.24 1.38 MWD IFR MS 66 6096.27 59.39 351.94 95.75 4053.28 3888.91 3779.52 -917.02 3889.18 346.36 0.87 MWD _IFR _MS 67 6189.94 59.29 351.81 93.67 4101.04 3969.02 3859.29 -928.41 3969.39 346.47 0.16 MWD _IFR _MS • 68 6285.89 59.51 352.35 95.95 4149.89 4051.09 3941.09 -939.79 4051.59 346.59 0.54 MWD _IFR _MS 69 6379.85 59.65 352.23 93.96 4197.46 4131.58 4021.38 -950.66 4132.22 346.70 0.19 MWD _IFR _MS 70 6474.84 59.88 352.18 94.99 4245.29 4213.12 4102.69 961.79 4213.92 346.81 0.25 MWD IFR MS 71 6570.13 60.12 352.54 95.29 4292.94 4295.08 4184.48 -972.76 4296.06 346.91 0.41 MWD _IFR_ MS 72 6663.31 60.43 352.19 93.18 4339.14 4375.45 4264.68 -983.52 4376.62 347.01 0.47 MWD _IFR_ MS 73 6758.68 60.21 351.64 95.37 4386.36 4457.82 4346.72 -995.17 4459.18 347.10 0.55 MWD _IFR_ MS 74 6852.70 59.78 351.42 94.02 4433.38 4538.82 4427.25 -1007.16 4540.36 347.18 0.50 MWD _IFR_ MS 75 6946.12 59.23 350.37 93.42 4480.79 4618.98 4506.73 -1019.90 4620.69 347.25 1.13 MWD IFR MS 76 7041.39 59.07 350.13 95.27 4529.64 4700.51 4587.34 -1033.75 4702.37 347.30 0.27 MWD_ IFR_ MS 77 7137.02 58.82 350.90 95.63 4578.97 4782.15 4668.14 -1047.25 4784.17 347.36 0.74 MWD _IFR_ MS 78 7232.52 58.32 350.82 95.50 4628.77 4863.30 4748.59 -1060.19 4865.51 347.41 0.53 MWD_ IFR_ MS 79 7326.67 58.30 351.04 94.15 4678.23 4943.08 4827.70 -1072.82 4945.47 347.47 0.20 MWD_ IFR_ MS 80 7419.55 58.46 351.71 92.88 4726.93 5021.78 4905.90 -1084.68 5024.38 347.53 0.64 MWD IFR MS 81 7514.82 58.46 351.69 95.27 4776.76 5102.53 4986.25 -1096.40 5105.36 347.60 0.02 MWD _ IFR MS 82 7609.96 58.71 352.08 95.14 4826.35 5183.25 5066.63 -1107.86 5186.33 347.67 0.44 - MWD - IFR • MS 83 7703.91 59.14 352.73 93.95 4874.85 5263.17 5146.39 -1118.50 5266.53 347.74 0.75 MWD_ IFR_ MS 84 7798.23 59.15 353.33 94.32 4923.22 5343.47 5226.76 -1128.32 5347.16 347.82 0.55 MWD_ IFR_ MS 85 7894.94 58.72 352.47 96.71 4973.13 5425.66 5308.96 -1138.56 5429.68 347.90 0.88 MWD IFR MS 86 7990.23 58.56 352.46 95.29 5022.72 5506.46 5389.63 -1149.23 5510.79 347.96 0.17 MWD_ IFR_ MS 87 8085.44 58.48 352.72 95.21 5072.43 5587.07 5470.15 -1159.70 5591.73 348.03 0.25 MWD_ IFR_ MS 88 8181.11 58.59 353.06 95.67 5122.37 5668.03 5.551.12 -1169.81 5673.04 348.10 0.32 MWD_ IFR_ MS 89 8276.38 58.45 352.70 95.27 5172.12 5748.64 5631.74 -1179.89 5754.01 .348.17 0.35 MWD_ IFR_ MS 90 8370.59 57.98 351.87 94.21 5221.75 5828.19 5711.10 -1190.64 5833.89 348.22 0.90 MWD IFR MS [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-2005 10::10:12 Page 5 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) {ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8464.52 58.03 352.19 93.93 5271.51 5907.36 5789.9 -1201.68 5913.38 348.28 0.29 MWD _IFR _MS 92 8558.10 57.86 351.12 93.58 5321.18 5986.24 5868.46 -1213.19 5992.55 348.32 0.99 MWD _IFR _MS 93 8652.36 57.77 352.45 94.26 5371.40 6065,56 5947.41 -1224.59 6072.18 348.37 1.20 MWD _IFR _MS 94 8747.42 58.33 352.16 95.06 5421.71 6145.68 6027.34 -1235.39 6152.64 348.42 0.65 MWD _IFR _MS 95 8841.28 59.20 352.21 93.86 5470.38 6225.42 6106,85 -1246.30 6232.73 348.47 0.93 MWD IFR MS 96 8937.02 60.26 351.95 95.74 5518.64 6307.59 6188.74 -1257.70 6315.25 348.51 1.13 MWD _IFR _MS 97 9030.86 60.17 351.67 93.84 5565.25 6388.57 6269,36 -1269.30 6396.56 348.55 0.25 MWD_ IFR _MS 98 9126.25 59.99 351.70 95.39 5612.83 6470.79 6351.16 -12,81.26 6479.11 348.59 0.19 MWD_ IFR _MS 99 9221.66 59.83 351.33 95.41 5660.67 6552.92 6432.81 -1293.44 6561.56 348.63 0.38 MWD_ IFR _MS 100 9315.42 59.56 351.28 93.76 5707.98 6633.48 6512.83 -1305.67 6642.42 348.66 0.29 MWD IFR MS 101 9409.72 59.66 351.54 94.30 5755.68 6714,41 6593.26 -1317.82 6723.67 348.70 0.26 MWD_ IFR _MS 102 9504.00 59.63 351.61 94.28 5803.33 6795.34 6673.74 -1329.74 6804.93 348.73 0.07 MWD_ IFR _MS 103 9598.44 59.89 352.19 94.44 5850.89 6876.45 6754.51 -1341.24 6886.39 348.77 0.60 MWD_ IFR _MS 104 9691.65 59.80 352.11 93.21 5897.71 6956.53 6834.35 -1352.25 6966.85 348.81 0.12 MWD_ IFR _MS 105 9785.13 59.71 352.96 93.48 5944.80 7036.71 6914.42 -1362.74 7047.43 348.85 0.79 MWD IFR MS 106 9877.65 59.31 352.79 92.52 5991.74 7115.81 6993.53 -1372.63 7126.96 348.90 0.46- MWD_ IFR_ MS 107 9972.07 58.61 352.96 94.42 6040.43 7196.08 7073.81 -1382.66 7207.67 348.94 0.76 MWD_ IFR_ MS 108 10066.96 58.44 353.70 94.89 6089.98 7276.29 7154.19 -1392.06 7288.36 348.99 0.69 MWD_ IFR_ MS 109 10160.49 57.98 354.15 93.53 6139.25 7354.96 7233.24 -1400.48 7367.57 349.04 0.64 MWD_ IFR_ MS 110 10253.87 58.08 354.88 93.38 6188.69 7433.24 7312.09 -1408.05 7446.43 349.10 0.67 MWD IFR MS 111 10349.49 58.38 355.74 95.62 6239.04 .7513.39 7393.11 -1414.69 7527.25 349.17 0.83 MWD_ IFR_ MS 112 10444.31 58.31 355.62 94.82 6288.80 7592.88. 7473.60 -1420.77 7607.45 349.24 0.13 MWD_ IFR_ MS 113 10538.49 58.10 355.99 94.18 6338.42 7671.68 7553.43 -1426.63 7686.97 349.30 0.40 MWD_ IFR_ MS 114 10632.35 58.00 356.19 93.86 6388.09 7750.02 7632.88 -1432.06 7766.06 349.37 0.21 MWD_ IFR_ MS 115 10726.50 58.17 356.30 94.15 6437.86 7828.58 7712.63 -1437.29 7845.41 349.44 0.21 MWD IFR MS 116 10821.23 58.54 356.07 94.73 6487.56 7907.88 7793.10 -1442.66 7925.50 349.51 0.44 MWD_ IFR_ MS 117 10916.86 59.27 355.82 95.63 6536.95 7988.46 7874.78 -1448.45 8006.88 349.58 0.80 MWD_ IFR_ MS 118 11012.14 59.33 355.76 95.28 6585.60 8069.11 7956.49 -1454.47 8088.33 349.64 0.08 MWD_ IFR_ MS 119 11106.68 59.68 353.97 94.54 6633.57 8149.53 8037.62 -1461.76 8169.46 349.69 1.67 MWD_ IFR_ MS 120 11201.94 59.82 353.02 95.26 6681.56 8231.05 . 8119.37 -1471.08 8251.56 349.73 0.87 MWD IFR MS [(c)2005 IDEAL ID9 1C 02] • L J SCHLUMBERGER Survey Report 1-Jul-2005 10:10:;12 Page 6 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (f t) (ft) (f t) (f t) (deg) 100f) type (deg) 121 11296.04 60.42 351.93 94.10 6728.44 8312.07 8200.26 -1481.77 8333.06 349.76 1.19 MWD_IFR_MS 122 11390.27 62.80 352.27 94.23 6773.25 8394.44 8282.36 -1493.16 8415.88 349.78 2.55 MWD_IFR_MS 123 11484.93 65.11 352.56 94.66 6814.81 8478.90 8366.66 -1504.38 8500.83 349.81 2.46 MWD_IFR_MS 124 11536.00 66.53 352.71 51.07 6835.72 8525.T5 8412.87 -1510.35 8547.37 349.82 2.79 Top of Window 125 11549.00 68.28 351.50 13.00 6840.72 8537.07 8424.75 -1512.00 8559.36 349.83 15.97 Bottom of Window 126 11562.39 67.19 351.50 13.39 6845.79 8549.40 8437.01 -1513.83 8571.75 349.83 8.14 End of Milling 127 11573.96 67.11 350.90 11.57 6850.28 8560.01 8447.55 -1515.47 8582.40 349.83 4.83 Inclination Only 128 11602.82 68.23 349.44 28.86 6861.25 8586.63 8473.85 -1520.02 8609.10 349.83 6.08 Inclination Only 129 11635.27 70.31 347.82 32.45 6872.74 8616.93 8503.60 -1526.01 8639.44 349.83 7.93 Inclination Only 130 11666.52 71.82 346.29 31.25 6882.88 8646.48 8532.40 -1532.63 8668.96 349.82 6.69 Inclination Only 131 11698.65 73.09 344.75 32.13 6892.56 8677.12 8562.06 -1540.29 8699.51 349.80 6.04 Inclination Only 132 11730.59 74.94 343.24 31.94 6901.36 8707.81 8591.58 -1548.76 8730.05 349.78 7.36 Inclination Only 133 11767.70 76.84 338.44 37.11 6910.41 8743.65 8625.56 -1560.57 8765.59 349.74 13.55 MWD_IFR_MS 134 11793.51 77.93 335.49 25.81 6916.05 8768.54 8648.73 -1570.43 8790.16 349.71 11.93 MWD_IFR_MS 135 11826.51 78.93 334.42 33.00 6922.67 8800.31. 8678.02 -1584.12 8821.42 349.65 4.39 MWD IFR MS 136 11864.17 80.40 332.93 37.66 6929.42 8836.54 8711.23 -1600.55 8857.04 349.59 5.51 MWD_IFR_MS 137 11896.84 81.44 329.50 32.67 6934.58 8867.77 8739.50 -1616.08 8887.66 349.52 10.84 MWD_IFR_MS 138 11929.57 82.13 325.87 32.73 6939.26 8898.58 8766.87 -1633.39 8917.73 349.45 11.18 MWD_IFR_MS 139 11960.66 83.76 323.84 31.09 6943.08 8927.41 8792.09 -1651.15 8945.79 349.36 8.34 MWD_IFR_MS 140 11995.68 85.62 318.85 35.02 6946.32 8959.17. 8819.31 -1672.93 8976.58 349.26 15.15 MWD IFR MS 141 12023.87 86.85 315.59 28.19 6948.17 8983.89 8839.96 -1692.03 9000.43 349.16 12.34 MWD _IFR MS 142 12055.47 88.40 312.37 31.60 6949.48 9010.74 8861.88 -1714.75 9026.25 349.05 11.30 - - MWD IFR MS 143 12090.46 90.42 307.82 34.99 6949.84 9039.19. 8884.40 -1741.50 9053.48 348.91 14.23 MWD_IFR_MS 144 12120.04 91.86 305.38 29.58 6949.25 9062.14 8902.03 -1765.24 9075.37 348.78 9.58 MWD_IFR_MS 145 12151.15 92.61 301.71 31.11 6948.04 9085.18 8919.21 -1791.15 9097.28 348.64 12.06 MWD IFR MS 146 12183.47 94.09 298.08 32.32 6946.15 9107.67 8935.28 -1819.12 9118.58 348.49 12.08 MWD_IFR_MS 147 12216.97 96.40 294.87 33.50 6943.09 9129.46 8950.15 -1848.97 9139.14 348.33 11.77 MWD IFR MS 148 12234.31 97.26 293.33 17.34 6941.02 9140.16 8957.18 -1864.69 9149.22 348.24 10.12 MWD_IFR_MS 149 12269.82 97.58 291.35 35.51 6936.44 9161.17 8970.57 -1897.26 9169.00 348.06 5.60 Inclination Only 150 12302.84 97.29 289.51 33.02 6932.17 9179.83 8982.00 -1927.94 9186.58 347.89 5.59 MWD IFR MS [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-2005 10:10:12 Page 7 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (f t) (deg) 100f) type (deg) 151 12335.54 97.13 289.30 32.70 6928.06 9197.84 8992.77 -1958.53 9203.58 347.71 0.80 MWD _IFR _MS 152 12365.23 96.85 289.11 29.69 6924.45 9214.11 9002.47 -1986.36 9219.01 347.56 1.14 MWD _IFR _MS 153 12398.64 96.55 289.39 33.41 6920.55 9232.45 9013.41 -2017.69 9236.48 347.38 1.22 MWD _IFR _MS 154 12428.37 96.85 284.18 29.73 6917.08 9247.70 9021.93 -2045.95 9251.01 347.22 17.43 MWD _IFR _MS 155 12459.46 93.85 286.71 31.09 6914.18 9263.06 9030.17 -2075.78 9265.68 347.05 12.60 MWD IFR MS 156 12492.43 93.55 285.48 32.97 6912.05 9279.71 9039.30 -2107.39 9281.70 346.88 3.83 MWD_ IFR _MS 157 12524.34 93.72 286..06 31.91 6910.03 9295.67 9047.95 -2138.04 9297.13 346.70 1.89 MWD_ IFR _MS 158 12556.14 93.89 286.08 31.80 6907.92 9311.72 9056.73 -2168.53 9312.73 346.53 0.54 MWD_ IFR _MS 159 12588.27 94.23 286.05 32.13 6905.64 9327.92 9065.60 -2199.33 9328.57 346.36 1.06 MWD_ IFR _MS 160 12619.83 93.10 285.96 31.56 6903.63' 9343.82 9074.29 -2229.60 9344.19 346.20 3.59 MWD IFR MS 161 12650.78 90.42 287.05 30.95 6902.68 9359.67 9083.08 -2259.26 9359.83 346.03 9.35 MWD_ IFR _MS 162 12682.86 90.15 285.48 32.08 6902.52 9375.98 9092.06 -2290.05 9376.03 345.86 4.97 MWD_ IFR _MS 163 12715.08 89.33 284.68 32.22 6902.6.6 9391.80 9100:44 -2321.16 9391.80 345.69 3.56 MWD_ IFR _MS 164 12747.60 90.18 284.47 32.52 6902.80 9407.50 9108.63 -2352.63 9407.55 345.52 2.69 MWD_ IFR _MS 165 12779.98 91.45 284.93 32.38 69.02.34 9423.21. 9116.84 -2383.95 9423.38 345.35 4.17 MWD IFR MS 166 12812.08 91.73 286.40 32.10 6901.45. 9439.24 9125.50 -2414.85 9439.61 345.18 4.66 MWD_ IFR _MS 167 12843.39 90.46 284.86 31.31 6900.85 9454.86 9133..94 -2444.99 9455.52 345.01 6.37 MWD_ IFR _MS 168 12874.62 90.64 285.57 31.23 6900.50 9470.25 9142..13 -2475.12 9471.26 344.85 2.58 MWD_ IFR _MS 169 12907.13 90.66 285.27 32.51 6900.07 9486.37 9150.78 -2506.46 9487.84 344.68 1.08 MWD_ IFR _MS 170 12938.19 90.90 284,52 31.06 6899.65 9501.52 9158.76 -2536.47 9503.50 344.52 2.53 MWD IFR MS 171 12970.50 90.84 287.01 32.31 689.9.16 9517.71 9167.54 -25.67.56 9520.30 344.35 7.71 MWD_ IFR _MS 172 13002.71 90.87 287.24 32.21 6898.68 9534.51 9177.02 -2598.34 9537.77 344.19 0.72 MWD_ IFR _MS 173 13033.92 91.08 286.51 31.21 6898.15. 9550.67 9186..08 -26.28.20 9554.66 344.03 2.43 MWD_ IFR _MS 174 13069.22 91.04 286.45 35.30 6897.49 9568.73 9196.09 -2662.05 9573.64 343.86 0.20 MWD_ IFR _MS 175 13100.09 90.12 288.33 30.87 6897.18 9584.95 9205.32 -2691.50 9590.73 343.70 6.78 MWD IFR MS 176 13130.90 89.64 288.98 30.81 6897.25 9601.72 9215.17 -2720.69 9608.41 343.55 2.62 MWD_ IFR _MS 177 13165.46 90.15 288.31 34.56 6897.31 9620.5.2 9226..2.2 -2753.44 9628.32 343.38 2.44 MWD_ IFR _MS 178 13196.57 89.77 288.81 31.11 6897.33. 9637.:40 9236.1.2 -2782.93 9646.28 343.23 2.02 MWD_ IFR _MS 179 13226.96 89.05 288.35 30.39 6897.64 9653.90 9245.81 -2811.74 9663.89 343.09 2.81 MWD_ IFR _MS 180 13261.14 89.46 290.53 34.18 6898.09 . 9672.89 9257.18 -2843.96 9684.19 342.92 6.49 MWD IFR MS • .7 [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-2005 1Q:10:12 Page 8 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) _{ft) (ft) (ft) (deg) 100f) type (deg) 181 13292.00 88.33 289.14 30.86 6898.68 9690.21 9267.65 -2.872.98 9702.75 342.78 5.80 MWD _IFR _MS 182 13322.13 88.54 287.52 30.13 6899.51 9706.45 9277.12 -2901.57 9720.29 342.63 5.42 MWD_ IFR _MS 183 13354.47 88.71 289.79 32.34 6900.28 9724.04 9287.46 -2932.20 9739.34 342.48 7.04 MWD_ IFR _MS 184 13386.65 88.16 293.29 32.18 6901.16 9742..88 9299.27 -2962.12 9759.64 342.33 11.01 MWD_ IFR _MS 185 13415.89 87.20 297.56 29.24 6902.35 9761.55 9311.81 -2988.50 9779.62 342.21 14.96 MWD IFR MS 186 13449.37 87.44 300.02 33.48 6903.9.1 9784.40 9327.92 -3017.81 9803.94 342.07 7.37 MWD_ IFR _MS 187 13480.69 88.37 304.78 31.32 6905.06 9807.18 9344.68 -3044.23 9828.04 341.96 15.48 MWD_ IFR _MS 188 13512.30 87.72 306.76 31.61 6906.14 9831.4.0 9363._15 -3069.86 9853.55 341.85 6.59 MWD_ IFR _MS 189 13544.60 87.13 305.78 32.30 6907.59 9856.33 9382.24 -3.095.87 9879.82 341.74 3.54 MWD_ IFR _MS 190 13575.81 87.58 305.75 31.21 6909.0:3 988.0.24 94.00.46 -3,121.17 9905.06 341.63 1.45 MWD IFR MS 191 13607.85 87.61 308.38 32.04 6910.37 99..05.25 9419.75 -3146.71 9931.44 341.53 8.20 MWD_ IFR _MS 192 13640.56 88.67 306.87 32.71 6911.43 9930.99 9439.71 -3172.60 9958.59 341.42 5.64 MWD_ IFR _MS 193 13671.98 90.77 306.13 31.42 6911.59 9955.34 94.58.40 -3197.86 9984.37 341.32 7.09 MWD_ IFR _MS 194 13703.66 90.56 308.93 31.68 6911.22 9980.24 9477.69 -3222.98 10010.71 341.22 8.86 MWD_ IFR _MS 195 13736.09 89.94 306.67 32.43 6911.08 10005.83 94.97.57 -3248.60 10037.79 341.12 7.23 MWD IFR MS 196 13767.10 89.88 307.10 31.01 6911.13 10030.00 9516.18 -3273.40 10063.44 341.02 1.40 MWD_ IFR _MS 197 13799.11 89.94 303.12 32.01 6911.18 10054.31 9534.59 -3299.59 10089.38 340.91 12.43 MWD_ IFR _MS 198 13831.27 89.70 301.46 32.16 6911.28 10077.67 9551.76 -3326.77 10114.52 340.80 5.22 MWD_ IFR _MS 199 13864.02 89.91 299.90 32.75 6911.39 10100.82 9568.47 -3354.94 10139.59 340.68 4.81 MWD_ IFR _MS 200 13895.63 90.90 298.22 31.61 6911.17 10122.53 9583.83 -3382.56 10163.24 340.56 6.17 MWD IFR MS 201 13923.83 90.26 306.39 28.20 6910.88 10143.00 9598.88 -3406.38 10185.38 340.46 29.06 MWD_ IFR _MS 202 13969.77 88.08 306.86 45.94 6911.54 10178.67 9626.29 -3443.24 10223.57 340.32 4.85 MWD_ IFR _MS 203 13988.40 87.13 309.41 18.63 6912.32 10193.42 9637.78 -3457.88 10239.32 340.26 14.59 MWD_ IFR _MS 204 14019.76 86.45 310.37 31.36 6914.08 10218.82 9657.86 -3481.90 10266.35 340.17 3.75 MWD_ IFR _MS 205 14050.69 87.88 305.73 30.93 6915.61 10243.27 9676.89 -3506.22 10292.51 340.08 15.68 MWD IFR MS 206 14083.95 90.80 304.64 33.26 6915.99 10268.56 9696.05 -3533.40 10319.81 339.98 9.37 MWD_ IFR_ MS 207 14114.15 90.15 305.83 30.20 6915.74 10291.54 9713.48 -3558..07 10344.63 339.88 4.49 MWD_ IFR_ MS 208 14146.59 90.57 305.75 32.44 6915.54 10316.42 9732.45 -3584.38 10371.51 339.78. 1.32 MWD_ IFR_ MS 209 14179.49 90.43 308.74 32.90 6915.25 10342.18 9752.36 -3610.57 10399.26 339.68 9.10 MWD_ IFR_ MS 210 14210.83 88.88 310.61 31.34 6915.44 10367.53 9772.36 -3634.69 10426.41 339.60 7.75 MWD IFR MS • • [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-20.05 10:10:12 Page 9 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 211 14242.70 87.47 313.56 31.87 691F.46 10:394.06 9793.71. -365.8.32 10454.67 339.52 10.25 MWD_ IFR _MS 212 14275.25 86.37 312.60 32.55 6918.21. 10421.44 9815.91 -3682.06 10483.78 339.44 4.48 MWD_ IFR _MS 213 14307.23 87.15 311.42 31.98 6920.01 10448.01 9837.28 -3705.79 10512.13 339.36 4.42 MWD_ IFR _MS 214 14338.51 88.82 307.99 31.28 6921.11 10473.30 9857.2.4 -3729.83 10539.30 339.27 12.19 MWD_ IFR _MS 215 14370.67 88.85 307.17 32.16 6921.77 10498.59 9'876.85 -3755.31 10566.67 339.18 2.55 MWD_ IFR MS 216 14401.89 88.49 304.14 31.22 6922.49 10522.49 9895.04 -37.80.67 10592.70 339.09 9.77 MWD_ IFR _MS 217 14434.38 87.96 303.89 32.49 6923.50 10546.75 9913.21 -3807.59 10619.30 338.99 1.80 MWD_ IFR _MS 218 14464.83 88.17 302.10 30.45 6924.53 10569.11 9929.78 -3833.11 10643.93 338.89 5.92 MWD_ IFR _MS 219 14497.99 89.34 303.01 33.16 6925.25 10593.30 9947.62 -3861.06 10670.66 338.79 4.47 MWD_ IFR _MS 220 14530.28 90.30 303.55 32.29 6925.35 10617.14 9965.34 -3888.05 10696.96 338.69 3.41 MWD_ IFR MS 221 14561.85 67.06 307.95 31.57 6926.08 10641.33 9983.77 -3913.65 10723.45 338.59 17.30 MWD_ IFR _MS 222 14593.76 85.73 306.73 31.91 6928.08 10666.31 10003.09 -3938.97 10750.69 338.51 5.65 MWD_ IFR _MS 223 14625.25 85.53 304.62 31.49 6930.48 10690.35 10021.40 -3964.48 10777.08 338.42 6.71 MWD_ IFR _MS 224 14657.70 87.64 304.55 32.45 6932.42 10714.76 10039.78 -3991.14 10804.00 338.32 6.51 MWD_ IFR _MS 225 14689.04 89.33 301.21 31.34 6933.24 10737.74 10056.79 -4017.45 10829.54 338.22 11.94 MWD_ IFR MS 226 14721.28 89.67 301.45 32.24 6933.53 10760.79 10073.55 -4044.99 10855.34 338.12 1.29 MWD_ IFR _MS 227 14753.04 89.19 297.41 31.76 6933.84 10782.74 10089.15 -4072.64 10880.14 338.02 12.81 MWD_ IFR _MS 228 14785.25 90.62 295.20 32.21 6933.89 10803.71 10103.43 -4101.51 10904.20 337.91 8.17 MWD_ IFR _MS 229 14817.17 92.59 293.44 31.92 6933.00 10823.63 10116.57 -4130.59 10927.33 337.79 8.27 MWD_ IFR _MS 230 14846.64 93.22 293.21 29.47 6931.51 10$41.60. 10128.22 -4157.61 10948.36 337.68 2.28 MWD_ IFR MS 231 14878.28 93.10 293.26 31.64 6929.76 10860.85 10140.68 -4186.64 10970.94 337.57 0.41 MWD_ IFR _MS 232 14911.64 92.00 296.81 33.36 6928.28 10881.97 10154.78 -4216.83 10995.51 337.45 11.13 MWD_ IFR _MS 233 14942.92 89.62 297.52 31.28 6927.84 10902.69. 10169.06 -4244.66 11019.39 337.34 7.94 MWD_ IFR _MS 234 14973.54 89.98 297.91 30.62 6927.94 10923.19 10183.30 -4271.77 11042.99 337.24 1.73 MWD IFR _MS 235 14998.47 89.34 296.68 24.93 6928.09 10939.74 10194.73 -42:93.92 11062.11 337.16 5.56 MWD_ IFR MS 236 15039.94 88.28 296.33 41.47 6928.95 10966.84 10213.24 -4331.02 11093.60 337.02 2.69 MWD_ IFR _MS 237 15070.76 88.70 296.21 30.82 6929.76 10986.88 10226.87 -4358.65 11116.96 336.92 1.42 MWD_ IFR _MS 238 15102.35 88.77 295.21 31.59 6.930.46 11007.19 10240.57 -4387.10 11140.74 336.81 3.17 MWD_ IFR _MS 239 15133.88 89.13 291.93 31.53 69..31.04 11026.54 10253.18 -4416.00 11163.72 336.70 10.46 MWD_ IFR _MS 240 15165.92 89.62 291.27 32.04 6931.39 11045.33 10.264..97 -4445.78 11186.36 336.58 2.57 MWD_ IFR MS [(c)2005 IDEAL ID9 1C 02] • • SCHLUMBERGER Survey Report 1-Jul-2005 10.:10;12 Page 10 of 13 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 241 15198.42 89.83 291.63 242 15228.71 89.88 290.53 243 15262.57 89.85 288.19 244 15294.92 89.19 287.72 245 15326.46 89.59 288.38 246 15357.92 90.00 286.01 247 15390.46 90.93 285.92 248 15420.87 92.19 287.58 249 15453.63 92.88 286.88 250 15486.47 93.13 284.98 251 15518.09 94.71 286.77 252 15549.81 96.52 285.70 253 15581.50 97.70 286.12 254 15613.60 98.07 287.06 255 15645.05 97.48 287.80 256 15677.49 97,69 288.12 257 15709.84 97.75 289.37 258 15741.04 98.07 289.30 259 15773.04 97.98 289.74 260 15805.58 98.26 291.28 261 15837.23 98.03 291.32 262 15869.39 97.97 292.04 263 15901.76 97.96 293.16 264 15933.94 96.48 295.46 265 15965.94 94.82 295.52 266 15995.93 93.85 294.97 267 16031.66 91.88 298.40 268 16063.43 89.42 297.80 269 16091.46 88.73 297.84 270 16124.19 88.85 298.00 [(c)2005 IDEAL ID9 1C 02) Course length (f t) 32.50 30.29 33.86 32.35 31.54 31.46 32.54 30.41 32.76 32.84 31.62 31.72 31.69 32.10 31.45 32.44 32.35 31.20 32.00 32.54 31.65 32.16 32.37 32.18 32.00 29.99 35.73 31.77 28.03 32.73 TVD depth {ft) 6931.54 6931.62 6931.70 6931.97 6932.31 6932.42 6932.16 6931.33 6929.88 6928.16 6926.00 6922.89 6918.97 6914.57 6910.31 6906.03 6901.68 6897.39 6892.92 6888.33 6883.84 6879.37 6874.88 6870.84 6867.69 6865.42 6863.63 6863.27 686'3 . 72 6864.42 Vertical Displ Displ Total section +N/S- +E/W- displ (f t} (ft) (ft) (ft) 11064.32 10276.85 -4.476.03 11209.31 11081.87 10287.75 -4504.29 11230.60 11100.64 10298.97 -4536.24 11253.72 11117.91 10308.94 -4567.01 11275.28 11134.79 10318.72 -4597.00 11296.38 11151.22 10328.02 -4627.05 11317.13 11167.63 10336.97 -4658.33 11338.12 11183.31 10345.73 -4687.44 11358.09 11200.43 10355.42 -4718.70 11379.84 11216.95 10364.42 -4750.23 11401.14 11232.81 10373.05 -4'180.57 11421.65 11248.85 10381.87 -4810.88 11442.37 11264.68 10390.49 -4841.12 11462.93 11281.00 10399.57 -4871.59 11484.05 11297.40 10408.91 -4901.32 11505.14 11314.57 10418.82 -4931.91 11527.17 11332.05 10429.12 -4962.27 11549.49 11349.17 10439.36 -4991.43 11571.28 11366.81 10449.94 -5021.29 11593.74 11385.21 10461.23 -5051.46 11617.00 11403.45 10472.61 -5080.66 11639.96 11422.17 10484.38 -5110.25 11663.48 11441.42 10496.69 -5139.84 11687.54 11461.34 10509..84 -5168.94 11712.15 11481.73 10523.54 -5197.68 11737.15 11500.77 10536..29 -5224.73 11760.58 11524.17 10552.32 -5256.60 11789.12 11545.60 10567.28 -5284.62 11815.02 11564.4010580.36 -53.09.41 11837.81 11586.39 10595.68 -5338.33 11864.49 At Azim (deg) 336.46 336.35 336.23 336.11 335.99 335.87 335.74 335.63 335.50 335.38 335.26 335.14 335.02 334.90 334.79 334.67 334.55 334.45 334.34 334.23 334.12 334.01 333.91 333.81 333.71 333.62 333.52 333.43 333.35 333.26 DLS Srvy Tool (deg/ tool Corr 100f) type (deg) 1.28 MWD_IFR_MS 3.64 MWD_IFR_MS 6.91 MWD_IFR 2.50 MWD_IFR 2.45 MWD IFR MS 7.65 MWD_IFR 2.87 MWD_IFR 6.85 MWD IFR MS 3.00 MWDy_IFR+ 5.83 MWD IFR 7.54 MWD_IFR_MS 6.62 MWD_IFR 3.95 MWD_IFR 3.12 MWD_IFR 2.99 MWD IFR 1.17 MWD_IFR 3.83 MWD_IFR 1.05 MWD_IFR 1.39 MWD_IFR 4.76 MWD_IFR 0.74 MWD_IFR 2.22 MWD_IFR 3.43 MWD_IFR 8.45 MWD_IFR_MS 5.19 MWD_IFR_MS 3.72 MWD_IFR 11.06 MWD_IFR_MS 7.97 MWD_IFR_MS 2.47 MWD_IFR_MS 0.61 MWD IFR MS • SCHLUMBERGER Survey Report 1-Jul-2005.10:10..:12 Page 11 of 13 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (f t) {f t) (ft) (ft) (deg) 100f) type (deg) 271 16160.51 89.86 299.80 36.32 6864.82 11611.26 10613.23 -5370.12 11894.49 333.16 5.68 MWD _IFR _MS 272 16189.28 89.81 302.17 28.77 6864.91 11631.70 10628.04 -5394.78 11918.85 333.09 8.24 MWD _IFR _MS 273 16220.90 68.29 303.11 31.62 6865.43 11654..81 10645.09 -5421.40 11946.11 333.01 5.65 MWD _IFR _MS 274 16253.28 87.76 302.74 32.38 6866.55 11678.56 10662.68 -5448.57 11974.13 332.93 2.00 MWD _IFR _MS 275 16285.08 87.50 302.45 31.80 6867.86 11701.76 10679.80 -5475.33 12001.56 332.86 1.22 MWD IFR MS 276 16319.40 87.09 303.42 34.32 6869.48 11726.9.4 10698.44 -5504.11 12031.28 332.78 3.07 MWD _1FR _MS 277 16351.98 86.83 303.11 32.58 6871.21 11750.95 10716.28 -5531.31 12059.61 332.70 1.24 MWD IFR ` _MS 278 16379.64 86.39 303.49 27.66 6872.85 11771.34 10731..44 -5554.39 12083.67 332.63 2.10 MWD IFR _ _MS 279 16415.48 86.36 303.73 35.84 6875.11 11.797.89 10751.24 -5584.18 12114.96 332.55 0.67 MWD _IFR _MS 280 16445.04 85.44 305.23 29.56 6877.23- 11.820..07 10767.93 -5608.48 12140.98 332.49 5.94 MWD IFR MS 281 16475.59 83.97 305.41 30.55 6880.04 11843.25 10785.52 -5633.30 12168.05 332.42 4.85 MWD IFR_ I MS 282 16510.79 83.25 305.55 35.20 6883.96 11869.96 10805.82 -5661.78 12199.25 332.35 2.08 MWD IFR y _MS 283 16539.82 82.66 304.50 29.03 6887.52 11891.82 10822.36 -5685.38 12224.85 332.29 4.12 MWD_ IFR_ MS 284 16572.85 81.93 304.10 33.03 6891.95 11916.37 10840.80 -5712.42 12253.76 332.21 2.51 MWD_ IFR_ MS 285 16607.65 82.04 305.03 34.80 6896.80 11942.33 10860.3.5 -5740.79 12284.30 332.14 2.67 MWD IFR MS 286 16638.86 82.13 304.87 31.21 6901.10 11965.75 10878.06 -57.66.13 12311.80 332.07 0.58 MWD_ IFR_ MS 287 16666.32 82.50 304.78 27.46 6904.77 11986.33 10893.60 -5788.47 12336.00 332.02 1.39 MWD_ IFR_ MS 288 16702.97 82.61 305.71 36.65 6909.52 12013.99 10914.58 -5818.15 12368.46 331.94 2.53 MWD_ IFR_ MS 289 16731.87 83.14 307.10 28.90 6913.11 12036.18 10931.59 -5841.23 12394.34 331.88 5.11 MWD_ IFR_ MS 290 16763.41 83.16 306.74 31.54 6916.87 12060.:60 10950.41 -5866.27 12422.7.4 331.82 1.14 MWD IFR MS 291 16794.33 82.93 306.52 30.92 6920..61 12084.43 10968.72 -58:90.90 12450.52 331.76 1.03 MWD i IFR MS 292 16826.20 83.56 306.09 31.87 6924.36 12108.89. 10987.46 -5916.40 12479.10 331.70 2.39 _ MWD - IFR MS 293 16858.19 84.88 306.04 31.99 6927.58 12133..41 11006.19 -5942.13 12507.80 331.64 4.13 MWD_ IFR y MS 294 16889.85 86.25 307.16 31.66 6930.03 12157.91 11025.01 -5967.47 12536.41 331.57 5.58 MWD_ IFR_ MS 295 16921.49 87.04 307.81 31.64 6931.88 12182.73 11044.23 -5992.53 12565.25 331.52 3.23 MWD IFR MS 296 16953.75 87.78 306.96 32.26 6933.34 12208.01 11063.8.0 -6018.14 12594.67 331.46 3.49 MWD_ IFR_ MS 297 16983.99 88.72 307.29 30.24 6934.2.6 12231.65 11082.04 -6042.24 12622.21 331.40 3.29 MWD_ IFR_ MS 298 17012..00 89.64 307.22 28.01 6934.67 12253..5.9 11099.00 -6064.53 12647.78 331.35 3.29 MWD_ IFR_ MS 299 17050.03 89.23 307.94 38.03 6935.04 12283.51 11122.19 -6094.67 12682.59 331.28 2.18 MWD_ IFR_ MS 300 17080.74 89.72 307.98 30.71 6935.32 12307.79 11141.08 -6118.88 12710.79 331.22 1.60 MWD IFR MS [(c)2005 IDEAL ID9 1C 02] SCHLUMBERGER Survey Report 1-Jul-2005 .10:10.;12 Page 12 of 13 Seq Measured Incl Azimuth Course TVD, Vertical Displ Displ Total At DLS Srvy Tool ## depth angle angle length depth .section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) {f t) (ft) (f t) (deg) 100f) type (deg) 301 17116.90 90.09 307.22 36.16 6935.38 12336.25 11163.14 -6147.53 12743.93 331.16 2.34 MWD_ IFR _MS 302 17144.89 90.25 306.94 27.99 6935.30 12358.13 11180.02 -6169.86 12769.49 331.11 1.15 MWD_ IFR _MS 303 17176.12 90.56 306.88 31.23 6935.08 12382.47 11198.77 -6194.83 12797.98 331.05 1.01 MWD_ IFR _MS 304 17208.50 90.37 307.53 32.38 6934.81 12407.82 11218.35 -6220.62 12827.60 330.99 2.09 MWD_ IFR _MS 305 17240.72 90.07 306.34 32.22 6934.69 12432.94 11237.71 -6246.37 12857.03 330.93 3.81 MWD IFR MS 306 17276.87 89.39 306.17 36.15 6934.86 12460.86 11259.09 -6275.52 12889.89 330.87 1.94 MWD_ IFR _MS 307 17305.06 89.05 306.69 28.19 6935.25 12482.69 11275.83 -6298.20 12915.56 330.81 2.20 MWD_ IFR _MS 308 17335.79 89.51 306.44 30.73 6935.63 12506.52 11294.13 -6322.88 12943.58 330.76 1.70 MWD_ IFR _MS 309 17370.83 90.70 306.81 35.04 6935.57 12533.73 11315.04 -6351.00 12975.56 330.70 3.56 MWD_ IFR _MS 310 17402.97 91.36 307.72 32.14 6934.99 1255.8.90 11334.49 -6376.58 13005.06 330.64 3.50 MWD IFR MS 311 17429.97 91.90 307.57 27.00 6934.22 12580.16 11350.98 -6397.95 13029.90 330.59 2.08 MWD_ IFR _MS 312 17466.49 92.90 306.37 36.52 6932.69 12608.63 11372.92 -6427.10 13063.34 330.53 4.28 MWD_ IFR _MS 313 17498.04 92.93 306.11 31.55 6931.09 12632..96 11391..55 -6452.51 13092.07 330.47 0.83 MWD_ IFR _MS 314 17527.77 93.81 305.25 29.73 6929.34 12655.69 11408.86 -6476.62 13119.02 330.42 4.14 MWD_ IFR _MS 315 17562.24 94.90 305.13 34.47 6926.72 12681.82 11428.67 -6504.71 13150.12 330.35 3.18 MWD IFR MS 316 17591.14 95.02 304.93 28.90 6924.22 12703.67 11445.19 -6528.28 13176.15 330.30 0.80 MWD_ IFR _MS 317 17624.13 94.63 303.51 32.99 6921.45 12728.30 11463.68 -6555.46 13205.68 330.24 4.45 MWD_ IFR _MS 318 17658.52 94.21 303.80 34.39 6918.80 12753.76 11482.68 -6584.00 13236.35 330.17 1.48 MWD_ IFR _MS 319 17687.92 93.79 304.34 29.40 6916.75 12775.69 11499.11 -6608.30 13262.70 330.11 2.32 MWD_ IFR _MS 320 17718.78 93.34 304.34 30.86 6914.83 12798.81 11516.48 -6633.73 13290.44 330.06 1.46 MWD IFR MS 321 17751.10 92.67 302.50 32.32 6913.13 12822.69 11534.26 -6660.67 13319.30 329.99 6.05 MWD_ IFR 322 17783.52 93.04 302.15 32.42 6911.52 12846.23 11551.57 -6688.03 13347.98. 329.93 1.57 MWD_ IFR 323 17816.08 94.84 301.81 32.56 6909.28 12869.71 11568.78 -6715.58 13376.68 329.87 5.63 MWD_ IFR 324 17847.20 96.41 301.22 31.12 6906.23 12891.92 11584.96 -6741.98 13403.94 329.80 5.39 MWD_ IFR 325 17879.49 96.78 300.32 32.29 6902.52 12914.63 11601.38 -6769.54 13432.00 329.74 3.00 MWD IFR 326 17910.59 96.02 299.00 31.10 6899.06 12936.09 11616.67 -6796.40 13458.75 329.67 4.87 MWD_ IFR 327 17945.43 95.49 299.90 34.84 6895.56 12960.06 11633.71 -6826.58 13488.72. 329.60 2.99 MWD_ IFR 328 17977.58 95.51 300.01 32.15 6892.48 12982..40. 11649.69 -6854.31 13516.54 329.53 0.35 MWD_ IFR 329 18005.15 94.77 299.33 27.57 6890.01 13001.47 11663.28 -6878.17 13540.36 329.47 3.64 MWD_ IFR 330 18049.45 94.16 299.45 44.30 6886.56 13031.98 11684.96 -6916.65 13578.59 329.38 1.40 MWD IFR [(c)2005 IDEAL ID9 1C 02] • • SCHLUMBERGER Survey Report 1-Jul-2005 10:.10.:12 Page 13 of 13 Seq Measured Incl Azimuth Course TVD Vertical . Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (ft} (f t) (ft) (deg) 100f) type (deg) Projection to TD using PowerDrive* Incl ination: 331 18090.00 92.90 299.14 40.55 6884.07 13059.90 11704.76 -6951.95 13613.63 329.29 3.20 Projection [(c)2005 IDEAL ID9 1C 02] f SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Aurora Well ...................... 5-111PB1 API number ...............: 50-029-23257-70 Engineer .................. S. Moy Rig :...................... Nabors 7ES State :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 35.60 ft KB above permanent.......: 0.00 ft DF above permanent.......: 64.40 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 Vsect Origin to target: 345.69 degrees [(c)2005 IDEAL ID9_1C_01.4] 24-May-2005 16:20:58 Page 1 of 6 Spud date ................: 14-May-2005 Last survey date.........: 24-May-05 Total accepted surveys...: 131 MD of first survey.......: 0.00 ft MD of last survey........: 12210.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 14-May-2005 Magnetic field strength..: 1152.55 HCNT Magnetic dec (+E/W-).....: 24.62 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1152.53 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.62 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.62 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... ~` I=Sag Corrected Inclination. ~ M=Schlumberger Magnetic Correction S=Shell Magnetic Correction .~ ~=°~4 F=Failed Axis Correction ~- ;; R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction e~ r® C's ~' co sa' ~ ""~ o c.y-~ • SCHLUMBERGER Survey Report 24 -May-2005 16:20:58 Page 2 of 6 ` --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVDSS -------- -------- 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) ------- (f t) --------- (f t) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 1 -------- 0.00 ------ 0.00 ------- 329.00 ------ 0.00 -------- -64.40 -------- 0.00 ------- 0.00 --------- 0.00 ------- 0.00 -------- 0.00 ----- 0.00 ----- TIP ------ None 2 100.00 0.67 43.93 100.00 35.60 0.31 0.42 0.41 0.58 43.93 0.67 GYR None 3 200.00 0.73 19.31 100.00 135.59 1.15 1.44 1.02 1.77 35.30 0.30 GYR None 4 258.00 1.01 22.64 58.00 193.58 1.86 2.26 1.34 2.63 30.64 0.49 GYR None 5 349.00 1.52 17.00 91.00 284.56 3.53 4.16 2.00 4.62 25.71 0.58 GYR None 6 438.00 1.63 344.77 89.00 373.53 5.81 6.51 2.02 6.81 17.20 0.99 GYR None 7 528.00 1.80 341.86 90.00 463.49 8.50 9.09 1.24 9.17 7.76 0.21 GYR None . 8 620.00 2.55 338.43 92.00 555.42 11.97 12.36 0.04 12.36 0.17 0.83 GYR None 9 714.00 3.96 336.62 94.00 649.27 17.25 17.29 -2.02 17.41 353.33 1.50 GYR None 10 808.00 4.97 332.16 94.00 742.98 24.41 23.87 -5.21 24.43 347.69 1.14 GYR None it 904.00 7.85 326.42 96.00 838.37 34.65 33.01 -10.78 34.72 341.91 3.07 GYR None 12 1028.00 10.36 328.63 124.00 960.80 53.30 49.59 -21.27 53.95 336.78 2.04 GYR None 13 1090.00 11.79 331.47 62.00 1021.65 64.77 59.91 -27.20 65.79 335.58 2.47 GYR None 14 1180.00 13.86 334.14 90.00 1109.40 84.25 77.69 -36.29 85.75 334.96 2.39 GYR None 15 1280.00 15.33 335.85 100.00 1206.17 109.01 100.53 -46.92 110.94 334.98 1.53 GYR None 16 1404.53 19.54 334.81 124.53 1324.95 145.70 134.41 -62.53 148.25 335.05 3.39 MWD_IFR _MSA 17 1499.49 25.21 331.98 94.96 1412.73 180.97 166.66 -78.80 184.36 334.69 6.08 MWD_IFR _MSA 18 1593.68 26.54 331.78 94.19 1497.47 220.89 202.92 -98.18 225.42 334.18 1.42 MWD_IFR _MSA 19 1687.93 30.86 329.24 94.25 1580.13 264.53 242.26 -120.51 270.58 333.55 4.76 MWD_IFR _MSA 20 1781.40 36.16 329.01 93.47 1658.03 313.97 286.53 -146.99 322.03 332.84 5.67 MWD IFR MSA 21 1876.90 39.00 329.27 95.50 1733.71 369.80 336.53 -176.85 380.17 332.28 2.98 MWD_IFR _MSA 22 1967.35 41.91 330.08 90.45 1802.53 426.20 387.18 -206.47 438.80 331.93 3.27 MWD_IFR _MSA 23 2061.33 42.94 329.92 93.98 1871.90 487.24 442.09 -238.17 502.17 331.69 1.10 MWD_IFR _MSA 24 2154.74 47.00 328.55 93.41 1937.97 550.53 498.79 -271.96 5.68.11 331.40 4.47 MWD_IFR _MSA 25 2248.34 50.22 328.08 93.60 1999.85 617.54 558.53 -308.84 638.23 331.06 3.46 MWD IFR MSA 26 2344.78 53.50 332.75 96.44 2059.42 690.68 624.48 -346.21 714.03 331.00 5.10 MWD_IFR _MSA 27 2438.24 54.72 336.67 93.46 2114.22 764.99 692.93 -378.52 789.58 331.35 3.64 MWD_IFR _MSA 28 2532.07 53.92 340.20 93.83 2168.96 840.57 763.79 -406.54 865.24 331.98 3.17 MWD_IFR _MSA 29 2627.85 53.32 343.35 95.78 2225.78 917.49 837.01 -430.66 941.31 332.77 2.72 MWD IFR MSA 30 2723.01 55.08 348.05 95.16 2281.47 994.63 911.77 -449.68 1016.63 333.75 _ _ A ~ „~ ,. [ (c) 2005 IDEAL ID9 0 1C 1.4] _ _ ~o~n~~ ~~~ .~ ,, 0 ~rii <., SCHLUMBERGER Survey Report 24-May-2005 16:20:58 Page 3 of 6 Seq Measured Incl Azimuth Course TVDSS Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2816.27 55.41 349.56 93.26 2334.63 1071.13 986.93 -464.55 1090.80 334.79 1.38 MWD _IFR _MSA 32 2910.74 57.46 349.87 94.47 2386.86 1149.65 1064.38 -478.60 1167.04 335.79 2.19 MWD _IFR _MSA 33 3004.77 58.15 350.29 94.03 2436.96 1228.99 1142.76 -492.31 1244.30 336.69 0.83 MWD _IFR _MSA 34 3099.37 60.20 349.47 94.60 2485.43 1310.01 1222.73 -506.59 1323.52 337.50 2.29 MWD _IFR _MSA 35 3195.33 59.70 350.00 95.96 2533.48 1392.86 1304.46 -521.39 1404.80 338.21 0.71 MWD IFR MSA 36 3286.94 59.77 349.98 91.61 2579.66 1471.76 1382.38 -535.15 1482.35 338.84 0.08 MWD_ IFR _MSA 37 3381.89 59.51 349.92 94.95 2627.65 1553.46 1463.05 -549.44 1562.82 339.42 0.28 MWD_ IFR _MSA 38 3476.60 58.94 350.39 94.71 2676.11 1634.59 1543.23 -563.36 1642.84 339.95 0.74 MWD_ IFR _MSA 39 3570.82 58.07 350.35 94.22 2725.33 1714.66 1622.43 -576.80 1721.91 340.43 0.92 MWD_ IFR _MSA 40 3665.03 59.50 349.04 94.21 2774.15 1795.03 1701.70 -591.22 1801.48 340.84 1.93 MWD IFR MSA 41 3761.05 60.62 348.99 96.02 2822.08 1878.10 1783.38 -607.07 1883.87 341.20 1.17 MWD_ IFR _MSA 42 3853.78 60.25 349.28 92.73 2867.83 1958.61 1862.59 -622.28 1963.79 341.53 0.48 MWD_ IFR _MSA 43 3949.40 61.11 348.18 95.62 2914.65 2041.86 1944.35 -638.57 2046.53 341.82 1.35 MWD_ IFR _MSA 44 4043.33 61.12 348.18 93.93 2960.03 2124.02 2024.85 -655.42 2128.28 342.06 0.01 MWD_ IFR _MSA 45 4136.88 61.67 347.99 93.55 3004.82 2206.08 2105.21 -672.38 2209.98 342.29 0.61 MWD IFR MSA 46 4231.68 60.80 347.89 94.80 3050.44 2289.12 2186.48 -689.74 2292.69 342.49 0.92 MWD IFR MSA 47 4325.59 60.31 347.72 93.91 3096.60 2370.84 2266.41 -707.01 2374.13 342.67 0.55 MWD_ IFR _MSA 48 4419.39 60.14 348.19 93.80 3143.18 2452.20 2346.04 -724.00 2455.21 342.85 0.47 MWD_ IFR _MSA 49 4512.55 60.46 348.67 93.16 3189.34 2533.02 2425.31 -740.23 2535.76 343.03 0.56 MWD_ IFR _MSA 50 4606.34 61.13 349.24 93.79 3235.10 2614.76 2505.66 -755.92 2617.20 343.21 0.89 MWD IFR MSA 51 4652.01 61.49 349.24 45.67 3257.03 2654.74 2545.02 -763.39 2657.05 343.30 0.79 MWD_ IFR _MSA 52 4773.91 60.57 350.51 121.90 3316.07 2761.10 2650.00 -782.15 2763.02 343.56 1.18 MWD_ IFR_ MSA 53 4868.80 60.52 350.63 94.89 3362.73 2843.43 2731.51 -795.68 2845.04 343.76 0.12 MWD_ IFR _MSA 54 4962.75 60.46 350.82 93.95 3409.01 2924.87 2812.20 -808.86 2926.22 343.95 0.19 MWD_ IFR_ MSA 55 5057.85 60.05 350.95 95.10 3456.19 3007.11 2893.73 -821.94 3008.20 344.14 0.45 MWD IFR MSA 56 5150.46 60.08 351.71 92.61 3502.41 3086.97 2973.07 -834.04 3087.84 344.33 0.71 MWD_ IFR_ MSA 57 5244.62 59.67 352.63 94.16 3549.66 3167.89 3053.75 -845.14 3168.54 344.53 0.95 MWD_ IFR_ MSA 58 5340.69 58.56 354.01 96.07 3598.98 3249.60 3135.63 -854.73 3250.04 344.75 1.69 MWD_ IFR_ MSA 59 5435.12 57.74 354.66 94.43 3648.81 3328.90 3215.45 -862.65 3329.16 344.98 1.05 MWD_ IFR_ MSA 60 5529.14 57.06 355.64 94.02 3699.47 3407.03 3294.37 -869.35 3407.15 345.22 1.14 MWD IFR MSA [(c)2005 IDEAL ID9_1C_01.4] ~~~ ~_. ~t~;T~rn?f~Si • • SCHLUMBERGER Survey Report 24- May-2005 16:20:58 Page 4 of 6 Seq Measured Incl Azimuth Course TVDSS 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) 61 5624.51 57.71 355.22 95.37 3750.87 3486.21 3374.45 -875.75 3486.24 345.45 0.78 MWD _IFR _MSA 62 5718.42 59.59 355.67 93.91 3799.73 3565.24 3454.39 -882.12 3565.24 345.68 2.04 MWD _IFR _MSA 63 5813.42 60.12 355.51 95.00 3847.43 3646.17 3536.30 -888.44 3646.19 345.90 0.58 MWD _IFR _MSA 64 5906.13 60.10 353.85 92.71 3893.64 3725.56 3616.33 -895.89 3725.65 346.09 1.55 MWD _IFR _MSA 65 6000.52 60.14 352.35 94.39 3940.66 3806.71 3697.57 -905.72 3806.89 346.24 1.38 MWD IFR MSA 66 6096.27 59.39 351.94 95.75 3988.88 3888.91 3779.52 -917.02 3889.18 346.36 0.87 MWD _IFR _MSA 67 6189.94 59.29 351.81 93.67 4036.64 3969.02 3859.29 -928.41 3969.39 346.47 0.16 MWD - IFR - MSA • 68 6285.89 59.51 352.35 95.95 4085.49 4051.09 3941.09 -939.79 4051.59 346.59 0.54 MWD _IFR _MSA 69 6379.85 59.65 352.23 93.96 4133.06 4131.58 4021.38 -950.66 4132.22 346.70 0.19 MWD _IFR _MSA 70 6474.84 59.88 352.18 94.99 4180.89 4213.12 4102.69 -961.79 4213.92 346.81 0.25 MWD IFR MSA 71 6570.13 60.12 352.54 95.29 4228.54 4295.08 4184.48 -972.76 4296.06 346.91 0.41 MWD _IFR _MSA 72 6663.31 60.43 352.19 93.18 4274.74 4375.45 4264.68 -983.52 4376.62 347.01 0.47 MWD _IFR _MSA 73 6758.68 60.21 351.64 95.37 4321.96 4457.82 4346.72 -995.17 4459.18 347.10 0.55 MWD _IFR _MSA 74 6852.70 59.78 351.42 94.02 4368.98 4538.82 4427.25 -1007.16 4540.36 347.18 0.50 MWD _IFR _MSA 75 6946.12 59.23 350.37 93.42 4416.39 4618.98 4506.73 -1019.90 4620.69 347.25 1.13 MWD IFR MSA 76 7041.39 59.07 350.13 95.27 4465.24 4700.51 4587.34 -1033.75 4702.37 347.30 0.27 MWD IFR ~ _MSA 77 7137.02 58.82 350.90 95.63 4514.57 4782.15 4668.14 -1047.25 4784.17 347.36 0.74 MWD IFR ^ MSA 78 7232.52 58.32 350.82 95.50 4564.37 4863.30 4748.59 -1060.19 4865.51 347.41 0.53 MWD IFR + MSA 79 7326.67 58.30 351.04 94.15 4613.83 4943.08 4827.70 -1072.82 4945.47 347.47 0.20 MWD _IFR _MSA 80 7419.55 58.46 351.71 92.88 4662.53 5021.78 4905.90 -1084.68 5024.38 347.53 0.64 MWD IFR MSA 81 7514.82 58.46 351.69 95.27 4712.36 5102.53 4986.25 -1096.40 5105.36 347.60 0.02 MWD_ IFR _MSA . 82 7609.96 58.71 352.08 95.14 4761.95 5183.25 5066.63 -1107.86 5186.33 347.67 0.44 MWD ~ IFR _MSA 83 7703.91 59.14 352.73 93.95 4810.45 5263.17 5146.39 -1118.50 5266.53 347.74 0.75 MWD IFR MSA 84 7798.23 59.15 353.33 94.32 4858.82 5343.47 5226.76 -1128.32 5347.16 347.82 0.55 MWD_ IFR _MSA 85 7894.94 58.72 352.47 96.71 4908.73 5425.66 5308.96 -1138.56 5429.68 347.90 0.88 MWD IFR MSA 86 7990.23 58.56 352.46 95.29 4958.32 5506.46 5359.63 -1149.23 5510.79 347.96 0.17 MWD_ IFR _MSA 87 8085.44 58.48 352.72 95.21 5008.03 5587.07 5470.15 -1159.70 5591.73 348.03 0.25 MWD ~ IFR _MSA 88 8181.11 58.59 353.06 95.67 5057.97 5668.03 5551.12 -1169.81 5673.04 348.10 0.32 MWD IFR MSA 89 8276.38 58.45 352.70 95.27 5107.72 5748.64 5631.74 -1179.89 5754.01 348.17 0.35 MWD_ IFR _MSA 90 8370.59 57.98 351.87 94.21 5157.35 5828.19 5711.10 -1190.64 5833.89 348.22 0.90 MWD IFR MSA _ ;--ti -~ e ~r~4~ ~ ~ ~ ~ ~ ~UU~~ [(c)2 005 IDEAL ID9 1C 01.4] -;~ ~~~ SCHLUMBERGER Survey Report 24-May-2005 16:20:58 Page 5 of 6 Seq Measured Incl Azimuth Course TVDSS 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) --------- (f t) ------- (deg) -------- 100f) ----- type ----- (deg) ------ --- 91 -------- 8464.52 ------ 58.03 ------- 352.19 ------ 93.93 -------- 5207.11 -------- 5907.36 ------- 5789.99 --------- -1201.68 ------- 5913.38 -------- 348.28 ----- 0.29 -- MWD --- _IFR ------ _MSA 92 8558.10 57.86 351.12 93.58 5256.78 5986.24 5868.46 -1213.19 5992.55 348.32 0.99 MWD _IFR _MSA 93 8652.36 57.77 352.45 94.26 5307.00 6065.56 5947.41 -1224.59 6072.18 348.37 1.20 MWD _IFR _MSA 94 8747.42 58.33 352.16 95.06 5357.31 6145.68 6027.34 -1235.39 6152.64 348.42 0.65 MWD _IFR _MSA 95 8841.28 59.20 352.21 93.86 5405.98 6225.42 6106.85 -1246.30 6232.73 348.47 0.93 MWD IFR MSA 96 8937.02 _60.26 351.95 95.74 5454.24 6307.59 6188.74 -1257.70 6315.25 348.51 1.13 MWD_ IFR _MSA 97 9030.86 60.17 351.67 93.84 5500.85 6388.57 6269.36 -1269.30 6396.56 348.55 0.28 MWD_ IFR _MSA 98 9126.25 59.99 351.70 95.39 5548.43 6470.79 6351.16 -1281.26 6479.11 348.59 0.19 MWD_ IFR _MSA 99 9221.66 59.83 351.33 95.41 5596.27 6552.92 6432.81 -1293.44 6561.56 348.63 0.38 MWD_ IFR _MSA 100 9315.42 59.56 351.28 93.76 5643.58 6633.48 6512.83 -1305.67 6642.42 348.66 0.29 MWD IFR MSA 101 9409.72 59.66 351.54 94.30 5691.28 6714.41 6593.26 -1317.82 6723.67 348.70 0.26 MWD_ IFR _MSA 102 9504.00 59.63 351.61 94.28 5738.93 6795.34 6673.74 -1329.74 6804.93 348.73 0.07 MWD_ IFR _MSA 103 9598.44 59.89 352.19 94.44 5786.49 6876.45 6754.51 -1341.24 6886.39 348.77 0.60 MWD_ IFR _MSA 104 9691.65 59.80 352.11 93.21 5833.31 6956.53 6834.35 -1352.25 6966.85 348.81 0.12 MWD_ IFR _MSA 105 9785.13 59.71 352.96 93.48 5880.40 7036.71 6914.42 -1362.74 7047.43 348.85 0.79 MWD IFR MSA 106 9877.65 59.31 352.79 92.52 5927.34 7115.81 6993.53 -1372.63 7126.96 348.90 0.46 MWD_ IFR _MSA 107 9972.07 58.61 352.96 94.42 5976.03 7196.08 7073.81 -1382.66 7207.67 348.94. 0.76 MWD_ IFR _MSA 108 10066.96 58.44 353.70 94.89 6025.58 7276.29 7154.19 -1392.06 7288.36 348.99 0.69 MWD_ IFR _MSA 109 10160.49 57.98 354.15 93.53 6074.85 7354.96 7233.24 -1400.48 7367.57 349.04 0.64 MWD_ IFR _MSA 110 10253.87 58.08 354.88 93.38 6124.29 7433.24 7312.09 -1408.05 7446.43 349.10 0.67 MWD IFR MSA 111 10349.49 58.38 355.74 95.62 6174.64 7513.39 7393.11 -1414.69 7527.25 349.17 0.83 MWD_ IFR_ MSA 112 10444.31 58.31 355.62 94.82 6224.40 7592.88 7473.60 -1420.77 7607.45 349.24 0.13 MWD_ IFR_ MSA 113 10538.49 58.10 355.99 94.18 6274.02 7671.68 7553.43 -1426.63 7686.97 349.30. 0.40 MWD_ IFR_ MSA 114 10632.35 58.00 356.19 93.86 6323.69 7750.02 7632.88 -1432.06 7766.06 349.37 0.21 MWD_ IFR_ MSA 115 10726.50 58.17 356.30 94.15 6373.46 7828.58 7712.63 -1437.29 7845.41 349.44 0.21 MWD IFR MSA 116 10821.23 58.54 356.07 94.73 6423.16 7907.88 7793.10 -1442.66 7925.50 349.51 0.44 MWD_ IFR_ MSA 117 10916.86 59.27 355.82 95.63 6472.55 .7988.46 7874.78 -1448.45 8006.88 349.58 0.80 MWD_ IFR_ MSA 118 11012.14 59.33 355.76 95.28 6521.20 8069.11 7956.49 -1454.47 8088.33 349.64 0.08 MWD_ IFR_ MSA 119 11106.68 59.68 353.97 94.54 6569.17 8149.53 8037.62 -1461.76 8169.46 349.69 1.67 MWD_ IFR_ MSA 120 11201.94 59.82 353.02 95.26 6617.17 8231.05 8119.37 -1471.08 8251.56 349.73 0.87 MWD IFR MSA s • [(c)2005 IDEAL ID9 1C 01.4] SCHLUMBERGER Survey Report 24-May-2005 16:20:58 Page 6 of 6 Seq Measured Incl Azimuth Course TVDSS Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degJ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (ft) (ft) (ft) (deg) 100f) type (deg) 121 11296.04 60.42 351.93 94.10 6664.04 8312.07 8200.26 -1481.77 8333.06 349.76 1.19 MWD _IFR _MSA 122 11390.27 62.80 352.27 94.23 6708.85 8394.44 8282.36 -1493.16 8415.88 349.78 2.55 MWD _IFR _MSA 123 11484.93 65.11 352.56 94.66 6750.41 8478.90 8366.66 -1504.38 8500.83 349.81 2.46 MWD IFR _MSA 124 11579.98 67.80 352.84 95.05 6788.37 8565.38 8453.09 -1515.45 8587.85 349.84 2.84 MWD _ _IFR _MSA 125 11675.30 67.32 352.39 95.32 6824.76 8652.84 8540.46 -1526.77 8675.85 349.86 0.67 MWD IFR MSA 126 11767.86 66.94 352.41 92.56 6860.73 8737.54 8624.99 -1538.05 8761.05 349.89 0.41 MWD_ IFR _MSA 127 11861.14 66.58 352.84 93.28 6897.54 8822.62 8709.99 -1549.06 8846.67 349.92 0.57 MWD_ IFR _MSA 128 11955.88 66.52 353.33 94.74 6935.24 8908.81 8796.28 -1559.52 8933.45 349.95 0.48 MWD_ IFR _MSA 129 12050.04 66.90 353.51 94.16 6972.47 8994.51 8882.19 -1569.43 9019.78 349.98 0.44 MWD_ IFR _MSA 130 12144.59 66.47 354.35 94.55 7009.89 9080.45 8968.53 -1578.61 9106.41 350.02 0.93 MWD IFR MSA Projection to TD: 131 12210.00 66.47 354.35 65.41 7036.00 9139.73 9028.21 -1584.52 9166.21 350.05 0.00 Projection [(c)2005 IDEAL ID9 1C 01.4) ~ ~~ ~ ~ ,- ~,~ ~~4~ _~ .. • SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Aurora Well ...................... S-111PB2 API number ...............: 50-029-23257-71 Engineer .................: C. Brinkman Rig :...................... Nabors 7ES State :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 35.60 ft KB above permanent.......: 0.00 ft DF above permanent.......: 64.40 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 Vsect Origin to target: 345.69 degrees [(c)2005 IDEAL ID9 1C 01.4] 10-Jun-2005 15:10:36 Page 1 of 7 Spud date ................: 14-May-2005 Last survey date.........: 06-Jun-05 Total accepted surveys...: 165 MD of first survey.......: 0.00 ft MD of last survey........: 12788.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 14-May-2005 Magnetic field strength..: 1152.55 HCNT Magnetic dec (+E/W-).....: 24.60 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1152.55 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.60 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.60 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 • • SCHL•UMBERGER Survey Report 10-Jun-2005 15:10:36 Page 2 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (f t) (ft) (ft) (ft) (f t) (deg) 100f) type (deg) 1 0.00 0.00 329.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.67 43.93 100.00 100.00 0.31 0.42 0.41 0.58 43.93 0.67 GYR None 3 200.00 0.73 19.31 100.00 199.99 1.15 1.44 1.02 1.77 35.30 0.30 GYR None 4 258.00 1.01 22.64 58.00 257.98 1.86 2.26 1.34 2.63 30.64 0.49 GYR None 5 349.00 1.52 17.00 91.00 348.96 3.53 4.16 2.00 4.62 25.71 0.58 GYR None 6 438.00 1.63 344.77 89.00 437.93 5.81 6.51 2.02 6.81 17.20 0.99 GYR None 7 528.00 1.80 341.86 90.00 527.89 8.50 9.09 1.24 9.17 7.76 0.21 GYR None 8 620.00 2.55 338.43 92.00 619.82 11.97 12.36 0.04 12.36 0.17 0.83 GYR None 9 714.00 3.96 336.62 94.00 713.67 17.25 17.29 -2.02 17.41 353.33 1.50 GYR None 10 808.00 4.97 332.16 94.00 807.38 24.41 23.87 -5.21 24.43 347.69 1.14 GYR None 11 904.00 7.85 326.42 96.00 902.77 34.65 33.01 -10.78 34.72 341.91 3.07 GYR None 12 1028.00 10.36 328.63 124.00 1025.20 53.30 49.59 -21.27 53.95 336.78 2.04 GYR None 13 1090.00 11.79 331.47 62.00 1086.05 64.77 59.91 -27.20 65.79 335.58 2.47 GYR None 14 1180.00 13.86 334.14 90.00 1173.80 84.25 77.69 -36.29 85.75 334.96 2.39 GYR None 15 1280.00 15.33 335.85 100.00 1270.57 109.01 1.00.53 -46.92 110.94 334.98 1.53 GYR None 16 1404.53 19.54 334.81 124.53 1389.35 145.70 134.41 -62.53 148.25 335.05 3.39 MWD_IFR _MS 17 1499.49 25.21 331.98 94.96 1477.13 180.97 166.66 -78.80 184.36 334.69 6.08 MWD_IFR _MS 18 1593.68 26.54 331.78 94.19 1561.87 220.89 202.92 -98.18 225.42 334.18 1.42 MWD_IFR _MS 19 1687.93 30.86 329.24 94.25 1644.53 264.53 242.26 -120.51 270.58 333.55 4.76 MWD_IFR _MS 20 1781.40 36.16 329.01 93.47 1722.43 313.97 286.53 -146.99 322.03 332.84 5.67 MWD_IFR _MS 21 1876.90 39.00 329.27 95.50 1798.11 369.80 336.53 -176.85 380.17 332.28 2.98 MWD_IFR _MS 22 .1967.35 41.91 330.08 90.45 1866.93 426.20 387.18 -206.47 438.80 331.93 3.27 MWD IFR MS 23 2061.33 42.94 329.92 93.98 1936.30 487.24 442.09 -238.17 502.17 331.69 1.10 MWD_IFR _MS 24 2154.74 47.00 328.55 93.41 2002.37 550.53 498.79 -271.96 568.11 331.40 4.47 MWD_IFR _MS 25 2248.34 50.22 328.08 93.60 2064.25 617.54 558.53 -308.84 638.23 331.06 3.46 MWD_IFR _MS 26 2344.78 53.50 332.75 96.44 2123.82 690.68 624.48 -346.21 714.03 331.00 5.10 MWD_IFR _MS 27 2438.24 54.72 336.67 93.46 2178.62 764.99 692.93 -378.52 789.58 331.35 3.64 MWD_IFR _MS 28 2532.07 53.92 340.20 93.83 2233.36 840.57 763.79 -406.54 865.24 331.98 3.17 MWD_IFR _MS 29 2627.85 53.32 343.35 95.78 2290.18 917.49 837.01 -430.66 941.31 332.77 2.72 MWD_IFR _MS 30 2723.01 55.08 348.05 95.16 2345.86 994.63 911.77 -449.68 1016.63 333.75 4.41 MWD_IFR _MS [(c)2005 IDEAL ID9 1C 01.4] SCHLUMBERGER Survey Report 10 -Jun-2005 15:10:36 Page 3 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 31 2816.27 .55.41 349.56 93.26 2399.03 1071.13 986.93 -464.55 1090.80 334.79 1.38 MWD_ IFR _MS 32 2910.74 57.46 349.87 94.47 2451.26 1149.65 1064.38 -478.60 1167.04 335.79 2.19 MWD_ IFR _MS 33 3004.77 58.15 350.29 94.03 2501.36 1228.99 1142.76 -492.31 1244.30 336.69 0.83 MWD_ IFR _MS 34 3099.37 60.20 349.47 94.60 2549.83 1310.01 1222.73 -506.59 1323.52 337.50 2.29 MWD_ IFR _MS 35 3195.33 59.70 350.00 95.96 2597.88 1392.86 1304.46 -521.39 1404.80 338.21 0.71 MWD_ IFR _MS 36 3286.94 59.77 349.98 91.61 2644.06 1471.76 1382.38 -535.15 1482.35 338.84 0.08 MWD IFR MS 37 3381.89 59.51 349.92 94.95 2692.05 1553.46 1463.05 -549.44 1562.82 339.42 0.28 _ MWD_ IFR _ _MS • 38 3476.60 58.94 350.39 94.71 2740.51 1634.59 1543.23 -563.36 1642.84 339.95 0.74 MWD_ IFR _MS 39 3570.82 58.07 350.35 94.22 2789.73 1714.66 1622.43 -576.80 1721.91 340.43 0.92 MWD_ IFR _MS 40 3665.03 59.50 349.04 94.21 2838.55 1795.03 1701.70 -591.22 1801.48 340.84 1.93 MWD_ IFR _MS 41 3761.05 60.62 348.99 96.02 2886.48 1878.10 1783.38 -607.07 1883.87 341.20 1.17 MWD_ IFR _MS 42 3853.78 60.25 349.28 92.73 2932.23 1958.61 1862.59 -622.28 1963.79 341.53 0.48 MWD_ IFR _MS 43 3949.40 61.11 348.18 95.62 2979.05 2041.86 1944.35 -638.57 2046.53 341.82 1.35 MWD_ IFR _MS 44 4043.33 61.12 348.18 93.93 3024.43 2124.02 2024.85 -655.42 2128.28 342.06 0.01 MWD_ IFR _MS 45 4136.88 61.67 347.99 93.55 3069.22 2206.08 2105.21 -672.38 2209.98 342.29 0.61 MWD_ IFR _MS 46 4231.68 60.80 347.89 94.80 3114.83 2289.12 2186.48 -689.74 2292.69 342.49 0.92 MWD_ IFR _MS 47 4325.59 60.31 347.72 93.91 3161.00 2370.84 2266.41 -707.01 2374.13 342.67 0.55 MWD_ IFR _MS 48 4419.39 60.14 348.19 93.80 3207.58 2452.20 2346.04 -724.00 2455.21 342.85 0.47 MWD_ IFR _MS 49 4512.55 60.46 348.67 93.16 3253.74 2533.02 2425.31 -740.23 2535.76 343.03 0.56 MWD_ IFR _MS 50 4606.34 61.13 349.24 93.79 3299.50 2614.76 2505.66 -755.92 2617.20 343.21 0.89 MWD_ IFR _MS 51 4652.01 61.49 349.24 45.67 3321.43 2654.74 2545.02 -763.39 2657.05 343.30 0.79 MWD_ IFR MS 52 4773.91 60.57 350.51 121.90 3380.47 2761.10 2650.00 -782.15 2763.02 343.56 1.18 MWD_ IFR - MS 53 4868.80 60.52 350.63 94.89 3427.13 2843.43 2731.51 -795.68 2845.04 343.76 0.12 MWD_ IFR _MS 54 4962.75 60.46 350.82 93.95 3473.41 2924.87 2812.20 -808.86 2926.22 343.95 0.19 MWD_ IFR _MS 55 5057.85 60.05 350.95 95.10 3520.59 3007.11 2893.73 -821.94 3008.20 344.14 0.45 MWD_ IFR _MS 56 5150.46 60.08 351.71 92.61 3566.81 3086.97 2973.07 -834.04 3087.84 344.33 0.71 MWD_ IFR _MS 57 5244.62 59.67 352.63 94.16 3614.06 3167.89 3053.75 -845.14 3168.54 344.53 0.95 MWD_ IFR _MS 58 5340.69 58.56 354.01 96.07 3663.38 3249.60 3135.63 -854.73 3250.04 344.75 1.69 MWD_ IFR _MS 59 5435.12 57.74 354.66 94.43 3713.21 3328.90 3215.45 -862.65 3329.16 344.98 1.05 MWD_ IFR _MS 60 5529.14 57.06 355.64 94.02 3763.87 3407.03 3294.37 -869.35 3407.15 345.22 1.14 MWD_ IFR _MS [(c)2005 IDEAL ID9 1C 01.4] SCA~UMBERGER Survey Report 10 -Jun-2005 15:10:36 Page 4 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (f t) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5624.51 57.71 355.22 95.37 3815.27 3486.21 3374.45 -875.75 3486.24 345.45 0.78 MWD_ IFR _MS 62 5718.42 59.59 355.67 93.91 3864.13 3565.24 3454.39 -882.12 3565.24 345.68 2.04 MWD_ IFR _MS 63 5813.42 60.12 355.51 95.00 3911.83 3646.17 3536.30 -888.44 3646.19 345.90 0.58 MWD_ IFR _MS 64 5906.13 60.10 353.85 92.71 3958.04 3725.56 3616.33 -895.89 3725.65 346.09 1.55 MWD_ IFR _MS 65 6000.52 60.14 352.35 94.39 4005.06 3806.71 3697.57 -905.72 3806.89 346.24 1.38 MWD_ IFR _MS 66 6096.27 59.39 351.94 95.75 4053.28 3888.91 3779.52 -917.02 3889.18 346.36 0.87 MWD IFR MS 67 6189.94 59.29 351.81 93.67 4101.04 3969.02 3859.29 -928.41 3969.39 346.47 0.16 _ MWD_ IFR _ _MS 68 6285.89 59.51 352.35 95.95 4149.89 4051.09 3941.09 -939.79 4051.59 346.59 0.54 MWD_ IFR _MS 69 6379.85 59.65 352.23 93.96 4197.46 4131.58 4021.38 -950.66 4132.22 346.70 0.19 MWD_ IFR _MS 70 6474.84 59.88 352.18 94.99 4245.29 4213.12 4102.69 -961.79 4213.92 346.81 0.25 MWD_ IFR _MS 71 6570.13 60.12 352.54 95.29 4292.94 4295.08 4184.48 -972.76 4296.06 346.91 0.41 MWD_ IFR _MS 72 6663.31 60.43 352.19 93.18 4339.14 4375.45 4264.68 -983.52 4376.62 347.01 0.47 MWD_ IFR _MS 73 6758.68 60.21 351.64 95.37 4386.36 4457.82 4346.72 -995.17 4459.18 347.10 0.55 MWD_ IFR _MS 74 6852.70 59.78 351.42 94.02 4433.38 4538.82 4427.25. -1007.16 4540.36 347.18 0.50 MWD_ IFR _MS 75 6946.12 59.23 350.37 93.42 4480.79 4618.98 4506.73 -1019.90 4620.69 347.25 1.13 MWD_ IFR _MS 76 7041.39 59.07 350.13 95.27 4529.64 4700.51 4587.34 -1033.75 4702.37 347.30 0.27 MWD_ IFR _MS 77 7137.02 58.82 350.90 95.63 4578.97 4782.15 4668.14 -1047.25 4784.17 347.36 0.74 MWD_ IFR _MS 78 7232.52 58.32 350.82 95.50 4628.77 4863.30 4748.59 -1060.19 4865.51 347.41 0.53 MWD_ IFR _MS 79 7326.67 58.30 351.04 94.15 4678.23 4943.08 4827.70 -1072.82 4945.47 347.47 0.20 MWD_ IFR _MS 80 7419.55 58.46 351.71 92.88 4726.93 5021.78 4905.90 -1084.68 5024.38 347.53 0.64 MWD_ IFR _MS 81 7514.82 58.46 351.69 95.27 4776.76 5102.53 4986.25 -1096.40 5105.36 347.60 0.02 MWD _ IFR MS 82 7609.96 58.71 352.08 95.14 4826.35 5183.25 5066.63 -1107.86 5186.33 347.67 0.44 _ MWD IFR - MS 83 7703.91 59.14 352.73 93.95 4874.85 5263.17 5146.39 -1118.50 5266.53 347.74 0.75 MWD_ IFR _MS 84 7798.23 59.15 353.33 94.32 4923.22 5343.47 5226.76 -1128.32 5347.16 347.82 0.55 MWD_ IFR _MS 85 7894.94 58.72 352.47 96.71 4973.13 5425.66 5308.96 -1138.56 5429.68 347.90 0.88 MWD_ IFR _MS 86 7990.23 58.56 352.46 95.29 5022.72 5506.46 5389.63 -1149.23 5510.79 347.96 0.17 MWD_ IFR _MS 87 8085.44 58.48 352.72 95.21 5072.43 5587.07 5470.15 -1159.70 5591.73 348.03 0.25 MWD_ IFR _MS 88 8181.11 58.59 353.06 95.67 5122.37 5668.03 5551.12 -1169.81 5673.04 348.10 0.32 MWD_ IFR _MS 89 8276.38 58.45 352.70 95.27 5172.12 5748.64 5631.74 -1179.89 5754.01 348.17 0.35 MWD_ IFR _MS 90 8370.59 57.98 351.87 94.21 5221.75 5828.19 5711.10 -1190.64 5833.89 348.22 0.90 MWD_ IFR _MS [(c)2005 IDEAL ID9 1C 01.4] SCH"LUMBERGER Survey Report 10-Jun-2005 15:10:36 Page 5 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (f t) (ft) (f t) (f t) (deg) 100f) type (deg) 91 8464.52 58.03 352.19 93.93 5271.51 5907.36 5789.99 -1201.68 5913.38 348.28 0.29 MWD _IFR _MS 92 8558.10 57.86 351.12 93.58 5321.18 5986.24 5868.46 -1213.19 5992.55 348.32 0.99 MWD _IFR _MS 93 8652.36 57.77 352.45 94.26 5371.40 6065.56 5947.41 -1224.59 6072.18 348.37 1.20 MWD _IFR _MS 94 8747.42 58.33 352.16 95.06 5421.71 6145.68 6027.34 -1235.39 6152.64 348.42 0.65 MWD _IFR _MS 95 8841.28 59.20 352.21 93.86 5470.38 6225.42 6106.85 -1246.30 6232.73 348.47 0.93 MWD _IFR _MS 96 8937.02 60.26 351.95 95.74 5518.64 6307.59 6188.74 -1257.70 6315.25 348.51 1.13 MWD _IFR _MS 97 9030.86 60.17 351.67 93.84 5565.25 6388.57 6269.36 -1269.30 6396.56 348.55 0.28 MWD _IFR _MS 98 9126.25 59.99 351.70 95.39 5612.83 6470.79 6351.16 -1281.26 6479.11 348.59 0.19 MWD _IFR _MS 99 9221.66 59.83 351.33 95.41 5660.67 6552.92 6432.81 -1293.44 6561.56 348.63 0.38 MWD_ IFR _MS 100 9315.42 59.56 351.28 93.76 5707.98 6633.48 6512.83 -1305.67 6642.42 348.66 0.29 MWD_ IFR _MS 101 9409.72 59.66 351.54 94.30 5755.68 6714.41 6593.26 -1317.82 6723.67 348.70 0.26 MWD_ IFR _MS 102 9504.00 59.63 351.61 94.28 5803.33 6795.34 6673.74 -1329.74 6804.93 348.73 0.07 MWD_ IFR _MS 103 9598.44 59.89 352.19 94.44 5850.89 6876.45 6754.51 -1341.24 6886.39 348.77 0.60 MWD_ IFR _MS 104 9691.65 59.80 352.11 93.21 5897.71 6956.53 6834.35 -1352.25 6966.85 348.81 0.12 MWD_ IFR _MS 105 9785.13 59.71 352.96 93.48 5944.80 7036.71 6914.42 -1362.74 7047.43 348.85 0.79 MWD_ IFR _MS 106 9877.65 59.31 352.79 92.52 5991.74 7115.81 6993.53 -1372.63 7126.96 348.90 0.46 MWD_ IFR _MS 107 9972.07 58.61 352.96 94.42 6040.43 7196.08 7073.81 -1382.66 7207.67 348.94 0.76 MWD_ IFR _MS 108 10066.96 58.44 353.70 94.89 6089.98 7276.29 7154.19 -1392.06 7288.36 348.99 0.69 MWD_ IFR _MS 109 10160.49 57.98 354.15 93.53 6139.25 7354.96 7233.24 -1400.48 7367.57 349.04 0.64 MWD_ IFR _MS 110 10253.87 58.08 354.88 93.38 6188.69 7433.24 7312.09 -1408.05 7446.43 349.10 0.67 MWD_ IFR _MS 111 10349.49 58.38 355.74 95.62 6239.04 7513.39 7393.11 -1414.69 7527.25 349.17 0.83 MWD_ IFR _MS 112 10444.31 58.31 355.62 94.82 6288.80 7592.88 7473.60 -1420.77 7607.45 349.24 0.13 MWD_ IFR _MS 113 10538.49 58.10 355.99 94.18 6338.42 7671.68 7553.43 -1426.63 7686.97 349.30 0.40 MWD_ IFR _MS 114 10632.35 58.00 356.19 93.86 6388.09 7750.02 7632.88 -1432.06 7766.06 349.37 0.21 MWD_ IFR _MS 115 10726.50 58.17 356.30 94.15 6437.86 7828.58 7712.63 -1437.29 7845.41 349.44 0.21 MWD_ IFR _MS 116 10821.23 58.54 356.07 94.73 6487.56 7907.88 7793.10 -1442.66 7925.50 349.51 0.44 MWD_ IFR _MS 117 10916.86 59.27 355.82 95.63 6536.95 7988.46 7874.78 -1448.45 8006.88 349.58 0.80 MWD_ IFR _MS 118 11012.14 59.33 355.76 95.28 6585.60 8069.11 7956.49 -1454.47 8088.33 349.64 0.08 MWD_ IFR _MS 119 11106.68 59.68 353.97 94.54 6633.57 8149.53 8037.62 -1461.76 8169.46 349.69 1.67 MWD_ IFR _MS 120 11201.94 59.82 353.02 95.26 6681.56 8231.05 8119.37 -1471.08 8251.56 349.73 0.87 MWD_ IFR _MS r~ C7 [(c)2005 IDEAL ID9 1C 01.4] SCHLUMBERGER Survey Report 10-Jun-2005 15:10:36 Page 6 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (f t) (ft) (f t) (f t) (ft) (deg) 100f) type (deg) 121 11296.04 60.42 351.93 94.10 6728.44 8312.07 8200.26 -1481.77 8333.06 349.76 1.19 MWD_ IFR_ MS 122 11390.27 62.80 352.27 94.23 6773.25 8394.44 8282.36 -1493.16 8415.88 349.78 2.55 MWD_ IFR_ MS 123 11484.93 65.11 352.56 94.66 6814.81 8478.90 8366.66 -1504.38 8500.83 349.81 2.46 MWD_ IFR_ MS 124 11536.00 66.53 352.71 51.07 6835.72 8525.15 8412.87 -1510.35 8547.37 349.82 2.79 Top_ of_Window 125 11549.00 68.28 351.50 13.00 6840.72 8537.07 8424.75 -1512.00 8559.36 349.83 15.97 Bottom of_Window 126 11562.39 67.19 351.50 13.39 6845.79 8549.40 8437.01 -1513:83 8571.75 349.83 8.14 End_ of_Mill 127 11573.96 67.11 350.90 11.57 6850.28 8560.01 8447.55 -1515.47 8582.40 349.83 4.83 MWD ~ Incl _Only 128 11602.82 68.23 349.44 28.86 6861.25 8586.63 8473.85 -1520.02 8609.10 349.83 6.08 MWD Incl Only 129 11635.27 70.31 347.82 32.45 6872.74 8616.93 8503.60 -1526.01 8639.44 349.83 7.93 MWD_ Incl _Only 130 11666.52 71.82 346.29 31.25 6882.88 8646.48 8532.40 -1532.63 8668.96 349.82 6.69 MWD_ Incl _Only 131 11698.65 73.09 344.75 32.13 6892.56 8677.12 8562.06 -1540.29 8699.51 349.80 6.04 MWD_ Incl _Only 132 11730.59 74.94 343.24 31.94 6901.36 8707.81 8591.58 -1548.76 8730.05 349.78 7.36 MWD_ Incl _Only 133 11767.70 76.84 338.44 37.11 6910.41 8743.65 8625.56 -1560.57 8765.59 349.74 13.55 MWD_ IFR_ MS 134 11793.51 77.93 335.49 25.81 6916.05 8768.54 8648.73 -1570.43 8790.16 349.71 11.93 MWD_ IFR_ MS 135 11826.51 78.93 334.42 33.00 6922.67 8800.31 8678.02 -1584.12 8821.42 349.65 4.39 MWD_ IFR_ MS 136 11864.17 80.40 332.93 37.66 6929.42 8836.54 8711.23 -1600.55 8857.04 349.59 5.51 MWD_ IFR_ MS 137 11896.84 81.44 329.50 32.67 6934.58 8867.77 8739.50 -1616.08 8887.66 349.52 10.84 MWD_ IFR_ MS 138 11929.57 82.13 325.87 32.73 6939.26 8898.58 8766.87 -1633.39 8917.73 349.45 11.18 MWD_ IFR_ MS 139 11960.66 83.76 323.84 31.09 6943.08 8927.41 8792.09 -1651.15 8945.79 349.36 8.34 MWD_ IFR_ MS 140 11995.68 85.62 318.85 35.02 6946.32 8959.17 8819.31 -1672.93 8976.58 349.26 15.15 MWD_ IFR_ MS 141 12023.87 86.85 315.59 28.19 6948.17 8983.89 8839.96 -1692.03 9000.43 349.16 12.34 MWD_ IFR_ MS 142 12055.47 88.40 312.37 31.60 6949.48 9010.74 8861.88 -1714.75 9026.25 349.05 11.30 MWD ~ IFR_ MS 143 12090.46 90.42 307.82 34.99 6949.84 9039.19 8884.40 -1741.50 9053.48 348.91 14.23 MWD I IFR_ MS 144 12120.04 91.86 305.38 29.58 6949.25 9062.14 8902.03 -1765.24 9075.37 348.78 9.58 MWD IFR_ MS 145 12151.15 92.61 301.71 31.11 6948.04 9085.18 8919.21 -1791.15 9097.28 348.64 12.06 MWD_ IFR_ MS 146 12183.47 94.09 298.08 32.32 6946.15 9107.67 8935.28 -1819.12 9118.58 348.49 12.08 MWD_ IFR_ MS 147 12216.97 96.40 294.87 33.50 6943.09 9129.46 8950.15 -1848.97 9139.14 348.33 11.77 MWD_ IFR_ MS 148 12234.31 97.26 293.33 17.34 6941.02 9140.16 8957,18 -1864.69 9149.22 348.24 10.12 MWD_ IFR_ MS 149 12269.82 97.58 291.35 35.51 6936.44 9161.17 8970.57 -1897.26 9169.00 348.06 5.60 MWD_ Incl _Only 150 12302.84 97.29 289.51 33.02 6932.17 9179.83 8982.00 '1927.94 9186.58 347.89 5.59 MWD_ IFR_ MS [(c)2005 IDEAL ID9 1C 01.4] SGHf,UMBERGER Survey Report 10-Jun-2005 15:10:36 Page 7 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degJ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 151 12335.54 97.13 289.30 32.70 6928.06 9197.84 8992.77 -1958.53 9203.58 347.71 0.80 MWD_ IFR _MS 152 12365.23 96.85 289.11 29.69 6924.45 9214.11 9002.47 -1986.36 9219.01 347.56 1.14 MWD_ IFR _MS 153 12398.64 96.55 289.39 33.41 6920.55 9232.45 9013.41 -2017.69 9236.48 347.38 1.22 MWD_ IFR _MS 154 12430.43 96.82 288.48 31.79 6916.85 9249.76 9023.65 -2047.56 9253.04 347.22 2.97 MWD_ IFR _MS 155 12462.82 97.16 287.55 32.39 6912.91 9266.95 9033.59 -2078.13 9269.54 347.04 3.04 MWD_ Inc l_Only 156 12494.47 97.68 286.16 31.65 6908.82 9283.19 9042.69 -2108.16 9285.19 346.88 4.65 MWD_ IFR _MS 157 12526.43 98.15 289..12 31.96 6904.42 9299.94 9052.29 -2138.33 9301.41 346.71 9.29 MWD_ IFR _MS 158 12558.70 98.57 286.81 32.27 6899.73 9316.99 9062.13 -2168.70 9318.02 346.54 7.20 MWD_ IFR _MS 159 12590.39 98.81 283.29 31.69 6594.94 9332.35 9070.27 -2198.94 9333.01 346.37 11.01 MWD_ IFR _MS 160 12622.52 98.04 284.06 32.13 6890.23 9347.26 9077.78 -2229.82 9347.63 346.20 3.37 MWD_ Inc l_Only 161 12654.21 95.67 284.10 31.69 6886.45 9362.22 9085.43 -2260.34 9362.38 346.03 7.48 MWD_ Incl_Only 162 12686.11 92.49 285.70 31.90 6884.18 9377.75 9093.62 -2291.08 9377.79 345.86 11.15 MWD_ IFR _MS 163 12718.30 88.60 285.45 32.19 6883.87 9393.78 9102.26 -2322.08 9393.78 345.69 12.11 MWD_ IFR _MS 164 12750.22 87.98 285.32 31.92 6884.82 9409.59 9110.72 -2352.85 9409.63 345.52 1.98 MWD_ IFR _MS Proje ction to TD: 165 12788.00 87.98 285.32 37.78 6886.16 9428.25 9120.70 -2389.26 9428.45 345.32 0.00 Projection [(c)2005 IDEAL ID9 1C 01.4] • C7 • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc. S-111 Nabors 7ES Dispatched To: Date Dispatched: Dispatched By: Helen Warman (A06CC) 8-Jul-05 Mauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James FI. Johnson Received By: ~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center(LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@b .com LWU Log Uehvery V1.1, 1U-UZ-U3 ~~~~' ~~ ~ ~ ~ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. pispatched To: Helen Warman (AOGCC) We{{ No S-111PB1 Date Dispatched: 6-Jun-05 Installation/Rig Nabors 7ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1, 10-02-03 Data No Of Prints No of Floppies Surveys 2 1 ' Please sign and return to: James H. Johnson ~ Received By: ~ rw BP Exploration (Alaska) Inc. Petrotechnical Data Lerner (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~bp.com • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman (A06CC) Well No S-111PB2 Date Dispatched: 20-Jun-05 Installation/Rig Nabors 7ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1, 10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Jonnson Received By: ~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh®bp.com ~~J -~~`I ~~~® ~~ ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 7131461-0920 SURVEY REPORT BP S-PAD #S-111 NABORS #7ES NORTH SLOPE, AK AK0505G_548 MAY 17, 2005 C~OC~~ ~ cis- o~ Serving the Worldwide Energy Industry with Precision Survey Instrumentation • ~~~® ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 May 26, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. 900 E. Benson Blvd. Anchorage, Alaska 99508 Re: S-Pad, Well #S-111 North Slope, Alaska Enclosed, please find one (1) original, two (2) copies, and two (Z) discs of the completed survey of the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~~~~ _. Rob Shoup North American Operations Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directi onal Survey for B.P. EXPLORATION (ALASKA) INC. Lease: S-Pad Well: 5-111, • Location: Nabors #7ES, North Slope, Alaska Job Number: AKOSOSG 548 Run Date: 17 May 2005 Surveyor: Robert Williams; Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.359920 deg. N Longitude: 149.035790 deg. W Azimuth Correction: • Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location B.P. Exploration (Alaska) Inc. Lease: S-Pad Well: S-111 Location: Nabors #7ES, North Slope, Alaska Job Number: AKOSOSG 548 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 100 ft. VERTICAL CLOSURE DEPTH DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet -------- 0.00------------0 -oo ----------- 0.00 ---------- N --- 0 0 E ---------------0 -00 ----- ---------- 0-00--------------- 0-0 ----- O 0-------------- 0.00 N------------0 -00- E - • 0 - 1280 FT. RATE GYROSCOPIC MULTISHOT AND MOTOR ORIENTATION ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #7ES R.K.B. OF 64.4 FT. -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 100.00 0.67 43.93 N 43 56 E 0.67 100.00 0.6 43.9 0.42 N 0.41 E 200.00 0.73 19.31 N 19 18 E 0.30 199.99 1.8 35.3 1.44 N 1.02 E 258.00 1.01 22.64 N 22 38 E 0.49 257.98 2.6 30.6 2.26 N 1.34 E 349.00 1.52 17.00 N 17 0 E 0.58 348.96 4.6 25.7 4.15 N 2.00 E 438.00 1.63 344.77 N 15 14 W 0.99 437.93 6.8 17.2 6.51 N 2.01 E 528.00 1.80 341.86 N 18 8 W 0.21 527.89 9.2 7.7 9.09 N 1.24 E 620.00 2.55 338.43 N 21 34 W 0.82 619.82 12.4 0.2 12.36 N 0.03 E 714.00 3.96 336.62 N 23 23 W 1.50 713.67 17.4 353.3 17.29 N 2.02 W 808.00 4.97 332.16 N 27 51 W 1.14 807.38 24.4 347.7 23.87 N 5.21 W 904.00 7.85 326.43 N 33 34 W 3.07 902.77 34.7 341.9 33.01 N 10.78 W 1028.00 10.36 328.63 N 31 22 W 2.04 1025.20 54.0 336.8 49.59 N 21.28 W 1090.00 11.79 331.47 N 28 32 W 2.47 1086.04 65.8 335.6 59.92 N 27.20 W 1180.00 13.86 334.14 N 25 52 W 2.39 1173.79 85.8 335.0 77.70 N 36.30 W 1280.00 15.33 335.85 N 24 9 W 1.53 1270.56 111.0 335.0 100.54 N 46.93 W Final Station Closure: Distance: 110.96 ft Az: 334.98 deg. 2 B.P. Exploratio-n (Alaska) Inc. Well: S-Pad S-111 Location: Nabors #7ES, North Slope, Alaska 100 90 80 70 .. 60 ~_ c~ z 50 O Z 40 30 20 10 o- Outrun Gyrodata .. nkn~n~r; SdR f1FFTnITTT\/G - - BOTTO HOLE ~ - E MD: 12 - 0.00 ~ I - - ----- ~ I '- , --- - ~ ~~- i ~ -- I -- _ j ! ~ i ~ I I - ------ ---- -- ----- ~ ' --- ~ - ~ 4- i -- ~ ~ i I -- ~, ' - I I ~ ~ '~ ~ ~ ' ~ ~ I ~ ~_ _ ~ i ~ i . -- ------ i ~ i i _ ~ ~ ~ - ~j ~ I ~ • ~ ~ ~ ~ ~ -45 -40 -35 -30 -25 -20 -15 -10 -5 0 FASTING (ft) B.P. Exploration (Alaska) Inc. Well: S-Pad S-111 Location: Nabors #7ES, North Slope, Alaska 9- 8- 7- ~ 6 0 0 °' S - w ~ 4 - w C7 w J O 3 - 2- 1- 0- Outrun Gyrodata AK0505G_548 DEFINITIVE I J ~ - I i -t ---- _ I _ __ ~ ~ -------I- -----~ I I -----~ ~ ~ I - -- , ' ~ I--- -- I -- ------ ----- _ i - ~ - ~------~' ~ !~ ------ , j I F- --- I i ~ ~ ~ ~ ~ ~ ~---{ I i ~ -- --1 ----. _ i I ~ I III ! i ~ ~ ~. - I i ~ i -------j ----' i -------~ I~ ---- -- ~ I -- - ~ i ` I -} - - - - _ ~ ~ ~ i ~ ~ i ~ _ ~~ ~ B _ LO M OM H ATED ~ :1280. LE _ _ 0 -- i ~ ,\ ~~ ,,\ , ' ~~ I ~ i I i I I i i i i i i i i i 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 MEASURED DEPTH (ft) • • B.P. Exptoratior~ (Alaska) Inc. Well: S-Pad S-111 Location: Nabors #7ES, North Slope, Alaska 15.0 - 12.5 - 10.0 z 0 Q z v 7.5 - z 5.0 2.5 - 0.0 - - Outrun Gyrodata , . AK0505G 548 DEFINITIVE " I ----- - ~~- - - ~--B~TfOI~II~~LE - LOCATED - ~ i ~%~ MD: 1280.00 i ! ~ f I i _ ~ - ~I I ~, _ ~ i . - - - ~ %' ' - ---_____-t---- _- --~ t'" V ~ > > 250 500 750 1000 MEASURED DEPTH (ft) i 1250 • N Q B.P. Exploration (Alaska) Inc. Well: S-Pad S-111 Location: Nabors #7ES, North Slope, Alaska 40.0 20.0 - 0.0 - 340.0 - ' Outrun Gyrodata AK0505G_548 DEFINITIVE i ~ -~ ~ ! ~ ~ ~ I ~ j ~ ~ -~_ ___~.__ ~~ i ~ ~.~ I y--._-_._,_ i I j i I ~ ~ _. i ~_ i I - -- ' - ~~ ~ i '__ ~,.. ~ _ _~ ~ _ -~ ,,t ~ ~ HOLE OM ~ ~ '~ ~~ ~ D OC ~. ~~ MD: 1280.00 _- ,_ i i i 250 500 750 1000 MEASURED DEPTH (ft) 1250 1 • • i 2os-os~ w Subject: Re: S-111 i From: `Winton Aubert <Winton__aubert~adminatate.ak.us> Date: Man, 25 Apr 2005 15:01:22 -0800 To: "Wesley, Dave E" <WesleyDE@BP.com> Dave, Thanks, I'll make this change in our records. Winton Wesley, Dave E wrote: Winton, We've been reviewing the mud program for S-111 i. I was quite conservative in the mud weights chosen for the intermediate 9 7/8" interval. Specifically, I had planned to displace to a 9.8ppg LSND prior to drilling out the surface shoe, and weighting up to 11.0 prior to drilling the HRZ. In considering that this well is to the western part of the field, where the shales are not as problematic, and based upon the fact there have been numerous wells on S-pad which have drilled the HRZ with lesser mud weight, I'd like to revise my plan. I would like to displace to an 8.8ppg to 9.Oppg LSND at the surface shoe, which is consistent with our recent operations in this part of the field. At the top of the HRZ, we'd weight up to 10.5ppg, which is the recommended minimum mud weight to control the HRZ at the planned inclination and azimuth, based upon the Polar plot used in determining adequate mud weight for the shale. Is this revision acceptable? Thanks and regards, Dave Dave Wesley, Jr. GPB Operations Drilling Engineer 564-5153 office 440-8631 cell ~ • ,~ FRANK H. MURKOWSK/, GOVERNOR Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay S-111 i BP Exploration (Alaska) Inc. Permit No: 205-051 Surface Location: 4527 NSL, 4497' WEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 367' NSL, 918' WEL, SEC. 16, T12N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and inject is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska) Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. ease provide at least twenty-four (24) hours notice for a representative of the Commissio o witness any required test. Contact the Commission's petroleum field inspector 07) 5 36 7 (pager). 6~ DATED this day of April, 2005 J~ K. cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. a °; _ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION~MMISSION PERMIT TO DRILL 20 AAC 25.005 W U~- 3/ ~ t j 2,05 R~~EIYEQ _ ~nnC 1 a. Type of work ®Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development ip a one ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zo e 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. V1~~ PBl~6~l~ga9e ~3oS 3. Address: P,O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 18033 TVD 6895 12. Field /Pool(s): Prudhoe Bay Field /Aurora Pool 4a. Location of Well (Governmental Section): Surface: 4527' NSL 4497' WEL SEC 35 T12N R12E UM 7. Property Designation: ADL 028256 , , . , , , Top of Productive Horizon: 2483' NSL, 751' WEL, SEC. 22, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2005 Total Depth: 367' NSL, 918' W EL, SEC. 16, T12N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: rnis we0 crosses th PA nd PBU Boundry 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 - 5980730 Zone- ASP4 10. KB Elevation Planned (Height above GL): 64.1' feet 15. Distance to Nearest Well Wit in Pool S-102L1 is 1366 away at 15800' MD 16. Deviated Wells: Kickoff Depth: 400 feet Maximum Hole Angle: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3075 Surface: 2395 ~ 18. asing rogram: Size ' Specifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# H-40 Weld 80' Surtace Surtace 110' 110' 60 sx Arctic Set A rox. 13-1/2" 10-3/4" 45.5# L-80 BTC-M 4660' Surface Surface 4660' 3339' 63 sx AS Lite, 443 sx Class 'G' ~ 9-7/8" 7-5/8" 29.7# L-80 BTC-M 12255' Surface Surface 12255' 7146' 08 sx LiteCrete, 322 sx Class 'G' ~ 6-3/4" 4-1/2" 12.6# L-80 H dri1521 6559' 11474' 6816' 18033' 6895' sxClass'G', ! C t B tnt~/~ 19. PRESENT-WELL CONDITION SUMMARY (To be completed forAedrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casin Len th Size Cement Volume MD TVD r n r I r tion Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Flling Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Robert Tirpack Title Senior Drilling Engineer Phil mith, 564-4897 Prepared By Name/Number. Si nature ~' l y ~t~'"" Terrie Hubble, 564-4628 dir.- Phone 564-4166 Date .3 ~ ,~ Commission Use Only Permit To Drill Number: API Number: ! 50- per. - ~ ~ ~ c7 ~ Permit Approval _ Date: ~ ~ ~G~ See cover letter for other requirements Conditions of Approval: Samp es Required '__ Yes ~'No Mud Log Require ~__; Yes ;~', No Hy o en Sulfide Measures `Yes ~No Directional Survey Required ~ Yes ^ No Other: ~~~ r~ 4~~~~ ~'~`" n~~~, c~~~~ ~r"~~~~ !~~ I,~~~t,t-~d_. 1 ~ 1i 11~ APPROVED BY A rove ~ ~,,,d i ~~ P \ ~ THE COMMISSION Date 0 on H~/A~1 RpG Form 10-401 l9~vised 6/2 4 ~_ ~ubrAtit In Duplicate • Well Name: S-111 i ~ Planned Well Summary Well S-111 i Well Horizontal Target Kuparuk C Type Injector Ob'ective AFE Number: AUD5M0066 Surface Northin Eastin Offsets TRS Location 5,980,730.34 618,930.49 753' FNL / 783' FWL 12 N, 12 E, 35 API Number: 50-029-##### Target Northin Eastin Offsets TRS Location 5,989,220.00 617,250.00 2,483' FSL / 751' FEL 12 N, 12 E, 22 Bottom Northin Eastin Offsets TRS Location 5,992,300.00 611,750.00 367' FSL ! 918' FEL 12 N, 12 E, 16 Planned KOP: 400' and / 400' tvd Planned TD: 18,033' and / 6,895' tvd Ri Nabors 7ES CBE: 35.60' RTE: 64.10' Estimated S ud Date: 4/15/2005 Planned O eratin Da s: 40.5 days Directional Program A roved Well Ian: Wp02, W 07 Exit oint: 11,587' and / 6,800' sstvd Maximum Hole Inclination: 94.0° from -12,150' to _13,333' in the tanned 6 3/4" roduction section. All surrounding wells pass major risk criteria. Wells S-108 and S-113 are the Proximity Issues: closest neighboring wells, each at 15' center. The closest approach to S-108 is at 194 md, with acenter-to-center distance of 15.5 . The closest ~proach ' ' to S-113 is at 644 md, with acenter-to-center distance of 18.9 . Survey Program: Standard MWD with IIFR /Cassandra. Nearest Well within ool: Well S-102L1, with center-to-center distance of 1,366' at 15,800' md. Nearest Pro a Line This well crosses the PA and PBU boundary, b desi n. Logging Program Hole Section: Required Sensors /Service 13'/2" Surface Real time MWD Dir/GR throu hout the interval. 9 7/8" intermediate: Real time MW D DirlGR/Res/PW D; Recorded Den/Neu throu hout the interval. 6 3/4" production: Real time MWD Dir/GR/Res/ABI/Den/Neu throu hout the interval. Cased Hole: USIT to confirm 7 5/8" casin cement uali ~ O en Hole: None tanned S-111 i Permit to Drill Application Page 1 ~ • Mud Program Hole Section / o eration: Drillin 13'/z" interval from surface to 2,100'. T e Densi Viscosi PV YP Chlorides API FL H S ud 8.8 - 9.2 300 - 250 20 - 45 50 - 70 <500 NC - 8.0 8.5 - 9.0 Hole Section / o eration: Drillin 13'/z" interval from 2,100' to -2,900'. T e Densit Viscosit PV YP Chlorides API FL H S ud 9.2 - 9.5 250 - 225 20 - 40 30 - 45 <500 8.0 8.5 - 9.0 Hole Section / o eration: Drillin 13'/z" interval from 2,900' to TD. T e Densi Viscosit PV YP Chlorides API FL H S ud 9.5 225 - 250 15 - 20 30 - 40 <500 5.0 - 7.0 8.5 - 9.0 Hole Section / o eration: Drillin 9 7/8" interval from surface shoe to To HRZ. T e Densit Viscosit PV YP Chlorides API FL H LSND 9.8-10.1 45-60 12-18 22-28 <600 4.0-7.0 9.0-9.5 Hole Section / o eration: Drillin 9 7/8" interval from Top HRZ to TD. T e Densi Viscosit PV YP Chlorides API FL H LSND ,~`11. 45 - 60 14 - 22 24 - 28 <600 3.0 - 5.0 9.0 - 9.5 Hole Section / o eration: Millin window in 7 5/8" casin . T e Densi Viscosit PV YP LSRV API FL H Flo-Pro 8.8 - 8.9 45 - 55 8 -15 30 - 35 >25,000 5.0 - 7.0 9.0 - 9.5 Hole Section / o eration: Drillin 6 3/4" production interval to TD. T e Densi Viscosi PV YP LSRV API FL H Flo-Pro 8.8 - 8.9 45 - 55 8 -15 24 - 28 >25,000 5.0 - 7.0 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. ~ Grade Connection i Length Top and / tvd Bottom and / tvd 42" 20" insulated 91.5# H-40 WLD 80' Surface 110' / 1.10' 13 1/2" 10 3/4" 45.5# L-80 BTC 4,660' Surface 4,660' / 3,339' 9 7/8" 7 5/8" 29.7# L-80 BTC-M 12,255' Surface 12,255' / 7,146' 6 3/4" 4'/z" 12.6# L-80 HYDRIL 521 6,559' 11,474'/ 6,816' 18,033' / 6,895' Tubin 5'/z" 17.0# L-80 TC-I I 11,474' Surface 11,474' / 6,816' S-111 i Permit to Drill Application Page 2 s • Cementing Program Casin Strip 10 3/4", 45.5#, L-80, BTC Surface casin Slurry Design Basis: Lead slurry. 2,067' of 10 3/a" X 13' "annulus from surface to the base of the Permafrost, with 225% exces , lu 1,593' of 10 3/a" X 13'/2" annulus with 30% excess. Lead TOC to urfa .Incorporate TAM port collar if necessary. Tail slurry. 1,000' of 10 3 13 1/2" annulus with 30% excess, plus ~86' of 10 3/4", 45.5#, shoe tract. Tail TOC to ~3,660'md, --2,793'tvd. Pre-Flush: 15.Obbls CW 100 S acer Fluid: 75.Obbls MudPUSH II at 10.10 Slur T e 10.70 Arctic Set Lite Permafrost Mix method Batch mix Lead Slurry: BHST /BHCT 58° F / 50° F Thickenin time 6 hrs 00 min Slur Volume 603.Obbl / 3,387cf 7 sx ASL 10.7 .4 cf/sk. Slur T e 15.8 Class `G' "° Mix method Batch mix Tail Slurry: BHST /BHCT 58° F / 50° F Thickenin time 4 hrs 45 min Slur Volume 92.Obbi / 518cf / 4 x Class `G', 15.8 .1 f/sk. ;~ .~- Casin Strip 7 5!8", 29.7#, L-80, BTC-M Intermediate casin lop strip Slurry Design Basis: Le sl rry. 3,915' of 7 5/8" X 9 7/8" annulus with 40% excess. Lead TOC to - ,17 md, 500' above top,Ugnu Ma. o luny. 1,168 of 7 5/8 X 9 7/8 annulus with 40 /° excess, plus -86 of 7 5/8", 29.7#, shoe tract. Tail TOC to ~11,086'md, 500' above TKUP. Pre-Flush: None planned S acer Fluid: 55.Obbls MudPUSH II at 11.50 Slur T e 12.0 LiteCRETE Mix method Batch mix Lead Slurry: BHST /BHCT 150° F / 120° F Thickenin time 6 hrs 55 min Slur Volume 210.Obbl / 1,179cf x LiteCRETE, 12.0 , 2.3 f/sk. Slur T e 15.8 Class `G' r slur with `GASBLOK' additive Mix method Batch mix Tail Slurry: BHST /BHCT 150° F / 120° F Thickenin time 4 hrs 00 min Slur Vo ume 67.Obbl / 376cf 32 sx Class `G', 15.8 ; 1. cf/sk. # ~.~ S-111 i Permit to Drill Application Page 3 s • Casin Strin 4 1/2", 12.6#, L-80, HYDRIL 521 Production liner Slurry Design Basis: Lead slurry: None planned. Tail slurry: 6,424' of 4 1/2" X 6 3/4" annulus with 40% excess, plus 150' of 4 /z X 7 5/8" liner lap, plus 200' of 4" dri Ip X 7 5/8' annulus, plus ~86 of 4 1 /2", 12.6#, shoe tract. Tail TOC to 1,43 md'. Pre-Flush: 15.Obbls CW100 S acer Fluid: 50.Obbls MudPUSH II at 10.Oppg Slur T e None tanned Mix method N/A Lead Slurry: BHST /BHCT N/A Thickenin time N/A Slur Volume N/A Slur T e 15.8 Class 'G' liner slur with `GASBLOK' additive Mix method Batch mix Tail Slurry: BHST /BHCT 150°F / 120° F Thickenin time 4 hrs 00 min -~~ ~' Slur Volume 233.Obbl / 1,308cf / ,11 Class `G', 15.8 1. cf/sk. ~.,,,• Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 10 3/4" casin Float a ui ment to surface 30 min recorded 3,500 si surface 10 3/4" casin shoe 20' new formation be and FIT 12.5 EMW 7 5/8" casin Float a ui ment to surface 30 min recorded 4,000 si surface 7 5/8" window 20' new formation be and FIT 10.0 EMW 4 %" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Well Control The surface hole interval will be drilled with a diverter. Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 9 7/8" intermediate interval into Kuparuk C sands Maximum antici ated BHP: 3,075 si at 6,800' sstvd. Maximum surface reSSUre: 9 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: 4 bls with 12.5 EMW FIT Planned BOPE test ressure: si low / 4,000 si hi h -14 da test c cle Drillin o erations BOPE configuration for 7 5/8" intermediate casin . 7 5/8" pipe rams, blind/shear rams, and an annular preventer. Well Interval: 6 314" roduction interval horizontal in Kuparuk C sands Maximum antici ated BHP: 3,075 si at 6,800' sstvd. Maximum surface ressure: 2, 5 I (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: I fi ' e with 10.Oppg EMW FIT. Planned BOPE test ressure: 0 si low / 4,OOOpsi hi h -14 da test c cle (Drilling o erations ~ Planned com letion fluid: 8.8ppg brine / 7.1 ppg Diesel S-111 i Permit to Drill Application Page 4 t • Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class 1 wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Formation MD TVDbkb TVDss Comments G 1 340 SV6 1535 Base Permafrost 1860 Fault A 2000 SV5 2120 SV4 2310 SV3 2685 SV2 2840 SV1 3175 UG4 3535 UG4A 3575 UG3 3900 U G 1 4465 Ma 4825 H drocarbon bearin Na 5035 H drocarbon bearin OA 5126 H drocarbon bearin Fault B 5450 Obf base 5460 Estimated EMW 8.4 CM2 K-10 5685 CM1 6365 THRZ 6650 Kalubik 6770 K-1 6800 TKUP 6800 Ku aruk C 6800 Estimated ressure 3,075 si 8.7 EMW LCU Ku aruk B 6940 Estimated ressure 3,350 si 9.3 EMW Ku aruk A Not enetrated TMLV Not enetrated OW C 6850 FW L 6880 TD Criteria TD Criteria: Through the base of Kuparuk C for MWD evaluation and adequate whip stock space. I1. o S-111 i Permit to Drill Application Page 5 s • Fault Prognosis Fault Formation Encountered MD Intersect TVDss Intersect Estimated Throw Direction of Throw Uncertainty Fault A SV5 2,274 -2,000 80' West 100' Fault B Schrader Obf 8,886 -5,450 65' East 100' Fault 1 Hz Ku aruk C 12,400 6,815 - 6,841 26' West 100' Fault 2 Hz Ku aruk C 13,700 6,794 - 6,816 22' West 100' Fault 3 Hz Ku aruk C 15,650 6,816 - 6,764 52' East 100' Fault 4 Hz Ku aruk C 17,000 6,773 - 6,833 60' West 100' Operations Summary Pre-Rig Operations: 1. Weld an FMC landing ring, for the FMC slim-hole wellhead, on the conductor. 2. If necessary, level the pad and prepare location for rig move. Riq Operations: 1. MI/RU Nabors 7ES. f 2. Nipple up the diverter spool and riser. P/U sufficient length of 5" drill pipe and stand back in the derrick. 3. M/U a 13 1/2" drilling assembly with Dir/GR. Spud and directionally drill surface hole to approximately the base of the permafrost. Trip for a new bit. 4. RIH and drill the remainder of the surface hole to approximately 100' tvd below the SV1 sand. POOH and UD BHA. 5. R/U, run, and cement the 10 3/4", 45.5# casing back to surface. A TAM port collar may be run as a contingency. 6. N/D the riser spool and N/U the FMC casing head and tubing spool. 7. N/U the BOPE and test to 4,000p '. ~ 8. MU 9 7/8" Rotary Steerable S .assembly and RIH, P/U 5~ rill pipe, to the landing collar. Test the 10 3/4" casing to 3,500 psi fo minutes. Record the test. 9. Drill out cement, float equipment, and the shoe. Displace the well to 9.8 ppg LSND drilling fluid. 10. Drill approximately 20' new formation and perform an FIT to 12.5ppg EMW. ~ 11. Drill ahead, according to directional proposal, to 100' above the HRZ. 12. Increase mud weight, via `spike' fluid, to 11.Oppg. Include sufficient Glycol in `spike' fluid to yield -5% solution in system. 13. Directionally drill ahead to intermediate TD, approximately 100'md below the top of the Kuparuk B. Condition hole as necessary. POOH, UD all 5" drill pipe. 14. R/U, run, and cement the 7 5/8", 29.7# intermediate casing. 15. Install casing pack-off and test per FMC representative. 16. Freeze-protect the 10 3/a" X 7 5/8" annulus, once the cement has reached 1,000psi compressive strength. 17. M/U a full gauge 6.75" mill assembly and RIH, P/U 4" drill pipe. RIH to tag. / 18. Pressure test the. 7 5/8" casing to 4,000psi for 30 minutes. Record the test. 19. Displace the well to 8.9ppg Flo-Pro based fluid. POOH, stand back mill assembly. 20. R/U SWS E-line. RIH with USIT, utilizing rollers as needed. Log the cement quality from PBTD to / above the Kuparuk. Confirm adequate zonal isolation with town staff. POOH. S-111 i Permit to Drill Application Page 6 • ~ 21. Attempt to run in hole with HES 7 5/8" EZS-line. tf it becomes problematic, POOH, R/D E-line, and run the EZSV on 4" drill pipe. Set at ~ ,6 md, or as required, for optimal well bore exit into the ~` Kuparuk C. POOH. 22. M/U a Baker 7 5/8" whip stock assembly. RIH, orient as desired, and set the whip stock on the EZSV. 23. Mill window in the 7 5/8" casing. Work window and circulate clean. Attempt an FIT to 11.8ppg EMW. / POOH and VD mill assembly. 24. M/U a 6 3/4" drilling assembly with Dir/GR/Res/Den/Neu. RIH, P/U additional 4" drill pipe as required. 25. Kick off and drill ahead, per directional proposal, to the extent the bit / bha allows. Short trip and condition hole as needed. 26. If and when necessary, POOH and UD conventional drilling assembly. P/U a Rotary Steerable assembly (RSS) and RIH. 27. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 1 ,0 md. 28. Condition the hole as required in preparation of running and cementing the 4 ~/z" produc ' n liner. Spot ~ liner running pill on bottom. POOH, UD excess 4" drill pipe, and UD BHA. 29. R/U and run the 4 1/2", 12.6#, L-80, HYDRIL 521 liner. Cement the liner per Dowell program. Release from the liner and set the packer. Circulate excess cement to surface. 30. Displace the well to 8.9ppg brine above the liner top. POOH and VD LRT. ~ 31. R/U and pressure-test the casing X liner string to 4,OOOpsi for 30 minutes. Record the test. 32. R/U, M/U Schlumberger 2 1/2", 6spf, DPC perforating guns and 2 7/8" drill pipe as required. RIH to tag and perforate per subsurface team. POOH, UD all drill pipe. 33. R/U and run a 5 1/2", 17.0#, TC-II, L-80 completion, with 4'/i" tubing tail. Space and land the tubing /" with the Tubing tail inserted into the liner tie back sleeve. RILDS. 34. Install a TWC and test. 35. N/D the BOPE. 36. N/U the adapter flange and tree. Test tree and adapter to 5,OOOpsi. Pull TWC. 37. R/U circulating lines and test. Reverse circulate 8.9ppg brine and Corrosion Inhibitor. Finish circulation with sufficient volume of diesel to freeze-protect the tubing and annulus to 2,200'. Allow the diesel to U-tube to equilibrium. 38. Drop ball/rod and set packer. Individually test the tubing and annulus to 4,OOOpsi for 30 minutes. Record each test. 39. Install a BPV and VR plugs in the annulus valves. 40. Secure, rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install the well house, instrumentation, and flow line. Estimated Spud Date: 04/15/2005 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 S-111 i Permit to Drill Application Page 7 s ~ Phase 1: Move In / Rig Up /Accept Planned Phase Time Planned Phase Cost 24 hours $66,711 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - There are two near-by neighboring wells, S-i 08 and S-113. S-113 is 15' to the north and S- 108 is 15' to the south of the S-111 conductor. - These will require removal of the well house and a surface shut in, with pressure bled off, during the rig MI/RU. Care should be taken while moving onto the well. Spotters should be employed at all times. - S-pad is not designa#ed as an HZS si#e. Flowever, Standard Operating Procedures for H2S precautions should be #ollowed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading S-108 10ppm S-102 10ppm S-113 10ppm S-119 N/A The maximum leuel recorded of H2S on the pad was 100ppm, in 12/2002. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. - Check the landing ring height on S-111 prior to rig mobilization. The BOP nipple up may need review for proper space-out prior to spud. Phase 2: Drill 13'h" Surface Hole Interval Planned Phase Time Planned Phase Cost 78 hours $405,582 Reference RP • "Prudhoe Bay Directional Guidelines" RP • "Well Control Operations Station Bill" RP Issues and Potential Hazards - There are two close approach issues while drilling the surface hole. Well S-108 is approximately 15.5' away from the planned S-111 path at 194'md. Well S-113 is approximately 18.9' away from the planned S-111 path at 644'md. - Surveys will need to be IFR + MS corrected. - Gas hydrates have been observed in some wells drilled on S-Pad. These were encountered near the base of permafrost to TD which is below the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation. S-111 i Permit to Drill Application Page 8 • • - S-111 is expected to cross one fault in the surface hole. Fault A will be encountered at approximately 2,274'md, 2,000'tvdss in the SV-5. No significant problems are expected during drilling. A TAM port collar in the 10 3/a" casing is proposed as a contingency, should this fault cause problems with lifting cement to surface.. Phase 3: Run and Cement 10 3/4" Surface Casing Planned Phase Time Planned Phase Cost 42 hours $525,433 Reference RP • "Casing and Liner Running Procedure" RP • "Surface Casing and Cementing Guidelines" RP • "Surface Casing Port Collar Procedure" RP Issues and Potential Hazards - It is critical that cement is circulated to the surface for well integrity. Planned cement volume is based upon: 225% excess cement through the permafrost zone and 30% excess below the permafrost. A 10 3/4" port collar will be positioned at --1,000'md to allow remedial cementing should cement not reach the surface on the primary cementing job. - One `bow-spring' centralizer, per joint, will be run on the first 15 joints. Additionally, one will be placed on each side of the port collar. - Reciprocate the casing -10' while displacing cement, if the hole condition will allow it. - Note: Check surface cement level prior to leaving the location to determine whether or not the cement has slumped. Record depth tagged on Morning Report. If TOC is greater than 20' below top of conductor, notify AOGCC and perform a 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, port collar cement work. Review the "Surface Casing and Port Collar RP" Phase 5: Drill 8 3/4" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 171 hours $1,133,859 Reference RP • "Standard Operating Procedure for Leak-off and Formation Integrity Tests" RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management' RP S-111 i Permit to Drill Application Page 9 • ~ Issues and Potential Hazards - This well bore will drill the HRZ at ~65° inclination, terminating in the Kuparuk B. Previous S-Pad wells drilled the HRZ with 9.8 to 11.4ppg mud weights. For this well, the HRZ will require a mud weight of 11.Oppg. Maintain mud weight at 11.Oppg, minimally, from above the HRZ to the 7 5/8" casing point. Follow all shale drilling practices to minimize potential problems. - The S-111 well path wilt cross one fault, Fault B, in the Schrader OBf at - 8,886'md, 5,450'tvdss. The potential for lost circulation or breathing is moderate. Monitor ECD and consult the Lost Circulation Decision Tree, embedded in the mud program, regarding LCM treatments and procedures. - Previous wells S-200 and S-201 encountered overpressure (10.0 ppg EMW) while drilling the UG4A. Mud weights of 10.1 ppg-10.3ppg were required. Several S-Pad wells drilled in 2000 used 10.5ppg to drill this interval as a precaution. Since that time many 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. - KICK TOLERANCE: In the scenario of 9.8ppg pore pressure in the Kuparuk, a minimum fracture gra of 11.6 ppg at the surface casing shoe, and 11.Oppg mud in the hole, the kick tolerance is 0 bls. Phase 6: Run and Cement 7 5/8" Intermediate Casing Planned Phase Time Planned Phase Cost 94 hours $822,751 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. - This intermediate casing cement job is planned as a single stage, with a 12.Oppg Lite-CRETE lead slurry to 500' above the Ugnu Ma, followed by a 15.8ppg class `G' tail slurry to -500' above the Kuparuk. The TOC lead will be 7,171'md, 4,631'tvd. The TOC tail will be 11,086'md, 6,650'tvd. - Confirm that the intermediate casing cement has had adequate thickening time (706c value), prior to freeze protecting the 10 3/4" by 7 5/8" casing annulus. If necessary, ensure a double barrier is in place on the annulus, at the surface, until the cement has set up for at least 12 hours. - Request a UCA from Schlumberger Dowell. Confirm a cement compressive strength of 1,000psi, minimally, prior to pressure testing the 7 5/8" casing. - It will be necessary to run a USIT log in the 7 5/8" intermediate casing, to confirm adequate zonal isolation, as required for injection service. S-111 i Permit to Drill Application Page 10 • • Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 30 hours $165,515 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. Phase 7: Drill 6 3/4" Production Hole Interval Planned Phase Time Planned Phase Cost 372 hours $1,837,779 ~ Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The planned well, S-111 i (W p07), is expected to cross four faults while drilling the production (injection) interval. Each of the four faults will be encountered in the Kuparuk C, at ~12,400'md, 13,700'md, 15,650'md, and 17,000'md. They are each of relatively small throw, ~25' - 50'. It is not expected that these will create significant trouble. However, should losses occur, follow the Lost Circulation Decision Tree, embedded in the mud program, regarding LCM treatments and procedures. - If a request is made to extend the well bore beyond the planned TD coordinate, regardless the revised TD location relative to the polygon, contact the drilling engineer prior to drilling ahead. It will be prudent to confirm proximity clearance. S-111 i Permit to Drill Application Page 11 • • Phase 9: Run 4~/z" Production Liner Planned Phase Time Planned Phase Cost 50 hours $489,444 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The planned production liner is a 4 '/2", 12.6#, L-80, HYDRIL 521 solid liner throughout the production (injection) interval. - Differential sticking is possible. The 8.9ppg Flo-Pro will be ~150psi over balanced to the Kuparuk C formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4 ~h" liner will be run to extend --150' back up into the 7 5/8" casing window. - Ensure the 4'/z° liner top packer is set prior to POOH. Phase 10: DPC Perforate Planned Phase Time Planned Phase Cost 38 hours $330,714 Reference RP • "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards - The well will be DPC perforated, -150psi overbalanced, after running the 4 '/z" liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. - Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Phase 12: Run 5'/s" X 4 ~/s" L-80 Completion Planned Phase Time Planned Phase Cost 20 hours $417,186 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. S-111 i Permit to Drill Application Page 12 • • - The completion, as designed, will be to run a 5 %z", 17.0# X 4%2", 12.6#, L-80, TC-II production tubing string, stinging into the 4 ~h" liner tieback sleeve. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 29 hours $89,109 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - There are two near-by neighboring wells, 5-108 and S-113. S-113 is 15' to the north and S- 108 is 15' to the south of the S-111 i well. ~ - Care should be taken while moving off of the well. Spotters should be employed at all times. - During ND BOPE/NU tree operations, the S-111 i well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid above ball/rod. o IA: Annulus valves and kilt weight fluid. o OA: Annulus valve and kill weight fluid. - During RD/MO operations, the S-111 i well bore will be secured with the following barriers: o Tubing: BPV and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. S-111 i Permit to Drill Application Page 13 E« S-111PB1 (P2b) ~~E~o Prudhoe Bay Unit - WOA SiRU~TURE S-PAD ~,~=e, 0 1200 2400 3600 4800 6000 7200 8400 9600 0 1200 2400 0 0 N C 3600 a~ m U O F- 4800 6000 7200 0 1200 2400 3600 4800 6000 7200 0 1200 2400 3600 4800 6000 7200 8400 9600 3ehlu e~ n ~LL S-111PB1 (P2b) 0.D Prudhoe Bay Unit - WOA ~~n~ S-PAD .moc ~,. re, rv~w -3600 -2400 -1200 0 1200 8400 7200 6000 n n n Z 0 4800 0 N C N (6 U cn 3600 v v v 2400 1200 n 0 -2400 -1200 0 1200 «< W Scale=1(in):1200(ft) E »> 8400 7200 6000 4800 3600 2400 1200 n S-111 PB1 (P2b Report Date: March 9, 2005 Client: BP Exploration Alaska Field: Prudhoe Bay Unit- WOA Structure I Slot: S-PAD / 5-111 (slot 15) ® ^,P~,~ F/ Well: ® Plan 5-111 '~ ~~~j' Borehole: r PIanS-111PB1 UWVAPI1t: 50029 Survey Name /Date: S-i i 1P81 (P2b) (March 9, 2005 Tort I AHD I DDI I ERD ratio: 76.856° 19288.32 ft / 6.08811.300 Grid Coordinate System: NAD27 Alaska Slate Planes, Zone 04, US Feet Location LaUlong: N 70.35600664, W 149.03412780 Location Grid NIEYIX: N 5980730.340 ftUS, E 618930.490 ftUS Grid Convergence Angle: +0.90966782° ~osal ~' ~ erg Survey I DLS Computation Method: Minimum Curvature (Lubinski Vertical Secion Azimuth: 345.690° Vertical Section Origin: N 0.000 ft, E 0.000 H ND Reference Datum: Rotary Table ND Reference Elevation: 64.10 ft relative to MSL Sea Bed I Ground Level Elevation: 35.60 ft relative to MSL Magnetic Declination: 24.650° Total Field Strength: 57623.965 nT Magnetic Oip: 80.849° Declination Date: April 20, 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North a True North: +24.650° • Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Hole NS EW DLS Tool Faca Build Rate Walk Rate Northing EasUng Latitude Longitude Depth Section Departure ft de de h ft tt ft ft ft de 100 ft de d 700 ft de 1100 ft kUS ftUS KIC U.UU U.VU 3Zy.UU -b4."IU U.UU U.UU U.UU U.VU U.UU U.UU -37.VUM U,UV U.UU b88U/3U.34 U7Sy3U.4H N /V.3bbUU6(i4 W 749.U341L/SU KOP Bld 1.5/100 400.00 0.00 329.00 335.90 400.00 0.00 0.00 0.00 0.00 0.00 -31.OOM 0.00 0.00 5980730.34 618930.49 N 70.35600664 W 149.03412780 G1 404.10 0.06 329.00 340.00 404.10 0.00 0.00 0.00 0.00 1.50 -31.OOM 1.50 0.00 5980730.34 618930.49 N 70.35600665 W 149.03412781 BId 2/100 500.00 1.50 329.00 435.89 499.99 1.25 1.31 1.12 -0.67 1.50 -31.OOM 1.50 0.00 5980731.45 618929.80 N 70.35600971 W 149.03413327 600.00 3.50 329.00 535.79 599.89 5.43 5.67 4.86 -2.92 2.00 -31.OOM 2.00 0.00 5980735.15 618927.49 N 70.35601992 W 149.03415151 700.00 5.50 329.00 635.47 699.57 12.95 13.52 11.59 -6.96 2.00 O.OOG 2.00 0.00 5980741.81 618923.35 N 70.35603830 W 149.03418432 800.00 7.50 329.00 734.83 798.93 23.79 24.84 21.29 -12.79 2.00 O.OOG 2.00 0.00 5980751.42 618917.36 N 70.35606480 W 149.03423167 900.00 9.50 329.00 833.72 897.82 37.95 39.62 33.96 -20.40 2.00 O.OOG 2.00 0.00 5980763.97 618909.55 N 70.35609941 W 149.03429348 Bld 3/100 925.00 10.00 329.00 858.36 922.46 42.00 43.85 37.59 -22.58 2.00 O.OOG 2.00 0.00 5980767.56 618907.31 N 70.35610933 W 149.03431119 1000.00 12.25 329.00 931.95 996.05 55.86 58.32 49.99 -30.04 3.00 O.OOG 3.00 0.00 5980779.84 618899.67 N 70.35614321 W 149.03437170 1100.00 15.25 329.00 1029.07 1093.17 78.63 82.09 70.36 -42.28 3.00 O.OOG 3.00 0.00 5980800.02 618887.10 N 70.35619887 W 149.03447110 1200.00 18.25 329.00 1124.82 1188.92 106.23 110.90 95.06 -57.12 3.00 O.OOG 3.00 0.00 5980824.47 618871.87 N 70.35626634 W 149.03459162 1300.00 21.25 329.00 1218.92 1283.02 138.59 144.69 124.02 -74.52 3.00 O.OOG 3.00 0.00 5980853.15 618854.02 N 70.35634546 W 149.03473293 1400.00 24.25 329.00 1311.13 1375.23 175.63 183.36 157.17 -94.44 3.00 O.OOG 3.00 0.00 5980885.98 618833.58 N 70.35643601 W 149.03489465 1500.00 27.25 329.00 1401.19 1465.29 217.24 226.80 194.40 -116.81 3.00 O,OOG 3.00 0.00 5980922.85 618810.62 N 70.35653773 W 149.03507633 1600.00 30.25 329.00 1488.86 1552.96 263.31 274.89 235.63 -141.58 3.00 O.OOG 3.00 0.00 5980963.67 618785.20 N 70.35665035 W 149.03527748 SV8 1853.87 31.87 329.00 1535.00 1599.10 289.93 302.68 259.45 -155.89 3.00 O.OOG 3.00 0.00 5980987.26 618770.51 N 70.35671542 W 149.03539371 1700.00 33.25 329.00 1573.88 1637.98 313.71 327.51 280.73 -168.68 3.00 O,OOG 3.00 0.00 5981008.33 618757.39 N 70.35677356 W 149.03549754 1800.00 36.25 329.00 1656.04 1720.14 368.30 384.50 329.58 -198.03 3.00 O,OOG 3.00 0.00 5981056.71 618727.27 N 70.35690702 W 149.03573592 1900.00 39.25 329.00 1735.10 1799.20 426.94 445.71 382.05 -229.56 3.00 O.OOG 3.00 0.00 5981108.67 618694.91 N 70.35705036 W 149.03599196 2000.00 42.25 329.00 1810.84 1874.94 489.46 510.98 438.00 •263.17 3.00 O.OOG 3.00 0.00 5981164.07 618660.42 N 70.35720320 W 149.03626495 Base Perm 2067.50 44.28 329.00 1860.00 1924.10 533.77 557.24 477.65 -287.00 3.00 O.OOG 3.00 0.00 5981203.33 618635.97 N 70.35731152 W 149.03645845 2100.00 45.25 329.00 1883.07 1947.17 555.69 580.12 497.26 -298.79 3.00 O.OOG 3.00 0.00 5981222.76 618623.87 N 70.35736511 W 149.03655416 2200.00 48.25 329.00 1951.58 2015.68 625.45 652.95 559.69 -336.30 3.00 O.OOG 3.00 0.00 5981284.57 618585.38 N 70.35753565 W 149.03685879 Crv 3/100 2258.33 50.00 329.00 1989.76 2053.86 667.69 697.06 597.50 -359.01 3.00 71.67G 3.00 0.00 5981322.01 618562:07 N 70.35763893 W 149.03704328 Fault A Crossing 2274.30 50.15 329.59 2000.00 2064.10 679.44 709.30 608.02 -365.26 3.00 71.29G 0.95 3.71 5981332.43 618555.65 N 70.35766768 W 149.03709404 2300.00 50.40 330.54 2016.43 2080.53 698.48 729.07 625.16 -375.13 3.00 70.6SG 0.98 3.69 5981349.41 618545.52 N 70.35771449 W 149.03717416 2400.00 51.45 334.16 2079.47 2143.57 774.00 806.70 693.91 -411.13 3.00 68.40G 1.05 3.62 5981417.58 618508.43 N 70.35790232 W 149.03746655 SV5 2465.57 52.20 336.48 2120.00 2184.10 824.70 858.24 740.75 -432.65 3.00 66.97G 1.14 3.53 5981464.06 618486.17 N 70.35803027 W 149.03764132 WeIlDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31rt-546) 5-111 (slot 15)\Plan S-111\Plan S-111 P61\S-111 P61 (P2b) Generated 3/9/2005 10:32 AM Page 1 of 2 Comments Measured Inclination Azimuth Subsea TVD TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Lagtuda Longitude Depth Section Departure ft de de ft ft ft ft ft ft de 1100 ft de de 100 @ de 1100 ft ftUS ftUS LJUU.UV JL.O.1 33/.b/ G-14-I.VV GLUJ.IU bbl .O/ 23tlJ.bL Ibb.B/ W43.L/ 3.VU bb.L4li l.ly 3.4/ bybl4b`J.V-I b104/b.-IJ N /U.3JifUyCyU VV l4y.V3//L/bL 2600.00 53.87 341.07 2200.86 2264.96 931.28 965.62 840.83 -471.47 3.00 64.20G 1.26 3.40 5981563.51 618445.77 N 70.35830369 W 149 .03795666 2700.00 55.22 344.36 2258.88 2322.98 1012.60 1047.07 918.60 -495.65 3.00 62.29G 1.35 3.29 5981640.88 618420.37 N 70.35851612 W 149 .03815303 SV4 2791.11 56.52 347.26 2310.00 2374.10 1088.00 1122.48 991.70 -514.11 3.00 60.66G 1.43 3.18 5981713.67 618400.74 N 70.35871583 W 149. 03830306 2800.00 56.66 347.54 2314.90 2379.00 1095.43 1129.90 998.95 -515.73 3.00 60.51G 1.47 3.13 5981720.89 618399.01 N 70.35873563 W 149 .03831621 2900.00 58.17 350.61 2368.76 2432.86 1179.52 1214.15 1081.66 -531.68 3.00 58.86G 1.51 3.07 5981803.33 618381.75 N 70.35896160 W 149 .03844574 End Crv 2954.25 59.02 352.24 2397.03 2461.13 1225.58 1260.45 1127.45 -538.58 3.00 O.OOG 1.57 2.99 5981849.00 618374.13 N 70.35908667 W 149 .03850181 SV3 3513.73 59.02 352.24 2685.00 2749.10 1702.13 1740.13 1602.73 -603.36 0.00 O.OOG 0.00 0.00 5982323.15 618301.82 N 70.36038508 W 149. 03902823 SV2 3814.87 59.02 352.24 2840.00 2904.10 1958.63 1998.32 1858.55 -638.23 0.00 O.OOG 0.00 0.00 5982578.36 618262.89 N 70.36108395 W 149. 03931161 SV1 4465.72 59.02 352.24 3175.00 3239.10 2513.01 2556.34 2411.46 -713.59 0.00 O.OOG 0.00 0.00 5983129.96 618178.77 N 70.36259442 W 149. 03992413 10-3/4" Csg Pt 4660.00 59.02 352.24 3275.00 3339.10 2678.50 2722.91 2576.50 -736.08 0.00 O.OOG 0.00 0.00 5983294.61 618153.66 N 70.36304531 W 149. 04010700 UG4 5165.14 59.02 352.24 3535.00 3599.10 3108.76 3156.00 3005.62 -794.57 0.00 O.OOG 0.00 0.00 5983722.71 618088.37 N 70.36421761 W 149. 04058247 UG4A 5242.86 59.02 352.24 3575.00 3639.10 3174.96 3222.63 3071.64 -803.57 0.00 O.OOG 0.00 0.00 5983788.58 618078.33 N 70.36439797 W 149. 04065563 UG3 5874.28 59.02 352.24 3900.00 3964.10 3712.79 3763.99 3608.05 -876.68 0.00 O.OOG 0.00 0.00 5984323.70 617996.71 N 70.36586334 W 149. 04125006 UG1 6971.99 59.02 352.24 4465.00 4529.10 4647.78 4705.12 4540.56 -1003.79 0.00 O.OOG 0.00 0.00 5985254.00 617854.84 N 70.36841084 W 149. 04228366 Ugnu MA 7671.42 59.02 352.24 4825.00 4889.10 5243.53 5304.79 5134.73 -1084.77 0.00 O.OOG 0.00 0.00 5985846.76 617764.44 N 70.37003402 W 149. 04294237 Schrader NA 8079.41 59.02 352.24 5035.00 5099.10 5591.05 5654.59 5481.33 -1132.01 0.00 O.OOG 0.00 0.00 5986192.53 617711.70 N 70.37098087 W 149. 04332667 OA 8260.10 59.02 352.24 5128.00 5192.10 5744.95 5809.50 5634.82 -1152.94 0.00 O.OOG 0.00 0.00 5986345.66 617688.35 N 70.37140019 W 149. 04349687 Fault B Crossing 8885.69 59.02 352.24 5450.00 5514.10 6277.82 6345.87 6166.27 -1225.37 0.00 O.OOG 0.00 0.00 5986875.85 617607.49 N 70.37285203 W 149. 04408621 OBf Base 8905.12 59.02 352.24 5460.00 5524.10 6294.37 6362.52 6182.77 -1227,62 0.00 O.OOG 0.00 0.00 5986892.32 617604.98 N 70.37289712 W 149. 04410452 CM2 9342.26 59.02 352.24 5685.00 5749.10 6666.71 6737.31 6554.13 -1278.24 0.00 O.OOG 0.00 0.00 5987262.79 617548.48 N 70.37391160 W 149. 04451638 CM1 10663.40 59.02 352.24 6365.00 6429.10 7792.02 7870.01 7676.45 -1431.21 0.00 O.OOG 0.00 0.00 5988382.44 617377.72 N 70.37697759 W 149. 04576136 Crv 4/100 11074.98 59.02 352.24 6576.85 6640.95 8142.60 8222.89 8026.09 -1478.87 0.00 O.OOG 0.00 0.00 5988731.26 617324.52 N 70.37793276 W 149 .04614930 11100.00 60.02 352.24 6589.54 6653.64 8164.01 8244.45 8047.46 -1481.78 4.00 O.OOG 4.00 0.00 5988752.57 617321.27 N 70.37799112 W 149 .04617300 11200.00 64.02 352.24 6636.44 6700.54 8251.73 8332.74 8134.94 -1493.70 4.00 O.OOG 4.00 0.00 5988839.85 617307.96 N 70.37823012 W 149 .04627006 End Crv 11224.43 65.00 352.24 6646.95 6711.05 8273.64 8354.80 8156.80 -1496.68 4.00 O.OOG 4.00 0.00 5988861.65 617304.64 N 70.37828982 W 149 .04629431 Top HRZ 11231.65 65.00 352.24 6650.00 6714.10 8280.14 8361.33 8163.27 -1497.56 0.00 O.OOG 0.00 0.00 5988868.11 617303.66 N 70.37830751 W 149. 04630149 Kalubik 11515.59 65.00 352.24 6770.00 6834.10 8535.80 8618.67 8418.26 -1532.31 0.00 O.OOG 0.00 0.00 5989122.49 617264.87 N 70.37900408 W 149. 04658437 K-1 /Kup C 11586.58 65.00 352.24 6800.00 6864.10 8599.71 8683.01 8482.00 -1541.00 0.00 O.OOG 0.00 0.00 5989186.08 617255.17 N 70.37917822 W 149. 04665509 LCU (Kup 8) 11917.84 65.00 352.24 6940.00 7004.10 8897.99 8983.24 8779.48 -1581.54 0.00 O.OOG 0.00 0.00 5989482.86 617209.92 N 70.37999089 W 149. 04698515 TD / 7-818" Csg 12254.47 65.00 352.24 7082.26 7146.36 9201.08 9288.32 9081.77 -1622.73 0.00 O.OOG 0.00 0.00 5989784.43 617163.93 N 70.38081669 W 149 .04732057 Leslal Description: Northinn IY1 fitUSl Easting (Xl fftUSl Surtace : 4526 FSL 4497 FEL S35 T12N R12E UM 5980730.34 618930.49 Target : 2482 FSL 751 FEL S22 T 12N R12E UM 5989220.00 617250.00 BHL : 3048 FSL 828 FEL S22 T 12N R12E UM 5989784.43 617163.93 WeIlDesign Ver 3.1 RT-SP3.03-HF5.00 Bld(do31rt-546) S-111 (slot 15)\Plan S-111\Plan S-111 PB1\S-111 PB1 (P2b) Generated 3/9!2005 10:32 AM Page 2 of 2 • Schlumberger Anticollision Report Company: Field: BP Amoco Prudhoe Bav Da[c: 3/9/2005 Time: 10:39:32 Pair. Reference Site: PB S Pad Co-ordina te(\t:) Reference: Well: Pla n S-'111, Tr ue North Kefereucc',1'e11: Plan S-111 ~'crtical ('h V~U) Reference: S-911 plan 64.1 Reference ~~'ellpatlPJan S-111PB1 Db: Syk;ase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Meth odMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 12254.47 ft Scan Method: Trav Cylinder North Maximum Radiu9fl000.00 ft Error Surface: Ellipse + Casing Survey Program fo r Definitive Wellpath Date: 1/7/2005 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name ft ft 28.50 1200.00 Planned: Plan #2 V1 GYD-GC-SS Gyrodata gyro single shots 1200.00 2600.00 Planned: Plan #2 V1 MWD MWD - Standard 1200.00 12254.47 Planned: Plan #2 V1 MWD+IFR+MS MWD + IFR + Muki Station Casing Points MD TVD Diameter HoleSize Name ft ft in in 4572.58 3294.10 10.750 13.500 10 3!4" 12254.47 7146.36 7.625 9.875 7-5/8" Summary <---------------~------- Offset Wellpath ----------------------> Reference Offset Ctr(~tr Ao-Go Allu~wbl c Site ' Well Wellpath MD MD Dishuuc :~rea Dcciatiu n Warnip~ ft ft ft ft ft ~ PB S Pad Plan S-122 Plan S-122P61 V1 Plan: 371.39 400.00 136.18 6.86 129.32 Pass: Major Risk PB S Pad Plan S-203 Plan S-203 (East) V3 P 476.45 500.00 1357.83 10.15 1347.68 Pass; Major Risk PB S Pad Plan S-203 Plan S-203 (West) V5 P 513.92 550.00 1357.69 9.02 . 1348.67 Pass: Major Risk PB S Pad Plan S-208 Plan S-208 VO Plan: S- 500.00 550.00 1628.02 10.86 1617.15 Pass; Major Risk PB S Pad Plan S-214 Plan S-214 V1 Plan: S- 446.37 450.00 196.32 7.63 188.69 Pass; Major Risk PB S Pad Plan S-400 S-400 VO Plan: S-400 w 394.09 400.00 405.89 6.65 399.24 Pass: Major Risk PB S Pad Plan S-401 S-401 VO Plan: S-401 w 1234.88 1350.00 387.87 27.43 360.44 Pass: Major Risk PB S Pad S-01A S-01A V1 397.66 400.00 882.32 10.39 871.92 Pass: Major Risk PB S Pad S-01 B S-01 B V1 393.78 400.00 882.29 10.31 871.98 Pass: Major Risk PB S Pad S-01 S-01 V1 481.89 500.00 877.76 11.74 866.02 Pass: Major Risk PB S Pad S-02APB1 S-02AP61 V1 397.53 400.00 883.90 8.02 875.88 Pass: Major Risk PB S Pad S-02A S-02A V1 397.53 400.00 883.90 8.02 875.88 Pass: Major Risk PB S Pad S-02 S-02 V1 396.28 400.00 883.88 8.00 875.89 Pass: Major Risk PB S Pad S-03 S-03 V1 438.38 450.00 903.55 7.98 895.57 Pass: Major Risk PB S Pad S-04 S-04 V1 472.78 500.00 929.25 9.26 919.99 Pass: Major Risk PB S Pad S-05APB1 S-05APB1 V1 436.64 450.00 975.81 11.09 964.73 Pass: Major Risk PB S Pad S-05A S-05A V1 436.64 450.00 975.81 11.09 964.73 Pass: Major Risk PB S Pad S-05 S-05 V1 431.57 450.00 975.75 10.97 964.78 Pass: Major Risk PB S Pad S-06 S-06 V1 436.32 450.00 1029.81 8.31 1021.50 Pass: Major Risk PB S Pad S-07A S-07A V1 436.48 450.00 1087.35 8.34 1079.00 Pass: Major Risk PB S Pad S-07 S-07 V1 436.48 450.00 1087.35 8.34 1079.00 Pass: Major Risk PB S Pad S-08 S-08 V1 435.74 450.00 1159.83 11.49 1148.33 Pass: Major Risk PB S Pad S-08 S-08A V2 435.74 450.00 1159.83 11.49 1148.33 Pass: Major Risk PB S Pad S-08 S-O86 V3 435.74 450.00 1159.83 11.49 1148.33 Pass: Major Risk PB S Pad S-09 S-09 V1 435.80 450.00 1235.69 9.87 1225.82 Pass: Major Risk PB S Pad S-100 S-100 V10 790.42 800.00 85.63 14.27 71.36 Pass: Major Risk PB S Pad S-101 S-101 V3 199.68 200.00 107.41 4.82 102.60 Pass: Major Risk PB S Pad S-101 S-101 P61 V9 199.68 200.00 107.41 4.82 102.60 Pass: Major Risk PB S Pad S-102 S-102 V11 596.06 600.00 64.94 10.74 54.20 Pass: Major Risk PB S Pad S-102 S-102L1 V5 596.06 600.00 64.94 10.74 54.20 Pass: Major Risk PB S Pad S-102 S-102L1PB1 V7 596.06 600.00 64.94 10.74 54.20 Pass: Major Risk PB S Pad S-102 S-102P61 V14 596.06 600.00 64.94 10.74 54.20 Pass: Major Risk PB S Pad S-103 S-103 V6 951.51 950.00 29.56 15.25 14.31 Pass: Major Risk PB S Pad S-104 S-104 V1 349.60 350.00 120.37 6.89 113.48 Pass: Major Risk PB S Pad S-105 S-105 V5 1107.50 1100.00 69.76 18.04 51.72 Pass: Major Risk PB S Pad S-106 S-106 V2 293.89 300.00 76.67 6.63 70.05 Pass: Major Risk PB S Pad S-106 S-106P61 V12 293.89 300.00 76.67 6.58 70.09 Pass: Major Risk PB S Pad S-107 S-107 V36 494.76 500.00 32.76 10.17 22.59 Pass: Major Risk PB S Pad S-108 S-108 V6 193.81 200.00 15.46 3.84 11.61 Pass: Major Risk PB S Pad S-109 S-109 V8 349.87 350.00 61.17 6.17 55.00 Pass: Major Risk PB S Pad S-109 S-109P61 V2 349.87 350.00 61.17 6.17 55.00 Pass: Major Risk PB S Pad S-10AP61 S-10AP61 V1 472.56 499.96 1312.53 10:16 1302.37 Pass: Major Risk Schlumberger Anticollision Report Cumpan~: BP Amoco Llatet 3/9/2005 f imc: 10:39:38 Pa„c: Z Field: Prudhoe Bay "Reference tiitc: PB S Pad ('o-ordinatclAH;) R eference: Well: Plan S-111, T rue North Reference Nell: Plans-111 ~'ectical`(T 1'D) Reference: 5-111 pl an 64.1 Reference ~~'cllpa tlF'lanS-111PE1 f)b: Sybase Summsrc <---__----__----____ _- pffser ~~~ctlpath ----------------------> Reference Of[set Ctr-Ctr ~o-Gu Allowable Site ~Fcll Wellpafh Dill MD Dirt.uic c:~rea Dc~iafi un blarnin;; ft ft ft ft ft PB S Pad S-10A S-10A V1 472.59 500.00 1312.53 9.97 1302.56 Pass: Major Risk PB S Pad S-10 S-10 V1 472.56 499.96 1312.53 10.16 1302.37 Pass: Major Risk PB S Pad S-110 S-110 V18 344.45 350.00 48.64 7.51 41.13 Pass: Major Risk PB S Pad S-112 S-112 V20 537.17 550.00 199.89 10.72 189.17 Pass: Major Risk PB S Pad S-113 S-113 V14 644.42 650.00 18.86 12.60 6.26 Pass: Major Risk PB S Pad S-113 S-113A V3 644.42 650.00 18.86 12.45 6.41 Pass: Major Risk PB S Pad S-113 S-1136 V6 644.42 650.00 18.86 12.45 6.41 Pass: Major Risk PB S Pad S-114 S-114 V13 649.29 650.00 94.24 13.35 80.89 Pass: Major Risk PB S Pad S-114 S-114A V6 649.29 650.00 94.24 13.19 81.05 Pass: Major Risk PB S Pad S-115 S-115 ST V1 Plan: Plan 299.95 300.00 122.27 5.75 116.52 Pass: Major Risk PB S Pad S-115 S-115 V7 299.95 300.00 122.27 5.65 116.62 Pass: Major Risk PB S Pad S-116 S-116 V6 447.02 450.00 256.73 7.75 248.97 Pass: Major Risk PB S Pad S-117 S-117 V4 448.09 450.00 151.53 8.18 143.34 Pass: Major Risk PB S Pad S-118 S-118 V5 447.64 450.00 241.39 7.73 233.67 Pass: Major Risk PB S Pad S-119 S-119 V7 451.65 450.00 29.21 8.59 20.62 Pass: Major Risk PB S Pad S-11 S-11 V4 471.56 500.00 1394.83 10.35 1384.48 Pass: Major Risk PB S Pad S-11 S-11A V1 472.23 500.00 1394.85 10.37 1384.48 Pass: Major Risk PB S Pad S-11 S-11 B V1 472.60 500.00 1394.86 10.37 1384.48 Pass: Major Risk PB S Pad S-120 S-120 V4 447.93 450.00 167.50 8.50 159.00 Pass: Major Risk PB S Pad S-123 S-123 V10 203.64 200.00 1046.67 6.53 1040.13 Pass: Major Risk PB S Pad S-12A S-12A V1 430.25 450.00 1476.74 9.60 1467.14 Pass: Major Risk PB S Pad S-12 S-12 V1 96.97 100.00 1483.51 2.32 1481.19 Pass: Major Risk PB S Pad S-13 S-13 V1 433.80 450.00 1574.17 8.18 1566.00 Pass: Major Risk PB S Pad S-14 Drilling091604 S-14A V 500.00 550.00 1667.11 16.61 1650.50 Pass: Major Risk PB S Pad S-14 S-14 V5 500.00 550.00 1667.11 16.61 1650.50 Pass: Major Risk PB S Pad S-15 S-15 V2 435.77 450.00 1234.34 10.56 1223.78 Pass: Major Risk PB S Pad S-16 S-16 V1 396.99 400.02 1341.33 7.55 1333.77 Pass: Major Risk PB S Pad S-17 S-17 V1 473.37 499.98 1454.61 10.52 1444.09 Pass: Major Risk PB S Pad S-17 S-17A V1 473.37 499.98 1454.61 10.52 1444.09 Pass: Major Risk PB S Pad S-17 S-17AL1 V1 473.37 499.98 1454.61 10.52 1444.09 Pass: Major Risk PB S Pad S-17 S-17AP61 V1 473.37 499.98 1454.61 10.52 1444.09 Pass: Major Risk PB S Pad S-17 S-176 V1 473.37 499.98 1454.61 10.52 1444.09 Pass: Major Risk PB S Pad S-17 S-17C V1 473.37 499.98 1454.61 10.41 1444.20 Pass: Major Risk PB S Pad S-17 S-17CPB1 V2 473.37 499.98 1454.61 10.41 1444.20 Pass: Major Risk PB S Pad S-17 S-17CP62 V1 473.37 499.98 1454.61 10.41 1444.20 Pass: Major Risk PB S Pad S-18 S-18 V 1 428.94 450.00 1562.75 7.87 1554.88 Pass: Major Risk PB S Pad S-18 S-18A V16 431.18 450.00 1562.78 7.76 1555.02 Pass: Major Risk PB S Pad S-19 S-19 V1 477.62 500.01 876.83 9.90 866.93 Pass: Major Risk PB S Pad S-200PB1 S-200PB1 V4 446.27 450.00 226.03 7.50 218.53 Pass: Major Risk PB S Pad S-200 S-200 V2 446.27 450.00 226.03 7.61 218.42 Pass: Major Risk PB S Pad S-201 S-201 V2 1054.78 1050.00 52.61 16.71 35.90 Pass: Major Risk PB S Pad S-201 S-201 P61 V11 1054.78 1050.00 52.61 16.66 35.95 Pass: Major Risk PB S Pad S-20 S-20 V4 435.78 450.00 886.76 8.18 878.58 Pass: Major Risk PB S Pad S-20 S-20A V2 435.78 450.00 886.76 8.18 878.58 Pass: Major Risk PB S Pad S-213 S-213 V9 446.33 450.00 181.91 7.37 174.54 Pass: Major Risk PB S Pad S-213 S-213A V22 450.25 450.00 181.98 7.42 174.56 Pass: Major Risk PB S Pad S-213 S-213AL1 V9 450.25 450.00 181.98 7.42 174.56 Pass: Major Risk PB S Pad S-213 S-213AL1-01 V7 450.25 450.00 181.98 7.42 174.56 Pass: Major Risk PB S Pad S-213 S-213AL2 V5 450.25 450.00 181.98 7.42 174.56 Pass: Major Risk PB S Pad S-213 S-213AL3 V7 450.25 450.00 181.98 7.42 174.56 Pass: Major Risk PB S Pad S-215 S-215 V9 510.78 550.00 1256.20 9.87 1246.33 Pass: Major Risk PB S Pad 5-216 5-216 V2 349.41 350.00 211.16 7.44 203.73 Pass: Major Risk PB S Pad S-21 S-21 V1 440.27 450.00 909.28 8.33 900.95 Pass: Major Risk PB S Pad S-22A S-22A V 1 483.07 500.00 876.98 8.60 868.38 Pass: Major Risk PB S Pad S-226 S-22B V2 483.07 500.00 876.98 8.71 868.27 Pass: Major Risk PB S Pad S-22 S-22 V1 483.07 500.00 876.98 8.62 868.36 Pass: Major Risk PB S Pad S-23 S-23 V1 441.44 450.00 894.14 8.03 886.11 Pass: Major Risk PB S Pad S-24 S-24 V5 438.78 450.00 920.56 8.44 912.12 Pass: Major Risk PB S Pad S-24 S-24A V1 440.79 450.00 920.59 8.48 912.11 Pass: Major Risk PB S Pad S-24 S-24B V2 440.79 450.00 920.59 8.48 912.11 Pass: Major Risk PB S Pad S-25AP61 S-25APB1 V2 555.91 600.00 940.66 13.32 927.34 Pass: Major Risk PB S Pad S-25A S-25A V1 438.88 450.00 944.40 7.98 936.42 Pass: Major Risk PB S Pad S-25 S-25 V1 438.88 450.00 944.40 7.98 936.42 Pass: Major Risk Schlum r • be ger Anticollision Report Company: BP Amoco Date: 3/9/2005 "Time': 10-39:38 Page: ~ i field: Prudhoe Bay Ieference Side:'- P$S Pad Co-ordinat e(NE) Reference: WeII:PIan S-111. T rue North `'Reference Well: Plan S-111 Vertical ('f' e'll) Hcference: S-111 pl an 64.1 Reference-WellpatlPJan S-111P61 llb: Sybase Summary <---------------------- Offset ~~'cllpath ----------------------> Reference Offset Cfr-Ctr Nu-Go'' Allowable Site Well ~Vcllpath MD ft MD ft DistanceArea ft ft Uc~iati ft un ~~an~it ~~ PB S Pad S-26 S-26 V1 439.24 450.00 959.73 7.26 952.47 Pass: Major Risk PB S Pad S-27 S-27 V1 439.42 450.00 991.43 8.41 983.03 Pass: Major Risk PB S Pad S-27 S-27A V3 439.42 450.00 991.43 8.30 983.13 Pass: Major Risk PB S Pad S-27 S-276 V7 438.76 450.00 991.42 8.12 983.30 Pass: Major Risk PB S Pad S-28 S-28 V4 438.95 450.00 1009.54 8.23 1001.31 Pass: Major Risk PB S Pad S-28 S-28A V1 438.95 450.00 1009.54 8.23 1001.31 Pass: Major Risk PB S Pad S-28 S-286 V2 439.90 450.00 1009.55 8.25 1001.30 Pass: Major Risk PB S Pad S-28 S-28BP61 V7 439.90 450.00 1009.55 8.25 1001.30 Pass: Major Risk PB S Pad S-29AL1 S-29AL1 V1 435.21 450.00 1181.84 8.57 1173.26 Pass: Major Risk PB S Pad S-29A Plan S-29AL2 VO Plan: 438.24 450.00 1181.89 8.41 1173.48 Pass: Major Risk PB S Pad S-29A S-29A V1 435.21 450.00 1181.84 8.57 1173.26 Pass: Major Risk PB S Pad S-29 Plan S-29B V1 Plan: S- 438.24 450.00 1181.89 8.51 1173.38 Pass: Major Risk PB S Pad S-29 S-29 V1 435.21 450.00 1181.84 8.57 1173.26 Pass: Major Risk PB S Pad S-30 S-30 V1 439.26 450.00 1069:18 7.98 1061.20 Pass: Major Risk PB S Pad S-31A S-31A V3 436.93 450.00 1109.93 7.62 1102.30 Pass: Major Risk PB S Pad S-31 S-31 V1 436.93 450.00 1109.93 7.62 1102.30 Pass: Major Risk PB S Pad S-32 S-32 V1 437.41 450.00 1284.54 10.58 1273.96 Pass: Major Risk PB S Pad S-33 S-33 V1 434.84 450.00 1133.86 7.71 1126.15 Pass: Major Risk PB S Pad S-34 S-34 V1 432.72 450.00 1341.36 7.54 1333.82 Pass: Major Risk PB S Pad S-35 S-35 V1 434.59 450.00 1368.28 7.34 1360.94 Pass: Major Risk PB S Pad S-36 S-36 V1 433.18 450.00 1423.80 7.32 1416.48 Pass: Major Risk PB S Pad S-37 S-37 V1 433.08 450.00 1449.27 7.14 1442.13 Pass: Major Risk PB S Pad S-38 S-38 V1 434.33 450.00 1257.63 7.27 1250.37 Pass: Major Risk PB S Pad S-40A S-40A V1 435.27 450.00 1486.48 7.17 1479.31 Pass: Major Risk PB S Pad S-40 S-40 V1 435.27 450.00 1486.48 7.17 1479.31 Pass: Major Risk PB S Pad S-41 L1 S-41 L1 V1 529.63 550.00 376.10 8.70 367.40 Pass: Major Risk PB S Pad S-41P61 S-41P61 V1 529.63 550.00 376.10 8.70 367.40 Pass: Major Risk PB S Pad S-41 S-41 V1 529.63 550.00 376.10 8.70 367.40 Pass: Major Risk PB S Pad S-42PB1 S-42PB1 V1 484.18 500.00 347.03 8.71 338.32 Pass: Major Risk PB S Pad S-42 S-42 V2 484.18 500.00 347.03 8.71 338.32 Pass: Major Risk PB S Pad S-43L1 S-43L1 V2 489.77 500.00 312.51 8.55 303.96 Pass: Major Risk PB S Pad S-43 S-43 V3 489.77 500.00 312.51 8.51 304.01 Pass: Major Risk PB S Pad S-44L1 P61 S-44L1 PB1 V3 492.07 500.00 285.02 8.02 277.00 Pass: Major Risk PB S Pad S-44L1 S-44L1 V5 492.07 500.00 285.02 7.97 277.05 Pass: Major Risk PB S Pad S-44 S-44 V10 492.07 500.00 285.02 7.97 277.05 Pass: Major Risk f - Field: Prudhoe Bay Site: PB S Pad _ Well: Plan 5-111 Wellpath: Plan 5-111PB1 o s-]oa(s-loa) 1a7 __ ..... 7 ............ ' . 33 ~ . ._ + • s-IC~p~ eC~b) lp .........loo _..__ _.. , , ,1 .• .. ~ .. ~. __. - 9 , ~ ~ ,, 30 , . ..., .., ~\ ,, 0 • ....50 ,. ~. ~ , . -- . \ ,,; ., ~ ., ,, 2 ~ , . , 6 11 .. ~~. \ ((( 11 12 ~`, 10' p 5-119 (S-1I9~7 p 7 , ~'.. `. 7 ,...,. ,. 0 -, 5. •. 1i 4 , 5 ~. ,r . .. \ ~1 , .`, ... _........ a _..- 5 `'fi i 5 6 a 5-107(5-10~ ,.~ _...,.., ` 20 ~~ ]L: ~ ' ......100 \ 13 ;~ ,,. ...._.._ _. _ .100._.._ ,. - 9 ., .. ~ . _.... 4 .14 ,.. • .. ~ ~ ~~ " ~ - - 8-108 (S108pB ]) 11 5-100(5-100) ~ '- _~. ~ 5-103 (5-103) . x 6 ,--~'~~ S-102 (S-]02~y~1) ~ 147 .141n P S-1C9-!'~~{~I) 180 S~IAfiQ&1P1S~Sl~r S-122PBI) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOB/in] • Site: PB S Pad Drilling Target Conf.: 95% Description: Map Northing: 5989220.00 ft Map Easting :617250.00 ft Latitude: 70°22'45.376N Polygon X ft 1 147.61 2 152.38 3 -147.61 4 -152.38 Target: S-ll 1PB1 Poly Yft -152.38 147.61 152.38 -147.61 Well: Plan S-111 Based on: Planned Program Vertical Depth: 6816.00 ft below Mean Sea Level Local +N/-S: 8515.98 ft Local +E/-W: -1545.62 ft Longitude: 149°02'48.094W MapEft MapNft 617400.00 5989070.00 617400.00 5989370.00 617100.00 5989370.00 617100.00 5989070.00 ~O ~O l0 ~0 ~O ~0 ~O V v 0~~~ D m '~ (~ u u u u u u i i ~ i i i f lu gar - ° ' WELL FIELD STRUCTURE S-111 (P7) Prudhoe Bay Unit - WOA S-PAD Magratk Paramabra Surtaca LamBOn NWl2]WOke Slab Planes, Zane Dd, U3 Feat Miarelleneoua MoCel: aGGM 2090 04: 80.849° Oabr MaY 19, 2005 Laf. N)021 21.624 N°Ming: 5980]30.34 MIS Glle Conv: x0.90988]82° Sb1: 5111 (sb118) TVD Ref: Rotary Table (fi0.10 R above MSL) Meg Dec: x24.625° FS: 5]625.9 nT Lon: W149 2 2.869 Foaling: 818839.48 ftUS Scale Fatl: 0.99991896]] Plan: 5111 (P]) Srvy Deb: May 10, 2005 9000 9500 10000 10500 11000 11500 12000 12500 13000 6500 7000 I 1 7500 ................................................................................................ 5-111 Tgt 3 Kup ..................................................... ~................ i i ......,......,.......~....,...............................e.,,..........,°..........,...........,,........., Crv BM 00 5-111 Tgt 7 Kup 5-111 Tgt 6 Kup ...........,.............:.................... ~-111 Tgt 9 Kup ,,,........,,...,........ To~ Whipstock ° ass hlpstock i Crv 8/100 End Crv S•111 Tgt 4 Kup 61100 5-111 Tg15 Kup C ' S•111 Tgt 6j Kup Fault 3 Crossin End Crv Crv SI100 Crv &100 End Crv End Crv KOP Bld 12/10 aultl Crossin Crv 61100 rv End C irv End Crv Crv BIYJIO End Crv Fault 4 CrQSSing End Crv ~ Fautt 2 Crossing 1 (P26) 90° PE 11 TD / h112" Lor '~ -111P81 (P2b) i 6500 (P7) 7000 7500 9000 9500 10000 10500 11000 11500 12000 12500 13000 Vertical Section (ft) Azim = 345.69°, Scale = 1(in):500(ft) Origin = 0 N/-S, 0 E/-W 11200 n n 10400 z O O W C II 9600 V V V 6800 6000 chlu her WE`L S-111 (P7) FIELD Prudhoe Bay Unit - WOA 9TRUDN~ S-PAD MegnMC Parameters SuAere Larati9n NAD2] Naeka Stab Pbnea, Zore Da, US Fast Miacelbneaus Maiel: eGGM 2004 DiP: 90.949° Deb: MaY 10, 2005 laf. N702121.fi24 NaM9g: 5990]30.34 flUS G~itl GOm^ +0.90986]82° SIN: 5111 Iabt 15) TVD Ref: RetarY TadeI84.tOflaOOVa MSL) Ma9 Dec: +24.625° FS: 5]825.9 nT Lan: W149 2 2.860 Ea49n9: 618930.49 M15 Srab Fed: 0.99991608]] %an: &111 (P]) Srvy Date: May 10, 2005 -7200 -6400 -5600 -4800 -4000 -3200 -2400 -1600 TO I a1lz" Lnr Edd Crv Si111 Tgt 9 Kup :Crv 6N 00 ~~ Fauh 4 Crossing ~ . ... Erid1t1 crvsllao i End Crv ~ ~;/ Sd11 Tgt 7 Kup Crv BN00 x-111 Flt 4 ault 3 Crossing End Crv "'^.~, 5-111 Tgt 8 Kupi Crv 61100 s ° / nd Crv ; 3-111 7gt 5 Kup 5111 Flt 3 '°Er3 $I'1 1 Crossing; End Crv z q ~P Ft°1... - .°° ......................°..., KOP Bld 121100/J' Base Whipstock / Top Whipstock -7200 -6400 -5600 -4800 -4000 -3200 -2400 -1600 «< W Scale = 1(in):800(ft) E »> % rv 61100 ' Fault 2 Crossing End Crv ' 5-111 Tgt 4 Kup S-111 Flt ?' End Crv/ - ,. 3.111 Tgt3K S Y • 11200 10400 9600 6800 8000 ~~, S-111 (P71 P ,a, Schlumherger Report Date: March 16, 2005 Client: BP Exploration Alaska Field: Prudhoe Bay Unit-WOA Structure I Slot: S-PAD I S-111 (slot 15) ® ® ^ Wetl: Plan 5-111 Borehole: Plan S-111 l1WIlAPYF: 50029 Survey Name 1 Date: S-111 (P7) I March 16, 2005 Tort 1 AHD 1 DDI I ERD ratio: 174.625° 115085.334 ft / 6.833° 12.188 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet location LatlLOng: N 70.35600664, W 149.03412780 Location Grid NIE YIX: N 5980730.340 ftUS, E 818930.490 ftUS Grid Convergence Angle: +0.90966782° Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 345.690° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 64.10 ft relative to MSL Sea Bed I Ground Level Elevation: 35.60 ft relative to MSL Magnetic Declination: 24.625° Total Field Strength: 57625.921 nT Magnetic Dip: 80.849° Declination Date: May 1D, 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North a True North: +24.625° Comments Measured Inclination Azimuth Subsea TVD TYD Vertical Along Hole NS EW DLS Tool Fate Build Rata Walk Rate Nodhing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft ft ft ft d 100 fl d de 100 ft de 1100 ft kUS ftUS I Op VVnIpSiOCK l"Ibb LUU Ob.UU 3bY.Z4 6tSUU.ltf bif04.Ztf tSbUU.7U ifbbJ.Jy 2f4t1Z.Jb -7647.Ub Base Whipstock 11600.00 67.08 352.24 6805.46 6869.56 8611.90 8695.27 8494,15 -1542.65 KOP Bld 12/100 11612.00 67.08 352.24 6810.13 6874.23 8622.88 8706.33 8505.10 -1544.15 11700.00 70.48 341.51 6842.06 6906.16 8704.73 8788.32 8584.82 -1562.82 11800.00 75.08 329.90 6871.75 6935.85 8798.57 8883.78 8671.63 -1602.14 11900.00 80.23 318.80 6893.19 6957.29 8889.34 8981.42 8750,79 -1659.03 12000.00 85.72 308.05 6905.45 6969.55 8973.07 9080.62 8818.84 -1731.02 90° Pt 12075.70 90.00 300.02 6908.28 6972.38 9029.53 9156.25 8861.13 -1793.65 12100.00 91.37 297.45 6907.99 6972.09 9046.11 9180.55 8872.81 -1814.95 End Crv 12153.16 94.36 291.81 6905.33 6969.43 9079.47 9233.64 8894.93 -1863.19 Fault 1 Crossing 12400.00 94.36 291.81 8886.55 6950.65 9224.55 9479.76 8986.38 -2091.69 Crv 61100 12821.19 94.36 291.81 6854.49 6918.59 9472.12 9899.73 9142.41 -2481.60 5-111 Tgt 3 Kup 12841.15 94.20 293.00 6853.00 6917.10 9484.02 9919.64 9150.00 -2500.00 End Crv 12869.37 94.05 294.69 6850.97 6915.07 9501.40 9947.78 9161.38 4525.74 Crv 61100 13332.49 94.05 294.69 6818.25 6882.35 9792.14 10409.75 9354.35 -2945.47 13400.00 91.78 298.05 6814.82 6878.92 9836.07 10477.16 9384.29 3005.86 S-111 Tgt 4 Kup 13452.66 90.00 300.66 6814.00 6878.10 9872.43 10529.82 9410.10 3051.75 End Crv 13493.75 87.53 300.65 6814.88 6878.98 9901.45 10570.89 9431.04 3087.09 Fault 2 Crossing 13700.00 87.53 300.65 6823.76 6887.86 10047.06 10778.95 9536.10 -3264.36 Crv 6/100 14057.15 87.53 300.65 6839.12 6903.22 10299.21 11133.77 9718.02 3571.32 5-111 Tgt5 Kup 14098.25 90.00 300.71 6840.00 6904.10 10328.25 11174.85 9738.98 3606.65 14100.00 90.11 300.72 6840.00 6904.10 10329.49 11176.61 9739.87 -3608.16 End Crv 14101.52 90.20 300.72 6839.99 6904.09 10330.57 11178.13 9740.65 -3609.47 Crv 6/100 15184.64 90.20 300.72 6836,28 6900.38 11096.84 12261.24 10293.94 -4540.59 15200.00 91.12 300.66 6836,10 6900.20 11107.70 12276.60 10301.78 -4553.80 5-111 Tgt 6 Kup 15204.74 91.40 300.64 6836.00 6900.10 11111.05 12281.34 10304.20 -4557.88 End Crv 15226.36 92.69 300.55 6835.23 6899.33 11126.30 12302.95 10315.20 -4576.48 Fault 3 Crossing 15650.00 92.69 300.55 6815.31 6879.41 11424.80 12726.12 10530.29 -4940.91 Crv 6/100 15868.23 92.69 300.55 6805.06 6869.16 11578.56 12944.11 10641.09 -5128.64 U.UU U.VULi U.UU U.UU byYSy723ti.4(i 16.00 O.OOG 16.00 0.00 5989198.20 0.00 -73.21 G 0.00 0.00 5989209.13 12.00 -69.31G 3.87 -12.19 5989288.53 12.00 -65.86G 4.59 -11.61 5989374.70 12.00 -63.48G 5.15 -11.10 5989452.94 12.00 -62.16G 5.50 -10.75 5989519.83 12.00 -81.86G 5.64 -10.60 5989561.12 12.00 -61.89G 5.66 -10.58 5989572.46 12.00 O.OOG 5.63 -10.61 5989593.81 0.00 O.OOG 0.00 0.00 5989681.61 0.00 97.86G 0.00 0.00 5989831.42 6.00 94.98G -0.83 5.96 5989838.71 6.00 O.OOG -0.53 5.99 5989849.68 0.00 124.OSG 0.00 0.00 5990035.95 6.00 124.22G -3.37 4.97 5990064.92 6.00 -180.OOG -3.38 4.96 5990090.00 6.00 O.OOG -6.00 -0.02 5990110.38 0.00 O.OOG 0.00 0.00 5990212.60 0.00 1.34G 0.00 0.00 5990389.60 6.00 2.78G 6.00 0.14 5990410.00 6.00 2.78G 5.99 0.29 5990410.87 6.00 O.OOG 5.99 0.29 5990411.63 0.00 -3.78G 0.00 0.00 5990950.02 6.00 -3.78G 5.99 -0.40 5990957.65 6.00 -3.98G 5.99 -0.40 5990960.00 6.00 O.OOG 5.99 -0.42 5990970.70 0.00 O.OOG 0.00 0.00 5991179.98 0.00 178.08G 0.00 0.00 5991287.76 67 /Zbb.77 N /U.3/y7 /y16 W 749.U46tibbbZ 617253.32 N 70.37921142 W 149.04666858 617251.66 N 70.37924134 W 149.04668073 617231.72 N 70,37945909 W 149.04683269 617191.03 N 70.37969623 W 149.04715247 617132.89 N 70.37991246 W 149.04761515 617059.84 N 70.38009833 W 149.04820050 616996.56 N 70.38021382 W 149.04870972 616975.07 N 70.38024572 W 149.04888293 616926.49 N 70.38030611 W 149.04927514 616696.59 N 70.38055577 W 149.05113305 616304.28 N 70.38098172 W 149.05430340 616285.77 N 70.38100243 W 149.05445301 616259.85 N 70.38103348 W 149.05466230 615837.14 N 70.38156025 W 149.05807543 615776.29 N 70.38164198 W 149.05856652 615730.00 N 70.38171244 W 149.05893971 615694.34 N 70.38176961 W 149.05922704 615515.44 N 70.38205641 W 149.06066869 615205.66 N 70.38255301 W 149.06316516 615170.00 N 70.38261023 W 149.06345253 615168.48 N 70.38261268 W 149.06346479 615167.16 N 70.38261480 W 149.06347545 614227.45 N 70.38412496 W 149.07104892 614214.11 N 70.38414635 W 149.07115637 614210.00 N 70.38415295 W 149.07118954 614191.23 N 70.38418296 W 149.07134084 813823.48 N 70.38478994 W 149.07430529 613634.01 N 70.38507229 W 149.07583246 WellOesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31rt-546) S-111 (slot 15)\Plan 5-111\Plan S-111\5-111 (P7) Generated 3/16/2005 11:15 AM Page 1 of 2 Comments Measured Inclination Azimuth Sub~Sea ND ND Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Seetion Departure ft de de ft ft ft ft ft ft d 700 ft de de 100 ft de 00 ft ftUS ftUS "iaavv.uu av./a aw.b_i bavw.va b6bb.le IIOVV.`J/ -ILy/b.bb "IVbDLZw -blbb.`J/ O.VV 1/b.VtlU -b.VV V.LU b`J713U3.w8 S-111 Tgt 7 Kup 15913.16 90.00 300.64 6804.00 6868.10 11610.27 12989.02 10663.95 -5167.30 6.00 178.SOG -6.00 0.20 5991310.00 End Crv 15924.98 89.29 300.65 6804.07 6868.17 11618.62 13000.84 10669.98 -5177.47 6.00 O.OOG -6.00 0.13 5991315.86 Crv 6/100 16625.70 89.29 300.65 6812.75 6876.85 12113.76 13701.51 11027.22 -5780.22 0.00 -178.93G 0.00 0.00 5991663.46 S-111 Tgt 8 Kup 16638.88 88.50 300.64 6813.00 6877.10 12123.07 13714.69 11033.94 -5791.56 6.00 -179.19G -6.00 -0.11 5991670.00 End Crv 16652.99 87.65 300.63 6813.47 6877.57 12133.03 13728.79 11041.12 -5803.69 6.00 O.OOG -6.00 -0.09 5991676.99 Fault 4 Crossing 17000.00 87.65 300.63 6827.68 6891.78 12377.93 14075.50 11217.76 -6102.04 0.00 O.OOG 0.00 0.00 5991848.86 Crv 6/100 17461.67 87.65 300.63 6846.58 6910.68 12703.76 14536.79 11452.77 -6498.97 0.00 -55.65G 0.00 0.00 5992077.51 17500.00 88.95 298.73 6847.72 6911.82 12730.36 14575.10 11471.74 -6532.25 ~ 6.00 -55.59G 3.39 x.95 5992095.95 S-111 Tgt 9 Kup 17530.90 90.00 297.20 6848.00 6912.10 12751.15 14605.99 11486.22 -6559.54 6.00 -55.29G 3.39 -4.95 5992110.00 End Crv 17594.60 92.18 294.06 6846.79 6910.89 12792.03 14669.69 11513.77 -6616.96 6.00 O.OOG 3.41 -4.93 5992136.63 TD/4-1/2" Lnr 18010.55 l 92.18 294.06 6831.00 6895.10 13050.02 15085.33 11683.20 -6996.51 0.00 O.QOG 0.00 0.00 5992300.00 Legal Description: Northing IY7 fftUSl Easting IX1 fftUSl Surface : 4526 FSL 4497 FEL S35 T12N R12E UM 5980730.34 618930.49 5-111 Tgt 3 Kup : 3116 FSL 1705 FEL S22 T12N R12E UM 5989838.71 616285.77 S-111 Tgt 4 Kup : 3375 FSL 2256 FEL 822 T12N R12E UM 5990090.00 615730.00 S-111 Tgt 5 Kup : 3704 FSL 2811 FEL S22 T12N R12E UM 5990410.00 615170.00 5-111 Tgt 6 Kup : 4269 FSL 3761 FEL S22 T12N R12E UM 5990960.00 614210.00 S-111 Tgt 7 Kup : 4628 FSL 4370 FEL S22 T12N R12E UM 5991310.00 613595.00 S-111 Tgt 8 Kup : 4998 FSL 4994 FEL 822 T12N R12E UM 5991670.00 612965.00 S-111 Tgt 9 Kup : 170 FSL 481 FEL 816 T12N R12E UM 5992110.00 612190.00 TD I BHL : 366 FSL 918 FEL 816 T12N R12E UM 5992300.00 611750.00 OISOUO.w3 N /U.38bl lb3/ VV lw`J.U/OVDwtlw 613595.00 N 70.38513467 W 149.07614696 613584.74 N 70.38515111 W 149.07622970 612976.44 N 70.38612587 W 149.08113336 612965.00 N 70.38674420 W 149.08122562 612952.76 N 70.38616380 W 149.08132433 612651.67 N 70.38664572 W 149,08375171 612251.09 N 70.38728682 W 149.08698139 612217.51 N 70.38733856 W 149.08725219 612190.00 N 70.38737807 W 149.08747420 • 612132.16 N 70.38745319 W 149.08794137 611750.00 N 70.38791512 W 149.09102939 WeIlDesign Ver 3.1 RT-SP3.O3-HF5.O0 Bld( do31 rt-546) S-111 (slot 15j\Plan S-111\Plan 5-111\S-111 (P7) Generated 3/16/2005 11:15 AM Page 2 of 2 • • Schlumberger Anticollision Report Company: BPAmoco Date: 3/16/2005 Mime: 11:33:14 Page: 1 E'icid: Prudhoe Bay Reference Site: PB S Pad Co-ordin;~tci A'I~:t R eference: Welly Plan S-11'1, Tr ue North Reference Wrll: Plan S-111 Vertical (Tl'D) Reference.:. S-111 plan 64.1 Reference WellpattP.lan S-111 Db: SVbase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Meth odMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 11 587.00 to 18010.55 ft Scan Method: Trav Cylinder North Maximum Radiu9A000.00 ft Error Surface: Ellipse + Casing Survey Program fo r Definitive Wellpath Date: 3/16/2005 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ft ft 28.50 1200.00 Planned: Plan #2 V1 (1) GYD-GC-SS Gyrodata gyro single shots 1200.00 11587.00 Planned: Pla n #2 V1 (1) MWD+IFR+MS MWD +IFR + Mufti Station 11587.00 18010.55 Planned: Pla n #7 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD fV D Diameter Hole Size Vame ft ft in in 4572.58 3294.10 10.750 13.500 10 3/4" 11587.00 6864.28 7.625 9.875 7-5/8" 18010.55 6895.10 4.500 6.750 4 1 /2" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD DistanecArca Deviation Warni - ft ft ft ft Ft ~ PB S Pad Plan S-111 Plan S-111 P61 V3 Plan: 11745.81 11750.00 21.78 307.79 -286.01 FAIL:- Major Risk PB S Pad Plan S-122 Plan 5-122 V1 Plan: PI 12869.37 12256.83 2255.36 238.62 2016.74 Pass: Major Risk- PB SPad Plan S-122 Plan S-122P61 V1 Plan: Out of range PB S Pad S-03 S-03 V1 12916.18 12650.00 5748.21 275.93 5472.28 Pass: Major Risk PB S Pad S-100 S-100 V10 13452.66 10500.00 6384.36 428.67 5955.69 Pass: Major Risk PB S Pad S-102 S-102 V11 15660.17 13488.00 2800.85 437.82 2363.02 Pass: Major Risk PS S Pad S-102 S-102L1 V5 15778.42 14980.00 1366.47 437.00 929.48 Pass: Major Risk PB S Pad S-102 S-102L1 PB1 V7 15731.54 14431.00 1897.43 435.14 1462.28 Pass: Major Risk PB S Pad S-102 S-102P61 V14 Out of range PB S Pad S-106 S-106 V2 17969.19 13250.00 5846.21 381.80 5464.40 Pass: Major Risk PB S Pad S-106 S-106P61 V12 Out of range PB S Pad S-107 S-107 V36 17960.91 14450.00 4355.68 436.10 3919.58 Pass: Major Risk PB S Pad S-113 S-113 V14 13400.00 9050.00 8943.28 276.43 8666.85 Pass: Major Risk PB S Pad S-113 S-113A V3 13400.00 9050.00 8943.28 276.50 8666.78 Pass: Major Risk PB S Pad S-113 S-1136 V6 13400.00 9050.00 8943.28 276.50 8666.78 Pass: Major Risk PB S Pad S-114 S-114 V13 15892.48 11850.00 7726.87 375.27 7351.60 Pass: Major Risk PB S Pad S-114 S-114A V6 17040.21 13300.00 7711.69 412.03 7299.66 Pass: Major Risk PB S Pad S-119 S-119 V7 17979.54 14250.00 2935.85 410.37 2525.49 Pass: Major Risk PB S Pad S-24 S-24 V5 Out of range PB S Pad S-24 S-24A V1 Out of range PB S Pad S-24 S-24B V2 13350.00 14155.00 6293.84 456.42 5837.43 Pass: Major Risk ~~ Field: Prudhoe Bay Site: PB S Pad Well: Plan 5-111 Wellpath: Plan 5-111 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [] OOfVin] X111 i • 2,200 HES4 1/2"'X' Hippie; I.D. =3.813" TREE= 41/16"CNV WELLHEAD = FMC ACTUATOR = KB. ELEV = 64.10' AMSL CB. ELEV = 35.60' AMSL KOP = 400' Max Angle = 96° @ 12,215' Datum MD = 11,624' Datum ND = 6,880' 10 3/4", 45.5#, L- 4,660 80, BTGM Minimum ID = 3.813" @ 2,200' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2 TBD TBD 3700 5800 59° 59° KBG-2 KBG-2 DCK DMY BK BK PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL I Opn/Sqz I DATE I 5 1/2", 17.0#, L-80, ~ I 1 ! I TGlltubing 11,345 11 345 51/2"X41/2"crossover 11,360 HES 4 1/2"'X' nipple; I.D. = 3.813" Baker 7 5/8" X 4 1/2" S-3 A-oduction Packer 11,380 11,395 HES 4 1/2"'X' nipple; I.D. = 3.813" 11,415 HES 4 1/2"'X' nipple; I.D. = 3.813" 4 1/2", 12.6#, L-80, TGlltubing 11,437 Baker 7 5/8" X 4 1/2" Flex-Lock liner hngr, 11,437 ZXP pkr, w/ TBS 13,760 Pup W/'RA' Tag 14,830 Pup W/'RA' Tag Baker Whip stock, 15,900 Pup W/'RA' Tag (Top of w indow) 11,587 0 0 0 HES 7 5/8" EZSV 11, 602 PBTD 17,945 7 518", 29.7#, L-80, 12,254 BTGM 4 1/2", 12.6 #, L-80 Hydril 521 line 18,033 DATE REV BY COMMENTS DATE REV 8Y COMMENTS 03/17/05 DEW Proposed Comp. (Wp02b, 07) PRUDHOE BAY UNff WELL: S-1111 PERMIT No: API No: 50-029- Exploration S-PAD z~ z6 25 S PAD N 1100 - ~ W N - - ~ _ I 1 I 34 35 ~ 36 cn v~ cn PROJECT N 1010 ^^^^^^^^^f^^^^^^^~fH^^- F-^ ^~- ~o AREA ~~[I ~t~p MI~,7 OD OONO.-,(7 ' M^t00 ~I' M N OO~ONOO O 0000.- N ~ ~ ~ < F. Q~ ^ N~N N N N N N VI VIN V V)V1 V V N V V V V V n V V V V ~ ~O I I I I I I ) )! I I ) l T.12N. 3 T.11N. 2 N 840 - 3 VICINITY MAP N.T.S. LEGEND AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR ~- QZ J ~. WELLS S-111 5-119 ~c S-120 RENAME NOTE THIS AS-BUILT DRAWING IS A REISSUE OF PREVIOUS AS-BUILT DRAWINGS FOR WELLS S-111, S-119 AND 5-120. S-111 WAS PREVIOUSLY ISSUED AS SLOT 15 ON JUNE 17, 2002. S-119 WAS PREVIOUSLY ISSUED AS SLOT 13 ON DECEMBER 31, 2001. S-120 WAS PREVIOUSLY SHOWN AS S-116, REISSUED AS SLOT 4 AND ORIGINALLY ISSUED AS WELL 5-103 ON JULY 4, 2000. o_ FZ-. TANK o J N o~ X ~_ p w Z O Q g NOTES: 1. DATE OF SURVEYS: (S-120 JULY 2, 2000) (S-119 JANUARY 31, 2001) (S-111 JUNE 15, 2002) 2. REFERENCE FIELD BOOKS: (S-120 Wo00-06 PGS. 1-4) (S-119 Wo01-05 PGS. 33-37) (5-111 Wo02-08 Pg. 7) 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. 6. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3 & S-4. (HELD S-4) 7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTATION. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. ~Q~E a0F o q~ ~ „ ~°°r'9 ~a`49~- °o* ooooaooooo00000000oooooaooooo00 '~.,'~o Jeffrey J. Cotton ~° ~ ' ~s LS 8306 '~ ~~ „~_ ~ESS I ONA~ ~''' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 2, 2000. LOCATED WITHIN PROTRACTED SEC. 35. T. 1 ~ N__ R. 1 ~ E.. UMIAT MERIDIAN. AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS S-111 Y=5,980,730.34 N. 1010.61 70'21'21.624" " ' 70.3560067' 35 6' 4,527' FSL ' X= 618,930.49 E. 124.60 149'02 02.860 149.0341278' . FEL 4,497 5-119 Y=5,980,699.94 N. 1,010.12 70'21'21.325" " ' 70.3559236' 36 2 4,497' FSL ' X= 618,930.01 E. 155.00 149'02 02.888 149.0341356' ' 4,498 FEL S-120 Y=5,980,564.33 N. 1,010.27 70'21'19.991" " ' 70.3555531' 8 35 4,361' FSL ' X= 618,930.21 E. 290.63 149'02 02.945 149.0341515' ' 4,500 FEL (~ CHECKED: LOH j~ ~N 0 I ,I I ~ DATE: ffj NN ~~UJn ~'~ DRAVANG: SHEET: _y~ FRB03 WOA-S 02-00 WOA S-PAD ~ `~~~OO ~o JDB ND. RENAMED AS-BUILT CONDUCTORS ,,,o ~„~ ~,,,~,~ scA~E: 1 ov 1 <;;~~„~EO u„E ~•= 1so~ WELL S-111, S-119 & S-120 ~4Q4~ O~ ° ° gG~l DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS CERTIFIED MAIL RETURN RECEIPT REQUESTED February 8, 2005 Gil Beuhler West End Satellite Team Manager BP Exploration (Alaska), Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 H. MURKOWSSI, GOVERNOR 550 WEST T~ AVENUE, SUITE 800 ANCHORAGE, ALASKA 98501560 PHONE.• (907) 269-8800 FAX.• (907) 289-8938 RE: Preliminary Approval Application to Expand the Prudhoe Bay Unit and the Aurora Participating Area Dear Mr. Beuhler: On March 25, 2004, BP Exploration (Alaska) Inc. (BPXA), as a Working Interest Owner (WIO) and Unit Operator of the Prudhoe Bay Unit (PBU), and on behalf of Chevron U.S.A. Inc., ConocoPhillips Alaska, Inc., ExxonMobil Alaska Production Inc. and Forest Oil Corporation, submitted an application to the Department of Natural Resources, Division of Oil and Gas, (Division) to expand the PBU and the Aurora Participating Area (APA) (Application). The proposed PBU expansion area included approximately 1,120 acres within two leases, and the proposed APA expansion area included approximately 2,240 acres within seven leases. Following discussions between the WIOs and the Division, BPXA revised the Application. The revisions are reflected in three Attachments to this decision. Attachment 1 is a map of the revised PBU and APA expansion areas. The revised PBU expansion area (the map's crosshatched areas) includes approximately 1,040 acres within two leases-ADCs 28256 and 390080. The expanded PBU will include a total of all or part of 1101eases and approximately 248,677 acres. The current APA includes portions of seven leases for a total of approximately 7,520 acres. The revised APA expansion area (the map's crosshatched and green-colored areas) includes all or portions of nine leases and approximately 10,480 acres. Attachment 2 is a revised APA tract allocation schedule. And, Attachment 3 memorializes a conceptual agreement between the Division and the WIOs on the makeup of the expansion areas and BPXA's work commitments in the expansion areas: "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." • • Mr. Gil Beuhler PBU and APA Expansion, Preliminary Approval February 8, 2005 Page 2 In addition to the agreement on expansion areas and work commitments, the Division and WIOs also agreed, that the 1980 Prudhoe Bay Royalty Settlement Agreement (RSA), and therefore a field cost deduction, will apply to 1) all production allocated to the APA expansion areas within the PBU at the time of the Application (the green-colored areas set out in Attachment 1); and 2) all production allocated to Section 22 of ADL 28256 (PBU Tract 11) and ADL 390080 (PBU Tract 118) because these lands were within the PBU on the effective date of the RSA. However, the RSA will not apply to Sections 15 and 16 of ADL 28256 (PBU Tract 11) because these lands were not within the PBU on the effective date of the RSA. Furthermore, because BPXA timely drilled and completed the 5-119 well as a production well, and commenced production on December 30, 2004, 20.832 percent of the production allocated to ADL 28256 (PBU Tract 11), or 5.308 percent of the total APA production, is not subject to a field cost deduction under the RSA. This calculation represents production from the 5-119 Area within Sections 15 and 16 of PBU Tract 11, as set out in Attachment 1. Similarly, if BPXA timely drills and completes the 5-111 well, then 33.334 percent of the production allocated to ADL 28256 (PBU Tract 11), or 8.493 percent of the total APA production, will not be subject to a field cost deduction under the RSA. This calculation represents production from the S-119 Area as described above and the 5- 111 Area within Sections 15 and 16 of PBU Tract 11, as set out in Attachment 1. The Division deemed the revised Application complete on August 3I, 2004, and arranged to begin public notice on September 9, 2004, in the Anchorage Daily News and Arctic Sounder under 11 AAC 83.311. Copies of the public notice were also provided to. interested parties under that regulation. These parties included the North Slope Borough, Arctic Slope Regional Corporation, the Alaska Department of Environmental Conservation, the Alaska Department of Fish and Game, the Alaska Department of Natural Resources, Division of Land, and the Alaska Oil and Gas Conservation Commission. The public notices invited interested parties and members of the public to submit comments by October 11, 2004. The revised Application was properly noticed in the Arctic Sounder on September 9, 2004, but did not appeaz in the Anchorage Daily News. This omission was corrected on November 19, 2004, when the revised Application was published in the Anchorage Daily News. The thirty-day public comment period for the notice published in the Anchorage Daily News closed on December 20, 2004. The Division received no comments regarding the revised Application during the two thirty-day public comment periods. The Division reviewed the statutes, regulations, Prudhoe Bay Unit Agreement, and the materials supplied by BPXA in support of the revised Application. The revised Application meets the criteria set out in 11 AAC 83.303. Approval of the revised Application is necessary and advisable to protect the public interest because it promotes the conservation of all natural resources, promotes the prevention of economic and physical waste, and provides for the protection of all parties, including the state. • • Mr. Gil Beuhler PBU and APA Expansion, Preliminary Approval February 8, 2005 Page 3 The Division is issuing this preliminary decision today to comply with the provisions of 11 AAC 83.316(a), which provides that the commissioner will issue a written decision on a unit expansion within 60 days after close of the public continent period. The Division will issue a final, appealable decision fully analyzing the criteria set out in 11 AAC 83.303 by April 15, 2005. Article 5.4 of the PBU Agreement provides that a revision of a participating area will be effective on the first day of the month following approval by DNR or any other date agreed to by DNR and the Unit Operator, acting on behalf of the WIOs. The Division and BPXA have agreed that the effective date of this Seventh PBU expansion, First APA expansion, and the revised APA tract allocation schedule is October 1, 2004, which is the first day of the month in which ADL 390080 was set to expire under the March 15, 2004 Letter Agreement between BP Exploration (Alaska) Inc. (BPXA) and the Department of Natural Resources (DNR) regarding the severance of ADL 28255 and creation of ADL 390080. Mark D. Myers, Director Date Division of Oil and Gas Attachments: 1) Map of the PBU and APA Expansion Areas 2) APA Tract Participation Schedule 3) Conceptual Agreement regarding the March 25, 2004, PBU and APA Expansion Application cc: AOGCC Gary Gustafson, BPXA Jeff Landry, ADOL PBU APA_Expansion_PreliminaryDecision 2.8.05 Prudhoe Bay Unit and Aurora Participating Area egend PBU and APA Expansion APA Expansion Current Aurora ParticfpalVng Area • (APA) 5-111 Area S-119 Area 0 Sta'.ute Miles Attachment 1 Alaska O~ and Gas Conservation Commission -Conservation Orde... http://www.state.ak.us/local/akpages/ADMIN/ogc/orders/co/co400_... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 August 9; 2004 Ta: AOGCC native distributian {ist Re: Carrectian to Canservatian Order Na. 4578 Nat infrequent{y, the Carnmissian amends a Canservatian arder that prescribes pao{ rules far a specific poal. Far ease of reference and to minimize canfusian, it has been the Commissian's recent practice to inCarparate such amendments firam time to time in a camprehensive{y revised versian afi the under{ying Canservatian arder that supersedes and rep{aces the previaus versian of the arder. This ensures that all app{icabie peal rules are set aut in a single dacument and avaids the necessity of reviewing a{tiple arders re{ating to a single peal. On June 25, 2004, the Cammsssian issued such a camprehensive{y revised arder prescribing pea{ rules for the Aurara Oil Paa{, in the farm of Canservatian Order Na. 4578. One of the saurCes of amendments to the previaus versian of this arder was Canservatian Order Na. 492, which estab{ished rules gaverning sustained annulus pressures far all peals within the Prudhae Bay Fie{d, including the Aurora Oil Poa{. Canservatian Order Na. 4578 stated that it "supersedes and replaces CO 457 dated September 7, 2001, CO 457A dated May 15, 2003; and CO 492 dated June 26, 2003." Since CO 492 affects ether pea{s in the Prudhae Bay fie{d in additian to the Aurara Oil Pao{, this statement is not carreCt. Canservatian Order Na. 4578 supersedes and rep{aces CO 492 an{y insafar as CO 492 Caneerns the Aurora Oil Pao{. Canservatian Order Na. 4578 has no effect on CO 492 as to any ether peals. Canservatian Order Na. 4578 has been CarreCted acCarding{y. A Capy of the carrected versian is attached. Sincere{y, Jahn K. Harman Chairman Re: TF-iE APPLICATION OF BPXA FXPLORATIflN (ALASKA} INC. far an arder expanding the affected area of the Aurara Oil Poal, Prudhae Bay Fie{d, Narth S{ape, Alaska IT APPEARING THAT: Canservatian Order Na. 4578 Prudhae Bay Fie{d Aurara Oii Paal June 25; 20U4 Corrected August 9, 2004 1. BP Exp{aratian (Alaska), Inc. ("BPXA") by applicatian dated March 26, 2004, applied far expandian of the affected area for the Aurara Oil Paa{ ("AOP") ru{es as defined in Canservatian Order ("CO°) Na. 457A, 2. BPXA pravided supp{emental {nfarmatian at the Cammissian's request an April 12, 2004; 3. Native of a pub{ic hearing, tentatively sChedu{ed far May 6, 2004, was duly published in the Ancharage f7ai{y News an Apri{ 2, 2004; and 4. Na requests far hearing ar ojectians canCernin the application were received. FINDINGS: 1. CO 457A defines the AOP and sets out rules gaverning its develapment and operatian within a specified 1 of 5 3!25/2005 10:19 AM Alaska Oil and Gas Conservation Commisssion -Conservation Orde... http://www.state.ak.usllocaUakpages/ADMIN/ogc/orders/co/co400 ... • • area. 2. BPXA proposes to expand the operation and development of the pool beyond the area specified in CO 457A. 3. Subsurface wireline log data, pressure measurements, and newly reprocessed seismic data all indicate that the AOP exfiends beyond the area specified in CO 457A to encompass the additional area proposed for development. 4. No reason appears why the rules set out in CO 457A should not also apply to operation and development of the AOP in the additional area proposed for development. 5. CO 492 establishes requirements for managing annular pressures for all pools within the Prudhoe Bay I"ieid, including the AOP. No reason appears why the requirements established in CO 492 should not be integrated into a single conservation order governing the AOP. 6. Administrative Approval ("AA") 457A.01 was issued to clarify requirements for maximum allowable annular pressure. No reason appears why the provisions of this Administrative Approval should not be integrated into a single conservation order governing the AOP. 7. AA 457A.02 permanently approved the use of the Prudhoe Bay Unit Western Satellite Production Metering Plan for production allooation and set out reporting requirements under this plan. hlo reason appears why the provisions of this Administrative Approval should not be integrated into a single conservation order governing the AOP. CONCLUSIONS: 1. The area subject to pool rules governing the development and operation of the AOP should be expanded to encompass the additional area proposed for development and indicated by subsurface well data, newly reprocessed seismic data: and reservoir pressure data acquired to date as being within the AOP. 2. All rules and approvals issued by the Commission for AOP operation and development should be consolidated into a single conservation order. 3. The record for this order includes the hearing records and administrative files related to Conservation Orders 457, 457A and 492 including administrative approvals issued under those orders. NOW, THEREFORE, {T IS ORDERED: This Conservation Order supersedes and replaces CO 457 dated September 7, 2001, CO 457A dated May 15, 2003, and - as to the Aurora Oil Pool only - CO 492 dated June 26, 2003. The findings, conclusions and administrative record for Conservation Orders 457; 457A and 492 are adopted by reference and incorporated in this decision. The following rules, in addition to statewide requirements under 20 AAC 25, to the extent not superseded by these rules; apply to the Aurora Oil Pool within the following affeoted area: Uiat Meridian Township Range, UM Sections T11-R12E Sec 2: W1J2 Sec 3: Ail Sec 4: 1=1J2, IVW 1J4, 112SW1I4 Sec 5: 112RIE1J4 Sec. 9: NE114. N1J2S1J4 Sec 10; NWIJ4SW1J4. W1J2W1/4 T12N-R12E Sec 15: S1J2SE1J4. SW114 Sec 16: RIW1J4, S1/2 Sec 17: S1J2, NE1J4 Sec 18: SE1f4 Sec 19: N112 NE1i4 Sec 20; E112, 1J2NW1/4 Sec 21: All Sec 22: A1I Sec 23: S1J2, S1/2NW134,S1/2NE114 2 of 5 3/25/2005 10:19 AM Alaska Oil and Gas Conservation Commisssion -Conservation Orde... http://www.state.ak.us/IocaUakpages/ADMIN/ogc/orders/co/co400_ • Sec 25; S112, S112NW114 Sec 26, All Sec 27: All Sec 28: All Sec 29: E1/2NE1/4. SE1I4 Sec 32: E112 Sec 33: Ali Sec 34: All Sec 35: All Sec 36: All Buie 1. VNeli Spacing tC0457, 9171011 Spacing units within the pool shah be a minimum of 4Q acres. 20 ARC 25.Q55(a)(1) and {2} shah not apply to property lines within the external boundaries of the Aurora Participating Area. Rule 2. Casin and 0ementin Practices 00457 917101 a. In addition to the requirements of 20 AAC 25,030, the conductor casing must be set at least 75 feet below the surface. b. In addition to the requirements of 2Q AAC 25.Q30, the surface casing must be set at least 5t}0 feet tvdss below the permafrost, Rule 3, Automatic Shut-in Bauipmet (00457, 917!011 a. All wells r~€ust be equipped with alai!-safe automatic surface safety vaive system capable of detecting and preventing an uncontrolled flow. b. Ai! wens must be equipped with a landing Hippie at a depth below permafrost, which is suitable for the future installation of a downhole flow control device to control subsurface flow. The Commission may require such installation by administrative action. c. Safety vaive systems must be maintained in good working order at all times and must e tested a minimum of once each six months ar according to such other schedule as is prescribed by the Commission. Rule 4. Common Pr+adction Facilities and Surface Common iin 457.02 9111103 a. The PBU Western Satellite Production fVletering Plan, approved by the Commission in CO 471 effective August 1, 2QC32 governs satellite production within the Western Operating Area of the Prudhoe Bay Unit, including the Aurora Oil Pool. b. The Prudhoe Bay Unit Gathering Center 2 wail allocation factor for oil, gas, and water shall be applied to adjust total AOP production. c. All wells must e tested a minimum of once per month. All new AOP wells must be tested a minimum of two times per month during the first three months of production. The Commission may require more frequent or longer tests if the allocation quality deteriorates. d. Technical process review meetings with the Commission shall be held at least annually. e. The operator shall submit a monthly report and file(s) containing daily allocation data and daily test data for the Commission`s review and evaluation. Rule 5. Reservoir Pressure Monitoring (00457, 9171011 a. Prior to regular production or injection, an initial pressure survey steal! e performed in each well. b. The minimum number ofi bottom-hole pressure surveys performed each year shalE equal the number of governmental seotions within the AOP that contain active wells, A minimum of four such surveys shall be conducted each year in representative areas of the AC3P. Bottom-hole surveys conducted pursuant to paragraph "a" of this Rule may be used to fulfill the minimum requirement. c. The reservoir pressure datum will be 6,7(?0 feet tvdss. d. Pressure surveys maybe stabilized static pressure measurements at bottom-hole or extrapolated from surface (single phase fluid conditions), pressure fall-off, pressure buildup, multi-rate tests, drill stem tests, and open-hole formation tests. e. ~3ata and results from all reservoir pressure monitoring tests on surveys must be reported to the 3 of 5 3/25/2005 10:19 AM Alaska Oil and Gas Conservation Commission -Conservation Orde... http :1/www.state. ak.usllocaUakpages/ADMINlogciordersJco/c 0400 ... Commission quarterly on Form '€0-412, Reservoir Pressure Report. Ai[ data necessary for analysis of each survey need not be submitted with the Form 10-412, but shall be available for inspection by the Cornrnission upon request. Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with paragraph "e» of this Rule. Rule 6. Gas-Qil Ratio Exern~tion (00457, 9171011 Wells producing from the AOP are exempt from the gas-oil-ratio limits of 20 AAC 25.240 {a) so long as the requirements of 20 AAC 25.240 {b) are met. Ruie 7. Enhanced Qil Recove or Reservoir Pressure Maintenance O eratinns C®457A, 5115103 Water and enriched hydrocarbon gas injection are authorized to enhance oil recovery within the ADP, Average reservoir pressure must be maintained above minimum miscibility pressure. 'Expansion of miscible gas injection outside of the North of Crest and West Blocks must be administratively approved by the Commission prior to long-term injection. Commission approval is required prior to implementing major changes in reservoir depletion strategy, Ruie 8. Reservoir Surveillance Re ort and C7e letion Plan U date C®457A 5115103 An annual reservoir surveillance report for the prior calendar year shall be filed with the Commission after one year of regular production and annually thereafter. The report shall include, but is not limited to, the following: a. Progress of enhanced recovery project implementation and reservoir management summary including results of reservoir simulation techniques; b. Voidage balance by month of produced fluids and injected fluids and cumulative status by major fault blocks; c. Summary and analysis of reservoir pressure surveys within the pool; d. Results, and where appropriate, analysis of production and injection log surveys, tracer surreys, observation well surveys, and any other special monitoring; e. Review of pool production allocation factors and issues over the prior year; and f. Review of the Annual Plan of rperations and Development including discussion of the reservoir depletion plan and the current status of reservoir repressurization activity. Rula 9. Production Anomalies CC?457 917101 In the event of oil production capacity proration at or from the Prudhoe Bay unit facilities, all commingled reservoirs produced through the Prudhoe Bay Unit facilities shall be prorated by an equivalent percentage of oil production, unless it is determined by the Commission that this will result in surface or subsurFace equipment damage. Rule 10. Administrative Actitsn (CQ457, 9!71011 Upon proper application or its own motion, the Commission may administratively waive the requirements of any ru{e stated above or administratively amend this C7rder as long as the change does not promote waste or jeopardize correlative rights, and is based on sound engineering and geoscience principles. Rule 11, Weil (Mechanical lntgri and Annulus Pressures (Cfl492, 5!26103 and AA4~7.01~ 71291031 a. The operator shall conduct and document a pressure test of tubulars and completion equipment in each development well at the #ime of installation or replacement that is sufficient to demonstrate that planned well operations will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. b. The operator shall monitor each development well daily to check for sustained pressure, unless prevented from doing so by extreme weather conditions, emergency situations, or similar unavoidable circumstances. 1111onitoring results shall be made available for AQGCC inspection. c. The operator shall notify the AOtaCC within three working days after the operator identifies a well as having {i) sustained inner annulus pressure that exceeds 20900 psig or {ii}sustained outer annulus pressure that exceeds 1000 psig. d. The Commission may require the operator to submit in an Application for Sundry Approvals {Form 4 of 5 3!2512005 10:19 AM Alaska Oil and Gas Conservation Commisssion -Conservation Orde... http://wwwstate.ak.usllocaUakpageslADMIN/ogc/orders/co/co400_... 10-403}: a proposal for corrective action or increased surveillance for any development well having sustained pressure that exceeds a limit set out in paragraph c. of this rule. The Commissian may approve the operator's proposal ar may require ether corrective action or surveillance. The Commission may require that carrective action be verified by mechanical integrity testing or other Commission approved diagnostic tests, The operator shall give the Commission sufficient notice of the testing schedule to allow the Commission to witness the tests. e. If the operator identifies sustained pressure in the inner annulus of a development wail that exceeds 4a°fo of the burst pressure rating of the wen's praduction casing for inner annulus pressure; or sustained pressure in the outer annulus that exceeds 45°I° of the burst pressure rating of the wail's surface casing for outer annulus pressure, the operator shall immediately notify the Cammission and take corrective action. Unless well canditions require the operator to take emergency corrective action before Commission approval can be obtained, the operator shall submit in an Application for Sundry Appravais {Form 10-403} a proposal for corrective action. The Commissian may approve the operator's proposal or may require other carrective action. The Cammission may also require that corrective action be verified by mechanical integrity testing or other Cammission approved diagnostic tests. The operator shall give the Commission sufficient notice of the testing schedule to allow the Gammission to witness the tests. f. Except as otherwise approved by the AOGCC under paragraph "d' or °e" of this ruse, before ashut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree that (i} the inner annulus pressure at operating temperature will be belaw 2000 psig, and (ii} the outer annufus pressure at operating temperature will be below 'i000 psig. However, a wail that is subject to paragraph "c'>, but not paragraph °e", of this rule may reach an annufus pressure at operating temperature that is described in the operator's notifioation to the AOGCC under paragraph "c" unless the AOGCC prescribes a different limit. Rule 12. Definitions For purposes of these rules; a. `inner annulus' means the space in a well between tubing and production casing; b. "outer annulus" means the space in a well between production casing and surface casing; e. "sustained pressure" means pressure that (i} is measurable at the casing head of an annulus, (ii} is not caused solely by temperature fluctuations, and (iii} is not pressure that has been applied intentionally. DONE at Anchorage, Alaska and dated June 25; 2004. Corrected August 9, 2004 John K. Rlorman, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount; Jr., Commissioner Alaska ®il and Gas Conservation Commission Conservation ~rder{ndex Hama l~Jebmaster 5 of 5 3125/2005 10:19 AM TERRIE L RUBBLE BP EXPLpRgT10N qK ANCH X 196612.. MB ~ ORAGE, ,qK, 9 5 NC "Mastercard Ghe ss-sii~52 9519-6612 ck 1$$ ORDER OFHE DATE 3 2 First National. Bank W $ ~ Anchorage, AK 9 Alaska. ' 9501 MEMO ,.. _ w `~ , ~• 1 2S `~~~601' 622?,„1556~~~ pi8 B • • i • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~,~~~~~~~ / PTD# ~? ~_~~ C~.~ ~ Development Exploration Service Stratigraphic CHECK WAAT ADD-OHS "CLUE"• APPLIES OPTIONS • MULTI ~ The permit is for s new wellbore segment of LATERAL eYisiiag well _• Permit No, ~ API No. (If API number Production.sbould continue to be reported as last two. (2) digits a function'of the original API number stated are between 60-69) above. PII,OT HOLE In accordance vrith ~ 20 AAC Z5.005(f}, all CPS records, data and toga acquired. for the pilot - hole must be clearly differentiated 'in both • name (name on permit plus PH) and API Dumber ( ______ ?0/80) from records, data sad logs acquired . for well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliance with 20 AAC 2S.OSS. Approval to ^!~ ~ ~ 11 I ~ /~ ' ` perforate sad produce is contingent upon conservation order approving s i f ' ~ ssuance o a ~ Z ~ aJ ~~~ ,spacing a=caption. . ~,Companv Hamel assumes ibe liability of any ~ - ~ protest to the spacing .eiception that may ~~~ , / ~ ~ occur. DRY DITCH All dry ditch sample sets submitted !o the SAMPLE Commission must be in no greater than 30' . sample intervals from below the permafrost - or from where samples are first caught and . I O' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, AURORA OIL- 640120 Well Name: PRUDHOE BAY UN AURO S-111i Program SER Well bore seg ^ PTD#:2050510 Company B_ P~PLORATION (ALASKA) INC Initial ClasslType SERI 1WINJ GeoArea _ Unit On/Off Shore On Annular Disposal ^ Administration 1 Permit_fee attached _ . _ _ - - - - _ - _ , Yes _ - _ 2 Lease number appropriate_-____--___-____------------ -------_Yes___-_ -- 3 Unique well-name and number _ _ _ _ _ _ _ _ ~ _ ~ _ _ _ ~ _ _ .Yes _ _ _ _ _ _ _ ~ - - _ _ _ _ _ - - _ - ------------------------------------- 4 Well located ina_defnedpoof________________ _____________ ___- --Yes_-___._ -_-_ ~5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - - - - - -Yes _ The permitform idicates this weq will cross-the Auora PA and PBU boundaries. The attached documentation- ~6 Well located proper distance-from other wells- _ - - Yes - - - - is a preliminary approval by-QNR of and expansion of both the Aurora PA-and PBU, The final approv_al_follows - - ~7 Sufficient acreage available in_d_rilling unit_ - _ - Yes - - _ - a public comment period. The basis for the_expansion is film and-i8 based on well-and seismic data documenting 18 If deviated, is.wellborep/at-included - - Yes - _ the productive_area of the-pool._ We used the-same information in writing pool rules and an AIO for this pool. _ - - . i9 Operator only affected party. - - - . - Yes 7he,pool rules, AIQ, PA and unitn_ow share common_boundaries -RPC - - - - _ - j 10 OpQratoChas_appropriate-bond inforGe________________________ _________Yes_----_- .---.---_-_----_ 11 Permit_canbeissuedwithoutconservationorder___________________ _____-_Yes___-__ ____--__--_- Appr Date ` 12 Permitcan be issued without adminietrativ_e_appr_oYal - - - - - - - - - - - - - -Yes - - _ - RPC 3/3112005 13 Can permit be approved before 15-day wait Yes X 14 Well located within area and_strata authorized by Injection Order # (put 10# in-comments)-(For- Yes - AIQ22-No-wells withinthe AQR for this-well-RPC_ - - - - - - _ _ % 15 All wells within114_milearea-ofreyiewidentified(Forservicewellonly)______ _________Yes--_._._ ,__-__--___._.-,_.-._-_-_-.-.-.-.-_-_-.- _., __ __ 16 Pre-produced injector; duration of pre production less than 3 months_ (For_se[vice well_ only) NA_ - _ - _ - - - - - i -- 17 ACMP_Finding of Gonsistency_has been issued_for_this project - - - - - - - - - - - - - - NA_ - _ - - - - - - - - _ - - - Engineering ~ 18 Conductorstring_provided_-__--_____________________-_ -_-__--_-Yes__-_--_ 20''011.0'.__; : _--_ - - , 19 Surface casing protects ail known USDWs _ - Yes - i 20 CMT vol-adequate_to ci[cufate,on conductor & surf csg - _ . - - - - _ Yes Adequate excess - - 21 CMT_vol-adequate_totie-inlongstring tosuricsg__________________ _.__-__No-_-_._._ -_-_-___ -_ 22 CMT_willcoverallkno_wn_pto_ductiyehorizons_-________ _________ _________Yes_____- _-___-_-___ 23 CasirlgdesignsadequateforC,T,6&permaf[ost _---_ _-_._ Yes_---_ _ _ _ -_-__-__ -- _-_ _-__ -_ --- - --- ^ --__ - 24 Adequate tankage-or(eservepit_- __ Yes-_--__- Nabo[s]ES_________________________-___-_____-__- 25 If a_ re-drill, has-a 10-403 for abandonment been approved _ - - - - - - . - NA_ _ . - - - New welt, _ - - - - 26 Adequatewellboreseparation-proposed--_____________________ _________Yes_,_,_-. _- 27 If diverter required, does it meetregulations- - - - - - - Yes - - - - - - - - ~ - - - - - Appr Date 28 Drillingfluid-programschematic.&equiplistadequate-------------_ ---__-,-_Yes_-___- Max MW-11,0_ppg.--_-_----_--._--__------_-._-_-_---_-_--_--,___-_-_--_- WGA 3/31!2005 X 29 BOPES,_do they meet regulation - - - - - Yes - - - - - - ~ 30 BO_PE_press rating appropriate; test to-(put psig in comments)- - - - - - - - - - - - - - - -Yes _ - - - - Test t_o 4000 psi. _MSP 23.95 psi._ - - _ - - _ - - - 31 Choke_manifoldcompliesw/API RP-53 (May 84)-__-__--____- _- _-_-_-___Yes_______ ___________--___-_-___ - - 32 Work willoccurwithoutoperationshutdown-__-__-__.-_-___--- -_----__Yes____-_ -_-_-__-,--_-___- -__-_ 33 Is presence-ofH2S gas probable__--__-_.__ --_-_____-- _-_._-_._ No,_____- Not anH2$pad.___-___-__-~_,_ - - - - ~ 34 Mechanical condition of wells within AOR verified (FOrs_e[vice wel_I onlya Yes - - - - - - No wells within AQR.- - _ - _ _ - - - - - i Geology , 35 Permit_can be issued wlo hydrogen_sulfide measures _ - - - - _ - Yes - - -'- - - -- - - - - - - - - - - _ - --------------------------------------------------- 36 Data_presentedonpotentialoyerpressur_ezones__________________ --,_-_.__NA--_-___- _-___-_-___ - - Appr Date 37 Seismic_analysisofshallowgaszones-------------------_.-_- _-------_NA_-_-_-_ - - _--__-_-_ - - - RPC 312512005 38 Seabedcondjtionsurvey_(ifoff-shore)____________ __________ _________ NA,___-_ - - __-_-__- - - - - 39 _ Contact na_melphone_for weekly progress-reports jexplorat_ory only]- ~ _ - - - - - NA- _ - _ _ - - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Com one Date ~~ ~^ ~~ V - - Q,j / ~- 4 ~ ~~~ s-A •
