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180-068
fl cit.,alh/CLJ ' STATE OF�LASKA OIL AND GAS CONSERVATION COMMIS• JAN 2 6 2018 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed i\0 3 c c Abandon 0 Plug Perforations ❑ 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 I1 Re-enter Susp Well 0 Other:OA Well Lock Squeeze El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 180-068 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20485-00-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number: PBU H-11 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9875 feet Plugs measured feet true vertical 9464 feet Junk measured 9818 feet Effective Depth: measured 9789 feet Packer measured 8285/8329 feet true vertical 9381 feet Packer true vertical 7948/7988 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32-112 32-112 Surface 2664 13-3/8" 31-2695 31-2695 4930 2670 Intermediate 8916 9-5/8" 29-8942 29-8564 6870 4760 Production Liner 1482 7" 8391-9873 8045-9462 8160 7020 Perforation Depth: Measured depth: 9136-9304 feet feet True vertical depth: 8749-8910 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2",13Cr80 27-8440 27-8092 Packers and SSSV(type,measured and 4-1/2"Bkr S-3 Packer 8285 7948 true vertical depth) 4-1/2"TIW HBBP Packer 8329 7988 12.Stimulation or cement squeeze summary: Intervals treated(measured): 31'-40'inside OOA @ Surface,between Conductor and Surface Casing �� �� , ( I ' , b Treatment descriptions including volumes used and final pressure: 21 Gallons 13.9 ppg SqueezeCrete Cement,2000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 300 4472 2364 620 274 Subsequent to operation: 300 4877 2792 1453 326 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.2831 15.Well Class after work: Daily Report of Well Operations IZI Exploratory 0 Development Q Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil II 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: 317-368 Authorized Name: Shriver,Tyson Contact Name: Shriver,Tyson Authorized Title: Well Interventio Engineer Contact Email: Tyson.Shrivernbp.com Authorized Signature: 7-2._ Date://,,:2 6/ f g Contact Phone: +1 9075644133 Form 10-404 Revised 04/2017 Vii..- 3/) / t s, Submit Original OnlybPD -SU,1 IV.: 2 ly LV18 /h • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary January 25, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for an Outer Annulus Squeeze covered under Sundry Application # 317-368 for Well H-11, PTD # 180-068. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. 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O E ll O = II O co o ll O P b ll O 2 II O < II O ® I I a 0 > "."- 2 > - o \ > - S ® > o 0 > - 0 > - 2 > a & .E @ & m m & 2 > m A = .g $ A .R m & « m A co m w w ¥ N- ¥ w N- ,- \ \ d - N 0 n in w a 6 g % N N e e N N Q R 0 TRS_ ' MCEV OY • ELLFEAD= MCV galSAF/ NOTES: `*'4-1i2"CHROME TBG'*' ACTUATOR= OTIS Fl KB.B.EV= 76.49' BF,ELEV= 4729' I - I KOP= 3200 20"CONDUCTOR H 110' 1746' 1-19-5/8'HES ES(3 ITB2 Max Angie= 22°@I 8300' Datum MD= 9269' ' ' 2126' H4-1/2"HES X NP, D=3.813' Datum TVD= 8800 SS — — 2908' 9-5/8"OV PKR L9-518'CSG,47#.L-80 HYD 563,1D=8.681' H 1763' / , GAS LFT M IMJt S 13-3/8*CSG,72#,L-80 BUTT,D=12.347' H 2700' ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3250 3246 13 MAG DONE RK 16 11/04/15 U 3 5116 4992 21 MMG SO RK 20 11104/15 2 6721 6486 22 MMG DAY RK 0 08/12/08 1 7802 7498 20 WIG DAY RK 0 08/12/08 Minimum ID =3.725" (d? $242' , ' 8134' - 41/2"Nes x NP,D=3.813" 4-1/2" HES XN NIPPLE X v ~ 8155' H9-5/8"X 4-1/2'BKR S-3 PKR,D=3.873' I , 8179' H4-1/2"HES X NP,0=3.813' ' 8242' H4-1/2"HES XN NP,D=3.725' 4-1/2'TBG 128#,13CR-80 VAM TOP, —{ 8263' �� 4152 bpf,D=3.958' 1 18279` _--{9-5/8"X 4-1/2'UNDUE OVERSHOT 4-i/2'TBG STUB(07115108} H 826T 8284' H BKR ANCHOR LATCH ASSY,D=3.95' X8285' H9-5/8'X 4-1/2'TNV HBBP PKR,D=3.875" X J 8289' 5-1/2"MI-LOUT EXTENSION,ID=4.91" _--------1 8294' H5-112- X 4-1/2'XO,D=3.958' ' 8321' H41/2"OTIS X NP,D=3.813' TOP OF T LAIR H 8391' CR ' 8428' H41/2"ORS XN NP,D=3.725" 4-1/2"TBG 12.65,13 -80 FOX, 8440' / I 8440" H4-112''V4LEG,D=3.958' .0152 bpf,ID=3.958' L 8431' HE.MD TT LOGGED 11/11/92 9-5/8'CSG,47#,L-80 BUTT,D=8.681" i-- 8942' , PERFORATION SUMMARY REF LOG: SVVS-BHCS ON 09/14/80 I ANGLE AT TOP PERF: 16'a 9136' Nob:leer he R-eduction DB for historical perf data I SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 9136-9146 O 04/19/90 3-3/8" 6 9156-9192 0 04/19/90 I 3-1/8' 8 9206-9244 0 05/08181 3-1/8" 4 9254-9265 0 05)08/81 9262' HT MARKER JOINT 3-1/8" 8 9286-9304 0 06/14/81V - ??? I--FISH-3-3/8"BAKER F3P(01/05/08); .••.•.•.'•41 08/21/08:FPI BELOW SAND TOP l •••••• •,•,•,o, PBTD —{ 9830' 'x.7.0 .•,•,. ....-.7.0 . 1�l�!'!�!�AY !!!!!!!4 !! !!!!! T Lf4{29#,L-80 BUTT,.0371 bpf,D=6.184" H9873' "".."`""*.! DATE REV BY COMMITS DATE REV BY COMMENTS PIRUDHOE BAY UNIT' 09/19/80 E22 ORIGINAL COMPLETION 12/11/15 JLS/JMO GLV CJO(11/04/15) WELL: H-11 01/07/92 D16 18NO 12/11/15 JLS/JMD PULLED PXNRUG(11/05/15) l fTNo:'1800680 08/13/08 014 IMO AA No: 50-029-20485-00 03/06/09 CMD/SV OORFECTlONB SEC 21,T11 N,R13E,1873'RC&1264'FEL 01/12/11 PJPIPJC IRAW P G CORRECTION 07/03/12 MSS/JMD SET PXN PLUG(06/28/12) BP Exploration(Alaska) VOF 77,r, • -0" I%%yes THE STATE Alaska Oil and Gas � -s OJ LAsKA Conservation Commission 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ` Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer scow P P 2Q 91, BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-11 Permit to Drill Number: 180-068 Sundry Number: 317-368 Dear Mr. Hibbert: 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, f;4t.../ Cathy . Foerster Commissioner DATED thisay of September, 2017. RBDMS Lv SEP - 8 2017 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMIIRN APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well IZI - Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Well Lock Sqz Il • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 180-068 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. • 6 99519-6612 Stratigraphic 0 Service 0 API Number 50-029-20485-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No RI PBU H-11 • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: AUG 0 4 20 iJ ADL 0028284- PRUDHOE BAY,PRUDHOE OIL' N^1� J3 9 f jj y 11. PRESENT WELL CONDITION SUMMARY /'"'o. I Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk( ). 9875 • 9464 • 9789 9381 9818 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2664 13-3/8"72#L-80 31-2695 31-2695 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1482 7"29#L-80 8391-9873 8045-9462 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary IBJ Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development B • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil RI ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert©BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engine Authorized Signature: 1:... ..,,.... .. � ► "� Date: e)f3/I7 �_' COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31-7- ' Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 -, Other: L/ Post Initial Injection MIT Req'd? Yes 0 No It Spacing Exception Required? Yes 0 Nore Subsequent Form Required: / e— <704- APPROVED 704- Approved by: COMMISSIONER COMMISSIONYTHE OVE47/2)94„.1---50...—__ DaterC —/7 VTZ 9/' / I7— o'RIGINAL RBDMS k. SEP - 82017 a'A07 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • • RECEIVED AUG 0 4 2017 AOGCC Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) August 3, 2017 To Whom it May Concern: Attached please find the Sundry Application for an OA Well Lock Squeeze on Well H- 11, PTD # 180-068. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • by Well: H-11 H-11 OA WeIlLock Squeeze Well Interventions Engineer: Michael Hibbert (907) 564-4351 Pad Engineer: Tyson Shriver (907) 564-4133 History H-11 is a GDWFI well that was drilled and completed in September 1980 in the 44, 45 and 46P sands. The well was a consistent producer when it came online fulltime in 1984 until its first RWO in 1992. This RWO was to swap tubing in preparation for an Ivishak frac. H-11 again produced consistently with great ontime until TxIAxOA communication was found in 2004. The communication issues left the well SI until 2008 when a second RWO was executed where tubing was swapped out and the OA was cemented to surfae. There was 4 years of steady production post-RWOunt l going Not Operable with " a confirmed SC leak. No action has been taken on fixing the SC leak with the recent success of micro-fine cements and other polymer products because of work that needed to be completed on the surface lines in order for H-11 to flow. Just recently, these surface line issues were resolved. The well is now ready for an attempt at an OA squeeze to mitigate the SC leak to surface. A passing MIT-IA to 2652 psi was performed on 11/4/15. A passing MIT-T to 2554 psi was performed on 11/4/.15. Current Status ✓ The well is currently shut in and is classified as "Not Operable" by BP. Objective Squeeze the OA with Well Lock to seal off OAxSC leak. Procedure 1. Obtain liquid leak rate OAxSC. Strap top of cement in OA. Prepare cellar/well. 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 500-600 psi per Recommended Practices. S • TREE= MCEVOY I.AELLI-FAD= 1.4CFVOY' Li 11 lel 1 SAFETY NOTES: ""'4,112" CHROME TBG*** ACTUATOR OTtS KS.B_EV= 76_49' BF ELEV 7' 47 29* i KOP= 3200' [ NDUCT 70'0-173-7--E. OR "1 10*-71 ....---- 1746' J 1:4'08'1-11-1-i17-.S414/11-N11-1 Ligum MD 7 I 2128 1 ]4-1/2'HES X NP, 13-3.813" 1 Datum TVD= 88017 _ -1 SS 2608' 9-5/8"TN PKR .. I 9-5/8'CSG,47*,L-80 HYD 563,13=8_681' 1---1 1763'--/- GAS LFT PJANCIFELS 13-318'MG,72s,L-80 BUTT,13=12 34r Z700 ST MD i TVD CEV TYPE VLV uvral FORT DATE 4 3250 3246 13 WAG DOW RK 16 11/04/15 IIP 3 5116 4992 21 MSG SO F8( 20 11/04/15 2 6721 6486 22 P4G OW RK 0 08/12/08 ______ _ 1 7802 7498 20 WAG OW RK 0 08/12/08 Minimum ID =3.725" @ 8242' I 8134' --14-1/2'HES X MP,ID=3.813' 4-1 ir HES XN NIPPLE 411 X 8186' -9-5/8'X 4-1/2-BKR S-3 PKR ID ..._ I 817 -1--14-1/2-HES X NP,13-3.813' I 8247 ---- • 4-1 rr HES X N NIP D 3.725' 1 4-1/2"TBG 12.61,13CR-80 VAN TOP, -1 8263'=3 ' 1----- 0152 bpi, _ 1_____.....---- 927W -9,518"X 4,1t2-UNIQUE OVERSHOi ID 958 --- 8284' -BKR ANIONINt LAID-1ASSY,0-395' . 11-1/2*TBG STUB(07/15/138) H 82er ,--- - I 8285' -9 5/8^X 4 1/2-TANI-488P AK/,2,ID-3 875' 1.... 8289' H5-1/2'MLLOUT a-03493N,10.4,91' ---------"'-[ 8294' H5-1/.7-X 4-1,77'XO 11-3 958' 1- --- - .,- ,-------_, 1 1 8321' - +4 1/2-olt,x NAP I) 3 tti r TOP OF T LNR ---1 8 391' 1 13 I I 8428' 1-4-1/2'OTB XN NP,I3=3705'-I 4-1/2'TBG 128*,13CR-80 FOX. 1 8440' 1 / \ ; 8440' --14-1i7 NM_EG,13.3 958' 1 0152 bpi,ID=3,958" 8431' Ham()TT LOGGED 11/11/92 1 I 9-5/8'CSG,479,L-80 BUTT,13=8.681' 1-- 8942' 1--.41 lik PERFORATION SUMMARY F8 LOG: S &-BECS ON 09/14/80 ANGLEAT TOP PEW: 16'92 9136' I Nbte:Fbfer to R-oduction DB for historical pert data SIZE SFF INTERVAL OpniSq2, DATE I 3-3)8" 6 9136-9146 0 04/19/90 3-3/8" 6 9156-9192 0 04/19/90 3-1/8" 8 9206-9244 0 052)6/81 3-1/8" 4 9254-9265 0 05436181 9262' i('PAAWERJOINff 3-118" 8 9288-9304 0 08(14/81 ' ?fl 1--'FM-3-3or 8AVERIBP(01/05/08); ••••‘•.1 ; •••• •.. 08/21/08.FELL BELOW SAM)TOP•••••• ••••••4 •••••• Fil3TD -41---9830' 4.9/9999r •••••••• .4 4 4••••4 ,I4.400/ [i• N9 iglt,L-80 BLOT, 0371 bpf,13=5 154' H 9813' ' DATE REV BY COMMENTS DATE REV BY COMMENTS F441)-CE BAY UNIT 09/19/80 E22 OFIG84P.L COMPLETION 12/11/15 JLS/..9.0,GLV 00(11534/1* wa_L I-1-11 01/07/92 018 I /O 12/11/15 .11.S/Jkl),PULIED PXN FLUG(1 itosri 5) PERMIT No:'1800680 4 --. 08/13418 014 111/0 ., API P 50-029-20485-00 03/06/09 CMD/SV i CORREMIONS SEC 21,T11N,R13E,1873'FNL&1264'FE. 01/12)11 PJFIRTC ICRAWI1G CORREC110N 107103/12,_MS-SiJkl)SET PXN PLUG(06/28/12) I _1 BP Exploration(Alaska) ? • • o_ 000000 c4 r N O U) O CO I� O 53 N N- N- ti U N 0 0 0 0 0 0 M N- N- CO M M M CD OD CO v- m Nr QD CO 00 00 00 1.11 O N OD N N O O QD a) co O 121 1 1 1 1 1 1 1 H in CO N 6) Lo 1 N- N co M N N- O N 6) — oo N- Q) N Lo O N M U0 0 v- CO I— O CO N V N CO 6) OD OD V• Cl .111 LUd' N v- CD uo rn r- co DI = M M N N- M N N CO CO .▪0• W CI- O O I— CD CD CD °O e0 0° OD ao O 0 U Cr) bJJJao01 01 = N co N *k J 4# *k ▪OD X Nr .* CO CO O O O\O N v U M 141 141 N N O 0 r r V V t +•+ to N CO LU En O QD 01 CO oo Nr Oo Co r- N C, N f— — OO v- -J WOC Q _O •N 0c UJ W oa C W' ZZ_ Z W. W W m C) u) F— � . • • a) N Cu m N N 10 LU I-- t N d I,- CO aOO N CN (Ni O 0LU O ao N ❑ I- CO - CO C) 00 ❑ CO CO 00 00 > I- O. 0 I- CO N .1- .c L co co co Q. c0 I- 6 N a) ❑ co 00 Lu ❑ ao co °o co 0 > 2 I— W ❑ 0• CI 0) Z W W 0 W0 H H J 0_ W ggY 00 > en CO 0 0 W Y Y H f g J 0 0 W W +I Q CO rn t CCOO C) J J J Q¢ j 0 Z CC a> ,- ,- N N CO Q Q Q W U C ❑ 6) CD CD 6) C 0 0 0 O J J J ❑ J E y 1r 2 Z < < Cl_ 11-1 O 0 0 0 W o. c Z Q Z W W W 0_ H H Q J Q (� 2 2 2 O U) co Cl) Cl) Cl) CU 1r Q 0. I i. O I- C C D C0) o O LU cos O Q-mC ,- NNN a cpcmOn C) C) ca 03 Il- a) 0 2 CC 0CD 0 Cl ) a 2 0 cn cn cn cn cn d CL y 0 0 c O LL u Lt C (n m d Q W W d d < Q0_ au) 0. 0 t a) d 0 W J J H d H LIJ LU 0 0 0) 0, 0) ❑ D D O c 01 0) W J J Z LL oma .- � � .- Z W a a <CC W LU cl 07 N 0 W W W J W W LY _ _ a 0 0 0 W LU O CO 0 CC CC J J 0 0 W W Q Q CO CO LL LL cn U) O_ cr a) E Cu z N .- c- .-- c- •- u_ O_ cn 0 IL N O_' LL 0 Q Q CO CO L.L. Ii V) O_ O' • • Packers and SSV's Attachment PBU H-11 SW Name Type MD TVD Depscription H-11 TBG PACKER 8151.87 7823.97 4-1/2" Baker S-3 Perm Packer H-11 TBG PACKER 8285.21 7947.6 4-1/2" TIW HBBP Packer H-11 PACKER 8329.08 7988.25 4-1/2" Baker D Packer • 0 0 Thousand Cubic Feet of Gas ("MCF") per Day co 00 0 00 0 O 0 0 0 0 lto -e,,,Pt t St t 4P Pt r 0 Iv 0 • �4P t a L' .....**'%.$ oo0 t c baa -"I o d — 41 • - 1. rya40 �• 10�4Pr , ,��� (-',.- .• 47-4' `, ell:-• 600,4 P, p LL U <00� o 1 r ro Z da a:;,4 �8 a1 ,, c S_ OON "0 c a ® '" 4P °' ro * .,° a N 0J a Oosi. -- n 0 00 p QJ J om �Z Ca d� -� .-i ' - n0 �zOO i:. , N - t00, a Q 4r -v PJ -a a4.64, >m 407 V 1111 Q — a 6 6 N. -0 10 co d a -'" ,_ 0 !6 N. e♦ I a a a G1. PO r Aa-...-n' r ¢ 3 3 3 - N �l = d i a a ,4 . �� 6614P 0 > iicioi IIII r o Y 0 Q r.r-7 • • - e66 L;-._ o CI. iF Pr 686.1.' 8 4Pr a VTO �+ 61;4 0 P n r m La:, � ►Jl © r 1861 ° c COC -0 �Atii�� ' a 4 -0 4 - s86 u c :r 3 6861 n. co v • ` • 1 4Pr - r86r 4 Pr . F 6 00 00 oc o .-, !6r 44, o o .i r o .-i Ilea Jad Ja:eM Jo siaa.ie8 Jo Aea iad no io s�aliee u 0 a ` • • — N 0 Thousand Cubic Feet of Gas ("MCF") per Day or 00 Gas-Oil Ratio (MCF per Barrel) 00 0 0 0 0 0 o 0 0 0 0 o 6 ari o vi oc M (Ni N .-I .-1 Vf o 1 :;::;:,O%4P 0 E r O @ elk> _ y a - _ y s llCO CO 0 Pc O - 6oOe o ll ++ i '44.r a o 1ce 1 1poe i = P, O ®' s��� o _ _: o m 00 cor4 -__ 4P o ZJN a N. 4-.7.4-_-.-____ r jr -�-:� O 73 u`^i n _ a=--� _.. FOp� ci T r; d '" -c' _ l m v J --------:-:-:-.7- ---N3- ` _-_-Z- --N- - z H 4P,, pr 1 o 003 W = c 0 3 G .��- ` -_ a --_ P/ o �a z. 0 V a a a � -_�_ - Pj I a d 3 E E E -�. 6 0 I -0 3 > > ��-= S 6r 0- elm / �� F6 O dA 4P� A/ CO - t j o 0 CC 66 a CL cv Q ' l4P m _7-2 I ./.4 , r — c, Co 6j4 r a, P'r 5 c ."° - - � 1861 `0' �'? p i s86r 4 a. c, 1 686r IIa`, . i lire, 1 1 P/ T r— r— . 6! 0 0 0 0 0 0 0 0 0 0 0 6l. 00 0 in o Lno Ln0 0 0 0 Ln 0 4Pr tri V M re N N .-I . Ilea Jad aa}e/N 10 spins Jo Ilea Jad l!O Jo spins 0 a Pro /86 —0 I4 Loepp, Victoria T (DOA) From: Sayers,Jessica <Jessica.Sayers@bp.com> Sent: Tuesday, July 21, 2015 9:10 AM To: Loepp,Victoria T (DOA) Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378)Well Lock top job to micro annular squeeze procedure Follow Up Flag: Follow up Flag Status: Flagged Awesome! Thank you Victoria! S`40E0 AUG 1 3 2015 Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, July 21, 2015 9:07 AM To: Sayers, Jessica Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Well Lock top job to micro annular squeeze procedure Jessica, The proposed change to add a Well Lock top job to the micro annuli squeezes for the following sundries is approved. Please include this approved modification with the approved sundries. • A-34A: (PTD185-105, Sundry 315-412) H-11: (PTD180-068, Sundry 315-413) R-24: (PTD193-074, Sundry 315-414) •• M-16(PTD 181-086, Sundry 315-378) Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�.alaska.aov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.aov From: Sayers, Jessica [mailto:Jessica.SayersObp.com] Sent: Tuesday, July 21, 2015 8:55 AM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Hi Victoria! 1 Just wondering if I can be of any further help. Would it be okay to move forward with the portion of these jobs we already have approval for(the SqueezeCrete portion only), while we wait for the WeIlLock piece to get sorted? Thanks! Jess Sayers From: Sayers, Jessica Sent: Thursday, July 16, 2015 2:33 PM To: 'Loepp, Victoria T(DOA)' Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) The results and findings have not yet been released or finalized. WeIlLock is a Newtonian fluid that reacts exothermically. Preliminary findings suggest that the heat capacity of the overall system should be carefully considered. The heat of reaction, heat transfer capability of the medium in which it is placed, whether the system is open/closed and under pressure or open to the atmosphere are prime factors for this evaluation. Empirical data suggests that microOA squeezes and downhole treatments are suitable and effective applications of WellLock. As such, BP management has given approval to proceed with both microOA squeeze jobs, as well as downhole treatments. Let me know if you need more information. Thanks, Victoria! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, July 16, 2015 1:04 PM To: Sayers, Jessica Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) What were the results of the investigation of the Well Lock incident on V-101? From: Sayers, Jessica [mailto:Jessica.Sayers@bp.com] Sent: Thursday, July 16, 2015 9:26 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Hi Victoria, Thanks for approving this requested 403. I have decided to add a conservative step to the well treatment for M-16 (this well is a well that has a fully cemented OA and we are using SqueezeCrete to remediate the surface casing leak). After the well is squeezed with SqueezeCrete, a nitrogen cap will be left on the OA. After the SqueezeCrete cures (going to allow 2 weeks) and before the MIT-OA, a WeIlLock top job will be added. This is for a couple of reasons: 1)we are more confident in the properties of WeIlLock to cure MicroOAs (it has no yield point because it is a Newtonian fluid) and 2)we have seen that we get the best WeIlLock jobs before MIT'ing with diesel (while WeIlLock will swap with diesel, it does not effectively do this in microannuli space- we therefore try to move forward with WeIlLock jobs without saturating the microOA with diesel). This step will be added to the other recently approved, similar jobs: • A-34A: (PTD185-105, Sundry 315-412) 2 • H-11: (PTD180-068, Sundry 315-413) • R-24: (PTD193-074, Sundry 315-414) Just wondering if you wouldn't mind helping us get navigated in the right direction here, in terms of the existing 403s? Are the already approved 403s ok, as is? If not, would we need to reapply for new 403s or would it be sufficient to update/add to the already approved 403s? Thank you so much for your time! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, June 19, 2015 2:12 PM To: Sayers, Jessica Subject: PBU M-16(PTD 181-086, Sundry 315-378) Jessica, What is the maximum squeeze pressure allowed at the discharge of the pumps for this procedure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.LoeoQ@alaska.gov 3 yOF Ty , ee*�� ��j�s, THE STATE Alaska Oil and Gas s�,;,.-s� , ofA LAsKA Conservation Commission itx 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1433 �� ALASY P Fax 907.276 7542 }` sato') www.aogcc.alaska.gov ; ,. Jessica Sayer o �( Well Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-11 Sundry Number: 315-413 Dear Ms. Sayer: 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, Cathy P. oerster Chair DATED this 14 day of July, 2015 Encl. RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMB, JN ,J U L 0 8 2015 APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 7/1 (�'/(� 1 Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing QC) Ve11PJations shutdown 0 ` Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing p Change Approved Program 0 Plugfor Redrillni)i o,a,10(4,1• 0 Perforate New Pool ❑ Repair Well ® Re-enter Susp Well 0 Other O9pUeeze 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: , 5 Permit to DnII Number: 180-068 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development li 99519-6612 Stratigraphic 0 Service ❑ 6 API Number: 50-029-20485-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool'? Yes 0 No m Will planned perforations require a spacing exception'? PBU H-11 ' 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028284 • PRUDHOE BAY,PRUDHOE 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): 9875 • 9464 • 8242 7908 8242 9818 Casing Length Size MD TVD Burst Collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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 See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program RI Exploratory ❑ Stratigraphic 0 Development ® . Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil WI • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG ❑ Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer Signature P.1 Phone +1 907 564 4281 Date --1/8 d 5 COMMISSION USE ONLY 6 Conditions of approval: ify Commission so that a di-sentative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No lif Subsequent Form Required: /0 —40 ` — yn APPROVED BYTHE Approved by: / ? 1 // COMMISSIONER COMMISSION Date: —/4L—/S aw,47 Yrs /'1-f J ORLC . L . , = r Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. tt ments in Duplicate RBDM JUL 1 5 2015 a) o 0 0 0 0 0 c O COti O In Ln N O O CO N- C N V V r-- 17; -N O o 0 0 0 0 7 O CO 00 CO V CO CO CO CO O L.0 O 'Cr N CO N CA CO CO CO co CA CO CA O N c- CO CA N- CO N- LO CO N— a) in V f— N CO CO N N- O N CA CO N C w LOO N CO in CD O) CO V I� N CO N- CA CO N N a— CO CA CO CO V 0 CUi i I i i i 4.0 QV N C)) In C)) I— • T M ch N N- CO N NN CO• TT CO lCD CD CO 00 O O O C° CaoCo UU O ') J J CO c = (n M (..,1 4 *k J *k 4# •Cl) x , *k CO CO 6) O 00 roD N 0 Lc)) LO NN 0) CA d' V ++ � 1- In N CO CIO CO CO CO CO V O C CO CO N- N N x— CO W W CnO Q Q CF— W0 •NUUW W U a Z Z Z r W W W m m 0 D Z > U, N f0 CO N N 0 0 ti t N I— CO N C O N 0 O 0o C] N CO co CO CT) CO CO CO CO > F 0. 0 CO CN t Co CO O ' co Co N CA co 00 Lu 0 00 > a• co ao °O co 0 Lu 0 W W Z O W 0 H J a cp 5 Y v 0 0 CO O O W Y Y g L Co CN 0 Ct Q Q w W cc w 4.+ a 'Sr CJ) Co O < < < w a a Z = o rn rn rn rn rn z z 20 k J J o J N a a W a 2 U 00 a W z 0 z 2 2 2 O ccn H ccnn c(n cn Q r a T" I n � � (8L (0 N N N a7 C3) co O a) L d - cn _ F- H a J as 2 2 2 O u) N (/) cn CO a) .2 O U • U) U) U) U) U) m a_ a_ d a_ d mm07mm 0. O N a d H Q N N N N N O :) :3 0 D • 0 0 0 0 0 W J J Z Q N N N N N Z LU 1 1 W CO CO ao CO CO N w O J o w w o o w N_ N_ N N_ N_ a :D W :: 0 WWW W O. Co CO Co Co CoQ 0 J JJ J D Cr 0_ O CO 102L.0 Q O W W < < 10_ 11C0 LL E w cn a CC N E m z wa a cn O w N 0 w 2 = 2 2 2 < < m m u_ -1001110_c a m Packers and SSV's Attachment H-11 SW Name Type MD TVD Depscription H-11 PACKER 8151.87 7823.97 4-1/2" Baker S-3 Perm Packer H-11 PACKER 8285.21 7947.6 4-1/2"TIW HBBP Packer H-11 PACKER 8329.08 7988.25 4-1/2" Baker D Packer by Date: 07-06-2015 0 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: H-11 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, surface casing squeeze repair treatment with SqueezeCrete. This well exhibits bubbling in the conductor when on production and returns fluid to the conductor when pressure tested. As such, it is suspected that the parent leak (leak present prior to fully cementing the OA) from surface casing to conductor is the anomaly. SqueezeCrete has been chosen as the repair medium due to both the low injectivity squeeze capability and also the benign reaction conditions of returns that may be present in the conductor (in comparison to WellLock). Well Detail Current Status: Not Operable Previous Test: 02-08-12 MIT-OA w/N2 to 500 psi, returns/bubbling in conductor 10-16-14 CMIT-TxIA to 3000 psi, Pass Integrity Issues: Fully cemented OA; OA presents bubbling in conductor on production and returns fluid to conductor when pressure tested Last H2S Reading: 01-29-12 20 ppm Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 07/11/13: MIT-OA Passed to 500 psi w/N2 > 10/11/14: PPPOT-T Passed to 5000 psi, PPPOT-IC Failed > 10/13/14: PPPOT-IC Passed to 3500 psi > 10/16/14: OMIT-IA Passed to 3000 psi 1 of 3 Procedure: 1 D Remove blue goo and ice/material in conductor. 8 D Place, Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 12 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump (2500 psi max) or until SqueezeCrete returns are observed in the conductor. 14 D Let well cure for 7 days. 15 D MIT-OA to 1200 psi with diesel 2 of 3 . ' TREE. hiCEVOY VVIL-EAD= MCEVOYI SAFETY NOTES -4 1i2"CHROME TBG ACTUATOR 4 0716 H-1 I KB ELEV 4 76 49' 5F.ELEV 4 47 29 /I C 1746' H9_5.4 -ES ES CIAIENTER -, KOP- 3200' 20"CONDuCTOR H 110' Vex Angie 4 22'fp 6300' ..,/ I [ 2126' H4-11"i-ES X 14P C..38 ilium MID n / 924* Ileum TVD 4 8600 SS - [ 2608' 1-19-53'DV P4R7 9-518"CSG,4710 L-80 HY°583,10-=8 881" H 1763' / GAS LFT MAAERII_S 97"; NC 1 WO DIEVITYPE VLV LATCH FORT. ONTE [13 VW'MG 720 100 SUIT 10.12 ur 1-f 2701Y , 4 3250 3246 13 :MAO DOVE RK 16 0811903 II 3 51.6 4992 21 AIM G SO 8< 20 108/19433 2 6721; i 6486 22 NMG DAM RK 0 06/12/06 1 1 , 7802 1 7468 20 1 MVP OW R14 0 06/1 VO6 Minimum ID=3.725" @ 8242 . 8134. 4412"HES X!VP 04 3813" 4-1/2"HES XN NIPPLE 1 81W HO-541"X 4-1,7 BM S-3 PKR,10•3 873' ,,..., II 817W 17 4-1,2"HES X NP 04 3 813" i 8242. H4-1 a'PAN/PtUG(08/26,1 2) 8247 4-17 rES XN NP,ID=3 725" 4 1/21 18012.60 1=12410 V X1A roe i-f 8283' ____--t_ ,19-645"X 4-ter t.INMui Lhe Li60-10T_I '3152 bpi 1-3 95W fib _ ...,_ --' 8284 ..R ANCHR A!CI,ASSY ID-39E' __ ___ 14-112'78G STL8(07/15108) 1.-{ 11267' r"------ _ 8265' -1 0_58,x 4-1,9'TW 32PC? c XT -828-9-:--1 45-1,2'MR„LOUT DOE01810.4 ID=.4-ill' I : ,-- 8294---I S lir X 4.11r X0.0 68 .3 9 I - , S ri211 CT X NP 13-38131 i- . ,-,, 2' . I TOE OFroaR k env 1---11 I 1 8428' H41/7 OM XN NP ID.3 225* 4.1.12"Tea 12 618,13014410 FOX, 1-1-7-8440' - ' '. 8440' 4-11.-WIEG,13.395r 0152 apt 0=3956 , 8431' --FEINID It 10G0 .)11,,"'192 I 1125*CSG 47$ L-60 8Ur7 0-,.3 54'' H 8942 --a FERFORABON5L0411.44RY FLOG SWS-81-CS ON 091"MB° ANGLE AT TOP TERF '6"Ci 91X I Note Fitter to And Won Elb for hotoreal CreT data Illadilleall INTERVAL Opn/Soz DA"E I 3-3010 6 91 36-9146 0 04/1 9,90 3.318" 6 9156 9192 0 04/1690 3-16" 8 9208-9244 0 056)8181 3-118" 4 9254•9265 C 0ee06/61 1 9297 -r MARKER.10041 I 3-16' 8 9286-9304 C 08114.61 -;$1 M FISH-3-3/13'BAKER 1847.(01/0508), 08/2110e FEL BELOVVSAND TOP •:•••••••44,4 min 9830 g poorAveip 1 rfW•Ve10 %%WAN -t RR.290.L-80 8U"" .0371 W 8)=,6184- H GAig"-RN ilY c61911/471Ntg-----T-50rMOW VC\J Mt/D*03E84Y 1-611 09‘19/40• E22 ORIGI NAL COMPLETION 03/06/09 040/SV CORRE-CiONS WELL H-11 u11192 916 MO 01/12/11 RifttP.1C CRANING COW4.r2.I ON Kfrtir ni) 1800680 08/13/081 1314 MVO 07103/12 145S1JMD SET Atte RUG(Ofir2(3/121 AA Ab 50-023-20485-00 I0132,08 OJT/IL I OPE SA NC TAG(09,25013, SEC 21.Ti 1 NI,R12C 1873'Fri.&1284'gEt. 10/16081 1/NC Cfh.L0 CRAFT CORR_TCTONS ' -- 11.24/08 I l-iWJMO ORLG CRAFT CORR(139/30.108) -_ BP Exploration(Alaska) 3 of 3 XHVZE ect Well History File Cove~ Jma ige 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. J ~)"~- ~ ~ <~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: [] Diskettes, No. [] Maps: [] Other, No/Type ~ [] Other items scannable by large scanner BEVERLY ROBIN VINCENT I~MARIA WINDY Project Proofing BY: (~~ROBIN VINCENT SHERYL MARIA WINDY OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other = TOTAL PAGES BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO IF NO ~N STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND:~/ ~/. -v - ~_..~S~''''~ NO Production Scanning Stage 1 Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION tS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) RESCANNED E~Y~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: I$1 General Notes or Comments about this file: 12/10/02Rev3NOTScanned.wpcl • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 0 Mr. Jim Regg Alaska Oil and Gas Conservation Commission d 333 West 7 Avenue S ,> 'N DAUG 0 h 2U12 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, 9g, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H 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, API and PTD numbers, 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, Gerald Murphy, at 659 -5102. Sincerely, v I Mehreen Vazir BPXA, Well Integrity Coordinator • • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 --IP H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 1-1-35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 11-38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 {,�` 01/20/11 S „ "-- NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 14-43 BGZ7 -00010 CROSSFLOW CHECK ..- / DX; 11/13110 1 a 1 NGI-14 AVIH -00052 EIMIIIM; TAVW 17iPA Z. 1 L -205 BLP0.00073 MEM LDL O :” f U, .12/21/10 1 ' 1 A-42A BL65 -00012 MEM PRODUCTION PROFILE � a Q 01/06/11 1 r± a 1 01 -30 BCZ2 -00031 INJECTION PROFILE F� :Jerr I—irga"7 1 02 -20 BBSK -00040 c a I 1 0 n OM abre. -g, - 1 1 07 -23B AY1M- 00056 A1iNL� AY K 1 K -11A BDB8 -00 'Q�,LIt'JIiL' F!Y ' ' 1e N . 1 04-24 AYIM -00055 C12150111Tr%1's # ' ' FIMM 1 • 11 -12 BCZ2 -00033 RST I ", // • 12/07/10 _ 1 0 •f ' — 1 2.28810.19 BCRJ -00055 RST 4 b —or) . 12/01/10 1 , 0 i 1 S -128 BCZ2 -00035 USIT —) q 01/02/11 . Q(n • 1 1 W -220 BG4H -00025 USIT -- ' 12/27/10 ♦ ji 1 1 S-41A 10AKA0106 OH MWDI WD EDIT '_] ' ' t 921 I S41AL1 — 10AKA0108 OH MWD /LWD EDIT '_ ,. __ 10/15/10 2 /V r'I 1 7. ...." . H -11 BGZ7 -00014 12/18/10 1 ' O 1 ti • ,"._ _ . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. MAR 1 4 2011 Anchorage, AK 99503 -2838 r r, - j ;`+, ( 1 , • , . 0S---- ' .!,f\1, A'. f' 11 '' , ~~.~f~m~~~~~~ N0.4903 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 t-; ~, ~ r° , ; t-, , a ~~ Alaska Oil & Gas Cons Comm Anchorage, AK 9s5o3-2838 ~''`~'~~ ~¢i,~'~-° ~~~ 1- ~ }' ~~~~`' Attn: ChristineMahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 09/23/08 L-216 10687773 -- -~~~ ~ MDT - 05/09/04 VVIVI 1 VV 1 L-204 11212880 MDT - ;~ 07/24/06 1 1 14-22A H-11 11999036 12017507 PPROF W/FLOW SCAN IMAGER / '~(0 USIT 08/17/08 08/09/08 1 1 1 1 D-22C 11963190 USIT _ '1 ~ (Q 08/20/08 1 1 NK-10 12066549 MEM INJECTION PROFILE G~ - ( / g'~ 09/11/08 1 1 09-28A 12031499 RST - 08/01/08 1 1 N-10A 12005225 MCNL ~ ~ 08/20/08 1 1 05-23B 40016995 OH MWD/LWD EDIT 05/27/08 2 1 DI CACC A!`1ld1A\A/I CA/~C ~C n CInT o _____________----.~..~~~.. ~. ~. v......v. .,..r ..r•r~~~~,~~V V,~4..VVrI LMV\l IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: ~ ~ • • b `~-J STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIONS [~.~~ V SEA 0 ~ ~~`~~ Alaska Qi~ & G~~ ~Qns. ~ar~r~~~~~~~~ 1. Operations Performed: Ai'1~i 5~~3~0 ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing - ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 180-068' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20485-00-00 - 7. KB Elevation (ft): 76 5' , 9. Well Name and Number: PBU H-11 - 8. Property Designation: 10. Field /Pool(s): ADL 028284 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9875' ~ feet true vertical 9464' ~ feet Plugs (measured) 9070' Effective depth: measured 9830' feet Junk (measured) 9249' true vertical 9420' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2696' 13-3/8" 2696' 2696' 4930 2670 Intermediate 8942' 9-5/8" 8942' 8564' 6870 4760 Production Liner 1482' 7" 8391' - 9873' 8046' - 9462' 8160 7020 &~~1~ ~ ~~~ ~ ~ ~ry~V ,..~6dJ i { ~ ~a Perforation Depth MD (ft): Below Plug: 9136' - 9304' - Perforation Depth TVD (ft): 8749' - 8910' 4-1/2", 12.6# 13Cr80 8440' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer 8155' 9-5/8" x4-1/2" TIW 'HBBP' packer 8285' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 8270'. Cut and pull 9-5/8" casing from 1760'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 134 bbls Class'G' 752 cu ft / 643 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ~ ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 308-262 Printed Name Sondra Stewman Title Drilling Technologist Prepped By NameMumber: Signa Phone 564-4750 Date ~?~"~ - ~j Tercie Hubble 564-4628 Form 10-404 Revised 04/2006 ~~~ ,j~:; ~t t ~~ r~ ~u~~ Submit Origin 1 Only C~~1GI~~L .~. ~. ~~~~, NELLHEAD = MCEVOI ACTUATOR = OTI: <B. ELEV = 76.4 3F. ELEV = 47.2 <OP - 320C vtax Angle = 22 @ 830C datum MD = 926 datum TVD = 8800' S: L ki 9-5/8" CSG, 47#, L-80 --~ 17 BTC, ID = 8.681" 13-3/8" CSG, 72#, L-80, 1D = 12.347" 2696' 1111 l,II1T1 ~ °- ~.~~J" L~Li 14-1/2" TBG 12.6#, 13CR80, .0152 bpf, ID = 3.958" ~-{ 8283" 4-1/2" TBG STUB (07/15/08) ~-~ 82$7' TOP OF 7" LNR ~~ 8391' ~ 4-1/2" TBG 12.6#, 13CR80, .0152 bpf, ID = 3.958" ~-~ 8440' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-{ 8942' PERFORATION SUMMARY REF LOG: SWS-BRCS ON 09/14/80 ANGLE AT TOP PERF: 16 @ 9136' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9136 - 9146 C 04/19/90 3-3/8" 6 9156 - 9192 C 04/19/90 3-1/8" 8 9206 - 9244 C 05/08/81 3-1/8" 4 9254 - 9265 C 05/08/81 3-1/8" 8 9286 - 9304 C 06/14/81 PBTD 9830' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9873' SAFETY NOTES: ***4-1 /2" CHROME TBG*** H-11 ') 74g' -~ 9-5/8" HES BTC ES CEMENTER 2126" 4-1/2" HES X NIP, ID = 3.813" 2608' 9-5/8" DV PKR GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 4 3250 3246 13 MMG DOME RK 16 08/1910 3 5116 4992 21 MMG SO RK 20 08119/0 2 6721 6486 22 MMG DMY RK 0 0811210 1 7802 7498 20 Mfv1G DMY RK 0 08!1210 $134' 4-1/2" HES X NIP, ID = 3.813" $155' 9 5/8" X 4-1/2" BAKER S-3 PKR $~~9' -~4-1/2" HES X NIP, ID = 3.813" $242" 4-1/2" HES XN NIP, ID = 3.725" 8279° 9-5/8" x 4-1/2" UNIQUE OVERSHOT 8283' LATCH ASSY 8285° 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 3.875" 8321' 4-1/2" OTIS X NIP, ID = 3.813" $42$' 4-1/2" OTIS XN NIP, ID = 3.725" $I moo' I~ 4-1 /2" TBG TAIL ID = 3.958" 8431' ELMD TT LOGGED 11 /11 /92 ?? -j SAND TOP (01105/08) ?? 3-3/8" BAKER IBP (01/05/08) IBP at ~ OQ` flo Ion er holding Well Went on vac afer removing junk catch. 9181' SAND PLUG 9249' 1 ~~v+RKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 09/19/80 ORIGINAL COMPLETION WELL: H-11 01/07/92 RWO PERMfT No: `1800680 08/13/08 D14 RWO API No: 50-029-20485-00 09101/08 DAV/PJC GVL C/O (08/19/08) SEC21, T11N, R13E, 1873' SNL & 1264' WEL BP 6cploration (Alaska) Page 1 of 2 Well: H-li Well History Well Date Summary H-11 7/13/2008 ***WELL S/I ON ARRIVAL*** (pre rwo) SET 4 1/2 JUNK CATCHER (119" OAL, 3.78"_OD~ON XN-NIPPLE_C~_8428' MD ***WELL LEFT S/I, DSO N TIFIE ) H-11 7/14/2008 INITIAL T/I/O = 300/280/0 PSI. CUT TUBING AT 8267' WITH 3.65" POWERCUTTER. FINAL T/I/O = 190/280/0. WELL LEFT SI. PAD OPERATOR NOTIFIED ON ALL VALVE POSITIONS BEING LEFT AS FOUND. ***JOB COMPLETE*** H-11 7/15/2008 T/I/0=170/360/0+. Temp=Sl. Bleed WHP's to 0 psi, pre-PPPOT-T & IC (pre-RWO). ALP=O psi. T FL C~ 300' (5 bbls). IA FL C~3 surf. OA FL NS. Bled IAP from 360 psi to 170 psi in 45 mins. Bled IAP & TP simultaneously from 170 psi to 20 psi {fluid/gas) in 2 hrs, 45 mins (3 hrs, 30 mins total) (10.5 bbls returns). Bled OAP to 0 in 30 secs (all gas). **Note: IA casing wouldn't hold, grease crew serviced. Final T/I/0=20/20/0. **MV open; SSV, WV & SV SI; IA & OA OTG** H-11 7/16/2008 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Opened bleeder screw to verify 0 psi in test void. Removed internal check and installed Alemite external check. Functioned LDS 2 broken gins th r .et mov .d fr . Iv. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Opened bleeder screw to verify 0 psi in test void. Removed internal check and installed Alemite external check. Functioned LDS 1 broken in the rest moved freel .Pumped through void, clean returns. Re energized secondary Y seal with plastic. Pressure voi to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. ***Broken LDS will need to be drilled prior to RWO*** H-11 7/16/2008 T/I/0=28/35/0+. Temp=Sl. Bleed WHP's to 0 psi pre-PPPOT-T & IC (pre-RWO). ALP=O psi, SI ~ casing & manifold bldg. T FL NS. IA FL NS. OA FL NS. Bled TP &IAP simultaneously from starting pressures to 2 psi in 2 hrs, 30 mins (gas/fluid) (.26 bbls). Bled OAP to 0 psi in 30 secs. Maintain open bleed while external checks are installed. ** Note: IA & OA integrals installed. Final T/I/0=2/2/0. ** MV &SSV open; SV & WV SI; IA & OA OTG ** H-11 7/18/2008 T/I/0= 0/0/0 CIRC OUT (PRE RWO) -Pumped 5 bbls meth spear, 893 bbls. 9.3 brine followed with 34 bbls. 60* diesel for F/P down the tubing, up the IA taking returns down H-32 flowline. RU U-tube hose, --- ---Job In Progress------ ***WSR Continued to 07-19-08*** H-11 7/19/2008 T/I/0=0/0/0, Temp=Sl. Repair broken LDS. Ri ed u Wach's drill. Drilled and re laced 2 broken LDS on tubin head and 1 broken LDS on casin head. Pressured TBG hanger test void to 5000 psi, test goo no leaks. Pressure test 9 5/8" pac off test voi to 500 psi, test good no leaks. H-11 7/19/2008 ***WSR Continued from 07-18-08*** Cric Out, CMIT TxIA to 3500 psi. FAILED (PRE RWO) U-tube TxIA for 1 hr to put F/P in place. CMIT TxIA Pumped'5T66 s1~Z. `'d'~'iese own T to reac test pressure C 3500 psi.T/IA lost 80/100 psi. in 1st 15 min. and 80/60 psi. in 2nd 15 min. for a total loss of 180/160 psi. in 30 min. 4th test. Bled well pressures down to 0 psi. Final WHP's 0/0/0 Notified Operator upon departure, Swab=Closed, Wing=closed, SSV=Closed, Master=Open, Casing valves open to gauges. Well support hard-line shut in from H-11 to H-32. H-11 7/20/2008 Set 6-3/8" CIW BPV# 415 set ~ 108" for pre rig. T/I/0= 10/0/0 H-11 8/1/2008 T/I/O = 10/0/0 Pulled 6 3/8" CIW J BPV thru tree rig move on. H-11 8/2/2008 T/I/O = 0/0/0 Pulled 6-3/8" CIW "H " TWC # 409 ~ 102" 5-5 'ext. used..post BOP test for Doyon 14...no problems H-11 8/11/2008 T/I/0= 0/0/0. Temp SI. IA FL (rig call in). IA FL is ~ 2100'. H-11 8/13/2008 T/I/O 0/0/0 Pull 4-1/16"CIW H TWC #277 Thru Tree, Post Tree Test. 1-2'EXT Used TaggedC~3 108" No Problems H-11 8/16/2008 T/I/0=0/0/0; Pull 4-1/16" CIW "H" BPV thru tree post Doyon 14; 1-2' ext. used, tagged @ 102'; (Best/Wortham Page 2 of 2 H-11 8/19/2008 *** WELL S/I ON ARRIVAL*** (post rwo) SET 4 1/2" SS-CATCHER ~ 5212' SLM PULLED ST#4 RK-DCR VLV FROM 3250' MD. PULLED ST#3 RK-DGLV FROM 5116' MD SET ST#4 RK-LGLV ~ 3250' MD. SET ST#4 RK-OGLV C~3 5116' MD PULLED EMPTY SS-CATCHER FROM 5212' SLM N N I P~ 8242' M D RAN 3.50" LIB ON 3.70" BARBELL, SD & TAGGED TD @ 9218' SLM LIB SHOWS FILL *** CONT ON 8/20/08 *** H-11 8/20/2008 *** CONT FROM 8/19/08 *** (post rwo) BAILED FILL @ 9216' SLM IN ATTEMPT TO RECOVER IBP , RECOVERED TOTAL OF 5 GALs FRAC SAND & SMALL METAL PIECES CURRENTLY RIH W/ 3.00" x 10' P-BAILER *** CONT ON 8/21/08 *** H-11 8/20/2008 *** CONT FROM 8/t9/OS *** (post rwo) RAN VARIOUS BAILERS TO FILL @ 9216' SLM IN ATTEMPT TO RECOVER IBP RECOVERED TOTAL OF 5 GALs FRAC SAND & VARIOUS METAL PIECES CURRENTLY RIH W/ 3.00" x 10' P-BAILER *** CONT ON 8/21/08 *** H-11 8/21/2008 *** CONT FROM 8/20/08 *** (post rwo) ATTEMPTED TO BAIL THRU FILL TO RETRIEVE 3 3/8" BAKER IBP TAGGED FILL G 9223' SLM BAILED TOTAL of 6 GALs FRAC-SAND, WOR ED TO 9227' SLM. RDMO *** WELL S/I ON DEPARTURE, DSO NOTIFIED *** Print Date: 9/3/2008 Page 1 of 1 • • BP ;EXP'LORATION Page 1 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/28/2008 00:00 - 04:00 4.00 RIGD P PRE RD for move to H-11 -RD:Stand pipe, Manifold, Tugger stand, Jump Rams & Wind walls. -LD: Stand pipe,Pipe handler, Link tilt & Mud bucket. -Unplug service loop & remove ODS rollers. 04:00 - 06:00 2.00 RIGD P PRE RU & LD Top Drive. -PU Block Carriage. 06:00 - 10:00 4.00 MOB P PRE PU & pin "C" section. Tie back lines. -Move Mud bucket sheave. 10:00 - 11:00 1.00 MOB P PRE Lower: Bridal lines, Hook & Yolk. -Hang Bridal lines & pull into sheaves. 11:00 - 11:30 0.50 MOB P PRE PJSM on Skidding Rig floor. -Skid Rig floor. 11:30 - 12:00 0.50 MOB P PRE PJSM to move off well. -Move off well L3-23 and align in center of Pad L3. 12:00 - 13:30 1.50 MOB P PRE Remove Stack from cellar. -Install rear Boosters. 13:30 - 14:30 1.00 MOB P PRE PJSM: on Skidding Rig floor. -Skid Rig floor into LD derrick position. 14:30 - 18:00 3.50 MOB P PRE PJSM & LD Wind walls. -Re-tie lines in Derrick. -Pull pins to Derrick. -Tie Derrick down. 18:00 - 19:00 1.00 MOB P PRE PU Tools & equipment on Rig. -Wait on Mats to be placed. 19:00 - 20:30 1.50 MOB P PRE PJSM w/ Security for Rig move. -Move from L3 Pad to Access road. -Back ug onto Mats & lay more Matting due to soft shoulders. -Plywood corner onto East Dock road. Rig off location at 20:00 hrs. 20:30 - 23:00 2.50 MOB P PRE Move Rig down road to Surfcote turnoff. 23:00 - 00:00 1.00 MOB P PRE Wait for Mats to be laid. 7/29/2008 00:00 - 07:00 7.00 MOB P PRE Rig ~ Surfcote Pad turnoff. -Continue to wait on rig mats placement. -Clear and clean rig. -Paint rig where needed. 07:00 - 08:30 1.50 MOB P PRE Cont. moving rig down East Dock Rd. to Hot Water Plant "Y" 08:30 - 09:30 1.00 MOB P PRE Wait on rig mats placement 09:30 - 12:00 2.50 MOB P PRE Cont. moving rig to FS 1 12:00 - 15:00 3.00 MOB P PRE Cont. moving rig down West Dock Rd. to CCP -Flat rear fire on rig 15:00 - 23:00 8.00 MOB N RREP PRE -Remove rear boosters -Replace flat fire -Install rear boosters 23:00 - 00:00 1.00 MOB P PRE Cont. moving rig down West Dock Rd. to L1 7/30/2008 00:00 - 01:00 1.00 MOB P PRE -Stage rig at Li -LD rig mats on West Dock Rd. due to poor road conditions (sink hole) 01:00 - 08:30 7.50 MOB P PRE Cont. moving rig f/ L1 to D-Pad access road on Spine Rd. 08:30 - 09:00 0.50 MOB P PRE Wait while setting rig mats on road 09:00 - 11:30 2.50 MOB P PRE Cont. moving rig f/ D-Pad access road to J-Pad 11:30 - 15:00 3.50 MOB P PRE -Stage rig by J-Pad Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task Code _NPT Phase 'I Description of Operations 7/30/2008 11:30 - 15:00 3.50 MOB P PRE -Set rig mats on access road to GC2 15:00 - 16:00 1.00 MOB P PRE Cont. moving rig f/ J-Pad to GC2 16:00 - 18:00 2.00 MOB P PRE -Stage rig by GC2 -Set rig mats on turn around GC2 towards H-Pad access road. 18:00 - 20:00 2.00 MOB P PRE Cont. moving rig f/ GC2 to H-Pad 20:00 - 22:30 2.50 MOB P PRE Set mats around access road to back end of H-Pad. -Remove boosters and front boosters frame. Set BOP stack in cellar and hang cellar doors. Unchain blocks and put tension 'i on drilling line. 22:30 - 23:00 0.50 MOB P PRE Move rig down access road to back end of H-Pad 23:00 - 00:00 1.00 MOB P PRE Shuffle mats around rig to continue moving. 7/31/2008 00:00 - 01:00 1.00 MOB P PRE -Finish moving rip to H-Pad -Position rig on pad 01:00 - 02:00 1.00 RIGU P PRE Raise and pin derrick 02:00 - 05:00 3.00 RIGU P PRE -Raise and pin lower wind walls. -Re-string super tugger line. -Hang lights. -Pin braces. 05:00 - 05:30 0.50 RIGU P PRE Skid rig floor to moving position. 05:30 - 09:00 3.50 RIGU P PRE Position ri over well H-11. Shim ri . 09:00 - 10:00 1.00 RIGU P PRE Skid rig floor to drilling position. 10:00 - 10:30 0.50 RIGU P PRE Unpin and lower C-section into place. 10:30 - 12:00 1.50 RIGU P PRE Hang bridle line in derrick. 12:00 - 00:00 12.00 RIGU P PRE -Hang ODS bridle line. -PU top drive -Install roller assy. on top drive. Remove and disassemble carriage -Hook up counter balance cylinders. -Hook top drive electric lines -Hook up koomey lines -Spot and berm rock washer -RU hard line and tiger tank -RU mud bucket and tongs -Tie up bridle lines -MU IBOP valves and saver sub. -Hook up kelly hose -Install brace for top drive rails. Install tilt link and pipe grabber assy. 8/1/2008 00:00 - 01:00 1.00 RIGU P PRE -Finish installing pipe grabber assy. -Install bales. Acce t ri ~ 01:00 01:00 - 03:00 2.00 WHSUR P DECOMP -Install secondary valve in IA -RU to pump down IA 03:00 - 03:30 0.50 WHSUR P DECOMP -Pum down IA and test BPV and IA to 1000 six 10 min on chart. Good test. Did not observe communication to A conductor. -Bleed off pressure. 03:30 - 04:30 1.00 WHSUR P DECOMP -Mobilize lubricator to rig floor. 04:30 - 05:30 1.00 WHSUR P DECOMP -RD lubricator and mobilize off rig floor. -Install pump in flange on wing valve. -Check hard line w/air. Printed: 9/2/2006 11:46:56 AM BP EXPLORATION Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Event Name: WORKOVER Start: 7/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Page3of14~ Spud Date: 7/28/2008 End: 8/13/2008 Date From - To Hoursr Task ',Code NPT Phase Description of Operations 8/1 /2008 8/2/2008 04:30 - 05:30 1.00 WHSUR P 05:30 - 07:30 2.00 WHSUR P 07:30 - 10:30 3.001 WHSUR ~ P 10:30 - 12:00 I 1.50 I W HSUR I P 12:00 - 16:30 I 4.50 I W HSUR I P DECOMP -Test hard line to 3500 si w/ water. Good test. DECOMP -Pump 20 bbls seawater down IA, taking returns out tubing to tiger tank. 210 gpm / 660 psi -Blow down and swap lines to pump down tubing and take returns out IA -Pump 75 bbls seawater down tubing, taking returns out IA to tiger tank. 210 gpm / 740 psi -Wait 30 min. for diesel migration. Pump additional 30 bbls seawater down tubing, taking returns out IA to tiger tank DECOMP -Observe well off balance -Cont. circulating well w/ seawater surface-surface. 210 gpm / 880 - 600 psi -Blow down lines. Verify well in balance. DECOMP -Cameron Re . d rod TWC -Test TWC f/ below to 1000 psi x 10 min on chart. Good test DECOMP -Attemt to test TWC f/ above to 3500 psi x 10 min w/ test -RU injection line to wing. Pressure up w/mud pump and set poppet. -Attempt to test again TWC f/ above w/ test pump. Observe ve t n win valve startin to leak. -Repack valve steam on wing valve. -Test TWC f/ above to 3500 gsi x 10 min on chart. Good test. 16:30 - 19:30 3.00 WHSUR P DECOMP -ND tree and adapter flange. -Check LDS -Reinstall secondary valve in IA 19:30 - 23:00 3.50 BOPSU P DECOMP NU 13 5/8" 5M BOP -BOP configuration (from top to bottom): 1. 13 5/8" 5M Annular preventer 2. 3 1/2" x 6" VBR (top rams) 3. 13 5/8" Blind Rams 4. Mud cross w/ choke line and kill line 5. 2 7/8" x 5" VBR (bottom rams) 23:00 - 00:00 1.00 BOPSU P DECOMP RU to test BOP 00:00 - 02:00 2.00 BOPSU P DECOMP -Cont. RU to test BOP -Modify and reinstall riser 02:00 - 03:30 1.50 BOPSU P DECOMP -Attempt to test annular preventer. No success. -Troubleshoot leak. Open annular preventer. Close bottom rams, pressure up to 3500 psi and identify leak by TWC. -Pressure up to 4000 psi x 3 times and set poppet. -Pressure up to 3500 psi w/ bottom rams closed and obtained good test. -Proceed to test BOP 03:30 - 08:00 4.50 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart. Test components w/ 4" test jt. Test top rams and bottom rams w/ 4" and 4-1/2" test jts. Test witnessed by WSL and Tourpusher. John Crisp, AOGCC Rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3100 psi 2. Pressure after close: 1900 psi Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: , I ~ NPT Phase Description of Operations Code Date .From - To Hours Task 8/2/2008 03:30 - 08:00 4.50 BOPSU P DECOMP 3. 200 psi attained at 35 sec 4. Full pressure attained at 2 min 52 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 29 components: 1. 13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 08:00 - 08:30 0.50 BOPSU P DECOMP RD testing equipment. Blow down top drive 08:30 - 11:00 2.50 WHSUR P DECOMP -PU lubricator extensions and MU to lubricator. MU pulling tool and rods -Set lubricator and extensions in BOP stack. Close top rams -Test lubricator to 500 six 5 min. Good test -Pull TWC. Observe no pressure after pulling TWC -Pull lubricator and extensions with TWC. -RD lubricator and extensions. Mobilize off rig floor 11:00 - 12:30 1.50 PULL P DECOMP Cut 150' excess drilling line used to LD top drive for rig move 12:30 - 14:00 1.50 PULL P DECOMP -MU 1 jt 4" DP and XOs. -RIH and screw in tubing hanger. BOLDS -Pull tubin han er to ri floor. Han er ulled free with 175k PUW / 150k PUW after pulling hanger free (blocks weight 50k) 14:00 - 15:00 1.00 PULL P DECOMP -Pump 40 bbls Safe Kleen pill and chase w/ 50 bbls seawater -Pump 40 bbls Safe Scav pill. -Continue circulating w1 seawater until Safe Kleen pill returned to surface. 381 gpm / 350 psi -Left Safe Scav pill in casing to pull tubing through it. 15:00 - 16:30 1.50 PULL P DECOMP -RU equipment to LD tubing -RU control line spooling unit -LD tubing hanger 16:30 - 19:00 2.50 PULL P DECOMP -Pull and LD 4-1/2" 12.6# 13Cr80 NSCT tubing to SSSV. -Recover 1/4" SS control line, 4 SS bands and 25 rubber clamps. 19:00 - 19:30 0.50 PULL P DECOMP -RD control line spooling unit and mobilize off rig floor -Install air slips 19:30 - 00:00 4.50 PULL P DECOMP Cont. pulling and LD 4-1/2" 12.6# 13Cr80 NSCT tubing and completion equipment (190 jts LD at report time). 8/3/2008 00:00 - 01:00 1.00 PULL P DECOMP Finish pulling and LD 4-1/2" 12.6# 13Cr80 NSCT tubing and completion equipment -Total LD: 211 jts tubing +SSSV + 5 GLMs + X nipple + 3.85' cutoff pup jt. -Jet cut uniform. Flare to 5" OD -Length f/ tubing stub to next collar: 6.26' 01:00 - 02:00 1.00 PULL P DECOMP -RD tubing handling equipment. Clean same and mobilize off rig floor -Clean rig floor -Mobilize 5" elevators and wear bushing to rig floor 02:00 - 02:30 0.50 WHSUR P DECOMP -Install wear bushing Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~I, Code I~ NPT ~ Phase Description of Operations 8/3/2008 02:00 - 02:30 0.50 WHSUR P DECOMP -Center stack. 02:30 - 03:00 0.50 CLEAN P DECOMP Mobilize tools for dress off BHA to rig floor 03:00 - 05:00 2.00 CLEAN P DECOMP - A „dress off mill inside washover shoe + 9-5/8" casing scraper. -PU 6 ea 6-1/4" DCs 1x1 05:00 - 06:30 1.50 CLEAN P DECOMP PU 4" DP 1x1 f/ pipe shed and RIH w/dress off BHA. 06:30 - 07:00 0.50 CLEAN P DECOMP Screw in T.D. -Circulate to balance fluid w/ 8 bpm, 180 psi 07:00 - 11:00 4.00 CLEAN P DECOMP Continue RIH 1x1 w/ 4" DP to 8180' -Work 9 5/8" scraper across 90' area from 8180' to 8090' -Continue PUDP to 8248' 11:00 - 11:30 0.50 CLEAN P DECOMP Screw in T.D. -Obtain parameters -PUW 180k, SOW 162k, ROW 170k w/ 2-3k tq -Break circ. w/ 8 bpm, 1050 psi -Ta 4 1/2" t b'n t t -Dress off Lubin to 8271' w/ 60 rpm 2-3k tq -Work over tubing w/ no rotary -Clean 11:30 - 13:00 1.50 CLEAN P DECOMP Pump H.V. sweep around w/ 9 bpm, 1180 psi 13:00 - 14:00 1.00 CLEAN P DECOMP Swallow 4 1/2" stub -RU and reverse circ. BU w/ 9 bpm, 1800 psi 14:00 - 17:00 3.00 CLEAN P DECOMP Observe well - POH 17:00 - 18:30 1.50 CLEAN P DECOMP -Rack back 6-1/4" DCs -LD dress off BHA. Mobilize tools off rig floor -Inspect dressoff mill -Good wear pattern on mill 18:30 - 19:30 1.00 DHB P DECOMP MU 9-5/8" RBP er Halliburton Re . 19:30 - 23:30 4.00 DHB P DECOMP -RIH w/ RBP to 8200'. Obtain parameters: PUW 165k /SOW 150k -Set RBP per Halliburton Rep. COE ~ 8193'. Top of fishing head ~ 8189' -Test RBP and casin to 3500 six 30 min on chart. Good 23:30 - 00:00 0.50 DHB P DECOMP POOH w/ RBP running tool 8/4/2008 00:00 - 02:30 2.50 DHB P DECOMP Cont. POOH w/ RBP running tool. LD RBP running tool. 02:30 - 04:00 1.50 EVAL P DECOMP PJSM w/ Schlumberger E-line crew -RU for 9 5/8" USIT log 04:00 - 04:30 0.50 EVAL P DECOMP RIH w/ USIT tools to 780'. Tool failed 04:30 - 09:00 4.50 EVAL N DFAL DECOMP -POOH and trouble shoot tools. Circuit in head -Rewire head -Test at surface 09:00 - 11:30 2.50 EVAL P DECOMP RIH w/USIT tools to 2820' -Log up to surface in cement evaluation mode -E-Line estimate to of cement at 2100' -Questionable area from 1800'-1900' 11:30 - 12:30 1.00 EVAL P DECOMP Break down E-line tools -RD sheaves 12:30 - 13:00 0.50 DHB P DECOMP MU 9 5/8" RBP r HES r 13:00 - 14:00 1.00 DHB P DECOMP RIH w/ 4" DP to 1920' 14:00 - 14:30 0.50 DHB P DECOMP Sot RBP at 1909' C.O.E. -Set w/ 1 turn left and release running tool -C.O.E.= 1909' -Top = 1905' 14:30 - 15:00 0.50 DHB P DECOMP Displace well w/ 9.8 ppg brine 15:00 - 15:30 0.50 DHB P DECOMP RU test equipment -Test RBP / Casin to 1500 si f/ 15 min. on chart -Good test Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/4/2008 15:30 - 17:00 1.50 DHB P DECOMP Pull one stand. Dump 2200# 20-40 Mesh sand. Pump 1/2 DP volume ~ 1 bpm. 17:00 - 18:00 1.00 DHB P DECOMP Wait for sand to settle. 18:00 - 18:30 0.50 DHB P DECOMP RIH and tag top of sand C~ 1851'. 18:30 - 19:30 1.00 DHB P DECOMP POOH w/ RBP running tool. LD RBP running tool. 19:30 - 20:30 1.00 PULL P DECOMP -Mobilize casing cutter to rig floor -MU casing cutting BHA 20:30 - 21:30 1.00 PULL P DECOMP RIH w/ casing cutting BHA to 1730' at controlled speed. 21:30 - 23:00 1.50 PULL P DECOMP -PJSM. Break circulation and locate collar ~ 1780'. Pull and position cutter C~3 1760'. -Spot Little Red units and vaccum trucks. 23:00 - 23:30 0.50 PULL P DECOMP -Cut 9-5/8" casin @ 1760'. PUW 77k /SOW 75k / ROTW 75k / 0-5k torque -Close annular preventer. Line up OA to tiger tank. Establish circulation throuah OA out to tiaer tank (break circulation with 600 psi). -Stop pump. Open annular preventer. Drop dart and shear pump out sub. -Close annular preventer. RU Little Red to pump diesel down drill pipe. Pressure test Little Red lines to 3000 psi. 23:30 - 00:00 0.50 PULL P DECOMP -Little Red pumping hot diesel down drill pipe, taking returns out OA to tiger tank. 1.5 bpm / 450 psi -No fluids comin throu h 20" conductor and flutes. 8/5/2008 00:00 - 01:00 1.00 PULL P DECOMP Displacing arctic pac out OA -Finish pumping 100 bbls hot diesel with Little Red, taking returns out OA to tiger tank. 1.5 bpm / 300 psi FCP -Chase diesel w/ 23 bbls hot hi-vis sweep. -Shut in OA. Blow down hard line to tiger tank -No fluids coming through 20" conductor and flutes 01:00 - 02:30 1.50 PULL P DECOMP Let diesel soak in OA. 02:30 - 04:00 1.50 PULL P DECOMP -Pump 50 bbls 9.$ ppg hot brine + 40 bbls hot hi-vis sweep taking returns out OA to tiger tank. -Continue ciculating with 190 bbls 9.8 ppg hot brine, taking returns out OA to tiger tank until returns clean. 9.5 bpm / 650 psi -Shut in OA. Blow down hard line to tiger tank. Open annular preventer. -Circulate until clean. 04:00 - 05:30 1.50 PULL P DECOMP POOH w/ casing cutter, -LD Cutter BHA -Knives show good wear pattern 05:30 - 06:00 0.50 PULL P DECOMP Pull wear ring -Clear floor -Mob spear BHA to floor 06:00 - 06:30 0.50 PULL P DECOMP PJSM -PU single 4" DP -Spear assembly -Engage 9 5/8" hanger -BOLDS 06:30 - 07:30 1.00 PULL P DECOMP Pull hanger & packoff free w/ 175k -Pull to ri floor w/ 125k -Break circ. - CBU X2 w/ 12 bpm, 1100 psi 07:30 - 08:00 0.50 PULL P DECOMP Mobilize casing equipment to rig floor Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Operations Summary Report Page 7 of 14 ~ Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date. From - To ,Hours Task Code NPT Phase Description of Operations 8/5/2008 08:00 - 09:00 1.00 PULL P DECOMP -Break out 4" DP single and LD same. -Disengage spear and LD same. -Cont RU casing equipment 09:00 - 13:30 4.50 PULL P DECOMP -Break out and LD casing mandrel hanger -Pull and LD 9-5/8" 47# L-80 BTC casino. -Breaking connections w/ rig tongs - 25k-35k breakout torque -Total LD: 44 jts + 19.33' cutoff jt. 13:30 - 14:30 1.00 PULL P DECOMP -RD casing equipment. -Clean pollution pan and clear rig floor. 14:30 - 15:00 0.50 WHSUR P DECOMP Install wear bushing 15:00 - 16:00 1.00 CLEAN P DECOMP -Mobilize tools to rig floor. -MU casing dress off BHA w/ 12-1/4" x 9-5/8" Washover shoe, 11-3/4" Washover extension with internal dress off mill and 13-3/8" casing scraper. 16:00 - 18:00 2.00 CLEAN P DECOMP RIH w/ casing dress off BHA to 1738' -Circulate BU ~ 600' and 1200' to clean hole of arctic pac build up around casing scraper. 18:00 - 19:30 1.50 CLEAN P DECOMP -Circulate BU ~ 1738'. 10 bpm / 390 psi -Obtain parameters PUW: 87k /SOW: 87k / ROTW: 90k -Wash down and tag casing stub ~ 1760'. Work with Washover shoe and swallow 7' inside washpipe extension. Dress off top of casing stub w/dress off mill. 60 RPM / 0-5k Torque. -Circulate hi-vis sweep surface-surface. 10 bpm / 390 psi 19:30 - 20:00 0.50 CLEAN P DECOMP POOH w/ casing dress off BHA 20:00 - 22:00 2.00 CLEAN P DECOMP -Rack back DCs and LD casing dress off BHA. -Clear rig floor of tools not needed for next operation 22:00 - 23:00 1.00 CLEAN P DECOMP -Mobilize 13-3/8" RTTS to rig floor. -RIH 2 stands of 6-1/4" DCs. MU 1'3-3/8" RTTS per HES Rep. 23:00 - 23:30 0.50 CLEAN P DECOMP RIH and set 13-3/8" RTTS ~ 513' COE 23:30 - 00:00 0.50 CLEAN P DECOMP Test 13-3/8" casing below RTTS to 2000 psi x 10 min on chart. 8/6/2008 100:00 - 01:00 I 1.00 I CLEAN I P 01:00 - 02:00 I 1.001 CLEAN I P 02:00 - 02:30 0.50 WHSUR P 02:30 - 04:30 2.00 CASE P 04:30 - 11:00 I 6.50 I CASE I P - u~ tom. Pressure up above RTTS to 500 psi. Pressure bleeds to 0 in aprox. 5 min. -Keeps pressuring up above RTTS to 500 psi and letting it bleed until observing fluid coming through conductor in Cella (takes aprox. 0.1 bbls to pressure up to 500 psi f/ 0 psi). Pump during 10 min in the following way: pump until pressure reaches 500 psi. Shut pump and let pressure bleed to 400 psi. Pump again and repeat process. Pump away a total of 0.6 bbls in 10 min this way. -Bleed pressure. Open rams. RD testing equipment DECOMP -Unseat RTTS -POOH w/ RTTS -Rack back DCs -LD RTTS. Mobilize off rig floor DECOMP Pull wear bushing -Mobilize equipment needed to rig floor. RU side door elevators and power tongs. -Install torque turn equipment. DECOMP -PJSM on running casing. Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To 'i Hours Task Code NpT Phase Description of Operations 8/6/2008 04:30 - 11:00 6.50 CASE P DECOMP -MU 9-5/8" casing patch assv +HES ES-Cementer + 9-5/8" XO BTC in x HYD 563 box. Bakerlock connections below ES-Cementer -Run 9-5/8" 47# L-80 HYD 563 casin w/ casin atch. Torque turn all connections. Install 1 straight bladed centralizer every jt on jts 1-44. Total casing run: 45 jts. 11:00 - 11:30 0.50 CASE P DECOMP PU 15' pup -Tag tog of 9 5/8" stub at 1760' - PU 4' -MU XO's from T.D. to 9 5/8" Hyd. and torque same 11:30 - 12:00 0.50 CASE P DECOMP Obtain parameters - PUW 122k -SOW 125k -Break circ. w/ 5 bpm, 40 psi -Rotate down over stub w/ 5-10 rpm -Observe pressure increase -Stop pumps & rotary -Set down 35k weight - PU & pull test to 250k -Slack off to 225k (100k overpull) -Bottom of casing patch C~ 1763' (3' swallow). ES Cementer ~ 1746'. 12:00 - 12:30 0.50 CASE P DECOMP Pressure u to 2000 si f/ 30 min. on chart 12:30 - 13:30 1.00 CASE P DECOMP Pressure to 3300 si too en ES cementer -PJSM w/all involved w/ cement operations -Circulate until 85 degree returns achieved. 13:30 - 15:00 1.50 CASE P DECOMP RD 4" pup & XO's -RU HES cement head 15:00 - 16:00 1.00 CASE P DECOMP Give to Schlumberger -Pump 2 bbls H2O -Test lines to 4000 psi -Pum 134 bbls 15.8 p Class "G" cement w/ GasBlok -Drop Closing plug and kick out w/ 1 bbls cement -Flush lines w/ 2 bbls H2O 16:00 - 16:30 0.50 CASE P DECOMP Displace w/ rig pumps using 8.5 ppg seawater -9 bpm, 250 psi - Caught up to cmt at 45 bbls away -Slow pumps to 7 bpm 300 psi -Close annular and open "OA" through choke and divert to slop tank -Cement back at 925 stks -Choke back w/ 500-650 si on OA . -Returns to cellar -Cement at 13 3/8" hanger w/ 1000 stks away -Bump closing lu and observe ES cementer close w/ 3000 i sL -Hold for 10 min -Check floats - OK - CIP at 16:15 hrs. 16:30 - 17:00 0.50 CASE P DECOMP Flush hard line to slop tank. Flush BOP stack. RD cement head. Blow down lines. 17:00 - 20:30 3.50 WHSUR P DECOMP -Suck out water f/ 9-5/8" casing. -ND BOP and break tubing spool flange 20:30 - 22:30 2.00 WHSUR P DECOMP -Install emergency slips per Cameron Rep. -Hang 9-5/8" casing w/ 100k overpull. RILDS. -Cut 9-5/8" casing w/ Wachs cutter per Cameron rep. Pull 20.88' cutoff jt w/ pup and XO. LD same. 22:30 - 00:00 1.50 WHSUR P DECOMP C/O tubing spool. 8/7/2008 00:00 - 01:30 1.50 WHSUR P DECOMP -Cont. installing new tubing spool. -Install choke line and turnbuckles 01:30 - 02:00 0.50 WHSUR P DECOMP Test 9-5/8" packoff to 3800 psi x 30 min per Cameron Rep. Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 9 of 14 .Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT .Phase Description of Operations 8/7/2008 01:30 - 02:00 0.50 WHSUR P DECOMP Test good. 02:00 - 03:30 1.50 BOPSU P DECOMP -Cont. NU BOP. Install riser, flow line, hole fill line and bleeder line. -Install secondary valve in IA 03:30 - 05:00 1.50 BOPSU P DECOMP -RU to test breaks. Install test plug and 4" test jt. Close top rams. -Test breaks to 250 psi low - 3500 psi high x 5 min each on chart. -Test witnessed by WSL and Tourpusher. 05:00 - 06:00 I 1.001 BOPSUR P 06:00 - 06:30 0.50 CLEAN P 06:30 - 09:30 3.00 CLEAN N 09:30 - 10:30 1.00 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 15:00 4.00 CLEAN P 15:00 - 15:30 0.50 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 17:30 1.00 CLEAN P 17:30 - 18:30 1.00 CLEAN P 18:30 - 19:30 1.00 CLEAN P 19:30 - 21:00 1.50 CLEAN P 21:00 - 21:30 0.50 CLEAN P 21:30 - 22:30 1.00 CLEAN P 22:30 - 23:00 0.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 8/8/2008 00:00 - 00:30 00:30 - 01:00 01:00 - 01:30 0.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 01:30 - 02:30 02:30 - 03:30 1.00 CLEAN P 1.00 CLEAN P DECOMP RDtesfequip. -Install wear ring -Blow down choke & kill lines DECOMP Mob. clean out BHA to floor RREP DECOMP Repair rotating drive motor on T.D. -Clean rig floor DECOMP MU Clean out BHA -8 1/2" bit, 2 boot baskets, 9 5/8" scraper & jars -RIH w/ 6 1/4" DC's DECOMP RIH w/ 4" DP -Tag cement at 1710' DECOMP Screw in T.D. -Obtain parameters -PUW 85k -SOW 85k -ROW 85k at 80 rpm, 2k tq -Clean out cement f/ 1710' -Tag plug at 1746' -Control drill plug / ES cementer w/ 100-120 rpm, 3-5k WOB -Clean out cement to 1810' -Wash & Ream w/ no weight to DECOMP CBU 1.5x w/ 9 bpm, 350 psi DECOMP RU test equip. -Test 9 5/8" casino to 3500 psi f/ 30 min. on chart -Good DECOMP -Tap top of sand ~ 1855'. -Dry drill 3'. PU and let sand settle. Repeat process. -PU 20'. Pump Hi-vis sweep and circulate BU 2x. 380 gpm / 420 psi DECOMP -Slip and cut drilling line (59.5') -Service top drive. DECOMP POOH w/ clean out BHA. DECOMP -LD 6 ea. 6-1/4" DCs. -LD clean out BHA. Clean boot baskets: piece of brass pin, piece of washer and aluminum piece from ES Cementer. -Clear rig floor DECOMP -Mobilize RCJB to ri floor -MU RCJB 8HA DECOMP RIH w/ RCJB. Tag top of sand C~ 1858' DECOMP Clean w/ RCJB f/ 1858' to 1868'. 5 bpm / 3060 psi DECOMP POOH w/ RCJB. Clean RCJB: aluminum pieces f/ ES Cementer. DECOMP RIH w/ RCJB (2nd trip). Tag top of sand Cry 1863'. DECOMP Clean w/ RCJB to 1 8 . 7 bpm, 2800 psi. Rotate up. DECOMP POOH w/ RCJB. Clean RCJB: aluminum piece from ES Cementer DECOMP RIH w/ RCJB 3rd tri Ta sand ~ 1863' DECOMP Clean w/ RCJB to 1893'. 8 bpm / 2980 psi. Rotate up Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Weil Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code'I NPT I Phase Description of Operations 8/8/2008 03:30 - 04:30 1.00 CLEAN P DECOMP POOH w/ RCJB. Clean RCJB: big aluminum piece from ES Cementer -Gather all pieces recovered and have all big pieces from ES __ Cementer aluminum sleeve. -Verify w/ HES Rep. that conditions OK to run RBP running tool to wash out sand and retrieve RBP C~3 1905', 04:30 - 05:00 0.50 CLEAN P DECOMP -LD RCJB assy. Mobilize off rig floor. -Mobilize RBP runnin tool to ri floor. 05:00 - 06:00 1.00 DHB P DECOMP -PU RBP running tool -RIH w/ RBP running tool to 1820' -MU top drive. Run down and tag top of sand ~ 1861'. -PU. Break circulation. Wash out sand f/ 1861' to 1907'. Latch RBP. 390 gpm / 370 psi 06:00 - 07:00 1.00 DHB P DECOMP Circulate hi-vis sweep surface to surface until hole clean of sand. 390 gpm / 370 psi 07:00 - 07:30 0.50 DHB P DECOMP -Unseat RBP er HES Re . -Verify RBP free. 07:30 - 08:00 0.50 DHB P DECOMP -Flow chek well -POOH w/ RBP and running tool 08:00 - 08:30 0.50 DHB P DECOMP -LD RBP and running tool -Clear rig floor 08:30 - 10:30 2.00 EVAL P DECOMP RU Schlumber er E-line ui ment w/air line wi er. 10:30 - 14:00 3.50 EVAL P DECOMP -RIH w/ USIT tool to 4000' -Take USIT log in cement evaluation mode f/ 4000' to surface. 14:00 - 14:30 0.50 EVAL P DECOMP RD Schlumberger E-line equipment. 14:30 - 16:00 1.50 CLEAN P DECOMP -MU RBP running tool -RIH w/ RBP runnin tool to 4100' 16:00 - 16:30 0.50 CLEAN P DECOMP Circulate C~ 4100'. 255 gpm / 400 psi 16:30 - 18:00 1.50 CLEAN P DECOMP Cont RIH w/ RBP running tool to +/- 8150'. 18:00 - 20:30 2.50 CLEAN P DECOMP Circulate well to bring warmer fluid from bottom up in the well. 255 gpm / 550 psi. -Fluid going in ~ 105 F (temperature in pits) 20:30 - 22:00 1.50 CLEAN P DECOMP Displace well w/ clean hot 2% KCI water. 320 gpm / 880 psi 22:00 - 00:00 2.00 CLEAN P DECOMP Cont. circulating well with hot 2% KCI water. 210 gpm / 350 psi. -Temperature in: 107 F /Temperature out: 100 F 8/9/2008 00:00 - 02:00 2.00 CLEAN P DECOMP Cont. circulating w/ hot 2% KCI water ~ 8150'. Fluid temp. ~ t00 F. 02:00 - 03:00 1.00 DHB P DECOMP -PU 1 jt 4" DP. RIH and latch RBP ~ 8189' -Unseat RBP er HES Re ri -Check well for flow. Well static. Disconect top drive and LD DP single. Observe fluid U-tubing into DP. -MU top drive and circulate DP volume. -Disconnet top drive and check well. In balance. 03:00 - 03:30 0.50 DHB P DECOMP -RU testing equipment. -Test 9-5/8" casing and IBP to 1000 psi x 10 min on chart. Good test. -RD testing equipment and blow down lines 03:30 - 07:30 4.00 CLEAN P DECOMP POOH w/ RBP f/ 8165' -LD & inspect - OK 07:30 - 08:00 0.50 WHSUR P DECOMP Pull wear ring 08:00 - 08:30 0.50 BOPSU P DECOMP Install test plug -RU to test BOPE 08:30 - 12:30 4.00 BOPSU P DECOMP Test BOP and related eauipment per BP / AOGCC procedures Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task 'I Code' NPT Phase Description of Operations 8/9/2008 08;30 - 12:30 4.00 BOPSU P DECOMP and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart. Test components w/ 4" test jt. Test top rams and bottom rams w/ 4" and 4-1/2" test jts. Test witnessed by WSL and Toolpusher. Chuck Scheve, AOGCC Rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3200 psi 2. Pressure after close: 1800 psi 3. 200 psi attained at 28 sec 4. Full pressure attained at 2 min 43 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 29 components: 1. 13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 12:30 - 13:00 0.50 BOPSU P DECOMP -RD testing equipment. Blow down choke and kill lines. -Install wear bushing 13:00 - 14:30 1.50 EVAL P DECOMP RU Schlumberger E-line equipment and air line wiper. 14:30 - 18:00 3.50 EVAL P DECOMP RIH w/ USIT/CBWDL tool to 4000' and log to surface. 18:00 - 19:30 1.50 EVAL P DECOMP RD Schlumberger E-line equipment. 19:30 - 22:00 2.50 FISH P DECOMP -Mobilize tools for GS Spear BHA to rig floor -MU GS Spear BHA w/ 8-1/8" Guide and extension (GS Spear inside) + Washpipe Shear Pin Guide Assy + 6 jts 2-7/8" Pac DP. 22:00 - 00:00 2.00 FISH P DECOMP RIH w/ GS S ear BHA to fish 'unk catcher set on XN ni le in tubin stub ~ 842 '. 8/10/2008 00:00 - 01:00 1.00 FISH P DECOMP Cont. RIH w/ GS Spear BHA to top of tubing stub ~ 8270' 01:00 - 02:30 1.50 FISH P DECOMP -PU and break circulation ~ 3 bpm / 1700 psi. -Obtain parameters: PUW 170k /SOW: 148k / ROTW: 160k (15 RPM) -Shear pins and wash down in tubing stub w/ 2-7/8" PAC DP. Ta 'unk catcher ~ +/- 8426'. Set 10k on 'unk catcher. 02:30 - 04:00 1.50 FISH P DECOMP -Wash over junk catcher. -Shut pump. Latch junk catcher. -Pull to max. 250k several times attem tin to free 'unk catcher. -Start pumping again and release GS Spear f/junk catcher. Wash over junk catcher. -Shut pumps and latch on junk catcher again. -Pull to 200k and 'unk catcher came free. Verify junk catcher free. 04:00 - 05:30 1.50 FISH P DECOMP -Set 10k on junk catcher. Drop dart and pump down drill pipe C~3 2.5 bpm -Shear open pump out sub. Wash out debris, 9 bpm / 1170 psi Printed: 9/2/2008 11:46:56 AM • • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: Frorn - To H-11 H-11 WORKO DOYON DOYON Hours VER DRILLI 14 Task G INC 'Code . NPT Start Rig Rig Phase Spud Date: 7/28/2008 : 7/28/2008 End: 8/13/2008 Release: 8/13/2008 Number: Description of Operations 8/10/2008 04:00 - 05:30 1.50 FISH P DECOMP -Flow check well -Make and pump dry job. 05:30 - 08:30 3.00 FISH P DECOMP POH and LD 4" DP to 4000' 08:30 - 10:00 1.50 FISH P DECOMP POH stand back DP f/ 4000' to 210' 10:00 - 12:00 2.00 FISH P DECOMP LD XO's, B.S., 5 joints 2 7/8" PAC. No Fishl GS S a h bl B k id 12:00 - 15:00 3.00 FISH P DECOMP f2,; r ( ear gu e assem y. - rea s -Load 4" DP in shed -Strap same -Prepare spear 15:00 - 16:30 1.50 FISH P DECOMP MU Spear BHA w/ 8-1/8" Guide and extension (Spear inside) + Washpipe Shear Pin Guide Assy + 6 jts 2-7/8" Pac DP. a 16:30 - 22:00 5.50 FISH P DECOMP -RIH on 4" DP stand f/ derrick to 3810'. Leave 2 stands on derrick to wash down inside tubing stub. -Cont. RIH on singles f/ pipe shed to 8266'. 22:00 - 23:30 1.50 FISH P DECOMP -Cut and slip drilling line (59.5') 23:30 - 00:00 0.50 FISH P DECOMP Obtain parameters before entering tubing stub: PUW 165k / SOW 150k. 3.5 bpm ~ 1680 psi 8/11/2008 00:00 - 02:00 2.00 FISH P DECOMP -Ta tb stub ~ 8270'. Swallow 10' in washpipe extensions. Set weight on shear pin guide assy. and shear pins w/ 12k. -Wash down in tubing stub w/ 3.5 bpm ~ 930 psi. Tag junk catcher C~ 8426'. -En a e 'unk catcher. Set down 15k on No Go (XO on top of spear). -Work pipe f/ 250k -315k pull. Increase pump to 5 bpm ~ 2000 psi. Pull junk catcher free w/ 315k pull. Lost returns when sunk catcher pulled free. 02:00 - 04:00 2.00 FISH P DECOMP -POOH w/drag, working pipe to max. 350k. Pull and break out 2 jts DP. LD 1 jt DP to pipe shed. Leave 1 jt DP in mouse hole. -Cont. working pipe. PU jt DP f/ mouse hole. Work pipe and POOH w/drag. Pulling max. 350k until working whole stand free. Rack back stand. POOH another stand until came out of tubing stub and rack back (bottom of BHA ~ 8237'). -No returns. Pum in fluid on back side thoru h hole fill line. No fluid level observed. 04:00 - 05:00 1.00 FISH P DECOMP Monitor well and wait on fluid. -Wait on DHD for fluid level shots 05:00 - 08:00 3.00 FISH P DECOMP Take on seawater to pits (3 loads) -DHD RU and shoot fluid levels. Several shots show 2100' 08:00 - 11:30 3.50 FISH P DECOMP POH LD 4" DP f/ 8327' to 3816' using calculated displacement + 60 bph 11:30 - 12:00 0.50 FISH P DECOMP POH standing back 4" DP in derrick using calcualted displacement + 60 bph -Fluid loss for tour = 387 bbls 12:00 - 13:00 1.00 FISH P DECOMP Continue POH standing back in derrick (40 stds total) using calculated displacement + 60 bph 13:00 - 14:30 1.50 FISH P DECOMP LD BHA - B.S. and XO's -6 jts 2 7/8" PAC -Shear guide assembly -Release S ear f/ fish Junk Catcher - LD same 14:30 - 15:30 1.00 FISH DECOMP Clean floor -Clear floor of vendor tools -Pull wear bushing 15:30 - 17:00 1.50 BUNCO RUNCMP RU to run 4 1/2 13CR tubing Printed: 9/2/2008 11:46:56 AM • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task I Code ! NPT ~ Phase Description of Operations 8/11/2008 15:30 - 17:00 1.50 BUNCO RUNCMP -Change elevators, bales -RU double stack tongs, compensator and torque turn equipment 17:00 - 00:00 7.00 BUNCO RUNCMP PJSM w/ all involved in operation -PU 9 5/8" X 4 1/2" Unique O.S. -Pups w/ "XN" nipple and RHC-M -Pups w/ "X" nipple - 9 5/8" x 4 1/2" Baker S3 packer - BakerLok all connections below packer -Run 4 1/2" 12.6# 13Cr80 VAM TOP tubin and com leti n e ui ment using compensator and torque turn to 4440 ft/Ibs to 4230' -Pumping 60 bph in IA while running completion. -Fluid loss for tour = 728 bbls 8/12/2008 00:00 - 06:30 6.50 BUNCO RUNCMP -Cont. running 4 1/2" 12.6# 13Cr80 VAM TOP tubing and completion equipment. -Utilize compensator and torque turn to 4440 ft/Ibs. -Ran 200 jts to 8271' (est.top of 4 1/2" stub) -Pumping 60 bph in IA while running completion. 06:30 - 08:30 2.00 BUNCO RUNCMP Obtain parameters - PUW 150k -SOW 130k -PU joints # 201 & 202 -No indication of stub at 8271' -Taking weight at 8276' -PU and work back down making 2' to 8278' guide depth (observe shear w/ 10k down wt.) -LD#202-PU 10'pup&4'pup -RU circ. head -Wash down - No pressure increase due to well being on Vac. -Take weight at 8281' and stack 15k down (O.S. guide depth) 08:30 - 09:30 1.00 BUNCO RUNCMP RU to reverse circ. with O.S. bottomed out -Fill annulus w/ 30 bbls seawater -PU and fluid fell immediately -Close annular - Circ down w/ 3 bpm, 40 psi -Observe pressure increase to 100 psi w/ 15k weight stacked on O.S. at 8281' -Bleed pressure -Open annular - PU to 8271' -Verify tag and spaceout depths 09:30 - 11:30 2.00 BUNCO RUNCMP LD pups and joint # 201 & 200 -PU spaceout pups (7.82', 3.84' and 2.35') and jt. # 200 -PU hanger -Land tubing at 8278.5' O.S. guide depth -RILDS 11:30 - 14:30 3.00 BUNCO RUNCMP R/U & Reverse circulate 456 bbls Seawater: -Pumped 126 bbls Seawater. -269 bbls Seawater w/ corrosion inhibitor. -Pump rate 126 GPM ~ 150-250 PSI. -No returns initially but partial returns out TBG after 200 bbls. 14:30 - 16:00 1.50 BUNCO RUNCMP Dro ball and rod down Tb , to off Tb w/ Seawater. -Set packer and test to 3500 PSI for 30 min., bleed off tb to -Top off annulus w/ Sewater. -Test annular to 3500 psi for 30 min. Bleed off TBG to shear , DCR valve. -Circulate down annulus 126 GPM at 300 PSI. -Circulate down Tbg 126 GPM ~ 140 PSI. 16:00 - 18:00 2.00 BUNCO RUNCMP UD landin JT. Install TWC., Printed: 9/2/2008 11:46:56 AM A • BP' EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: H-11 Common Well Name: H-11 Spud Date: 7/28/2008 Event Name: WORKOVER Start: 7/28/2008 End: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~' Code ~ NPT Phase Description of Operations 8/12/2008 16:00 - 18:00 2.00 BUNCO RUNCMP -Test from bottom to 1000 PSI, test from top to 3500 PSI. -Test for 10 minutes each and chart -Pass. 18:00 - 19:00 1.00 BOPSU P RUNCMP Blow down lines to stack and suck out fluid. 19:00 - 21:00 2.00 BOPSU P RUNCMP N/D BOP 21:00 - 00:00 3.00 WHSUR P RUNCMP NU Adapter flange and Tree. -Test flange/hanger void to 5000 PSI for 30 min. -Test tree to 5000 PSI for 10 min -Pass. 8/13/2008 00:00 - 01:30 1.50 WHSUR P RUNCMP RU DSM lubricator and test same 500 PSI for 5 min. - u u ricator. 01:30 - 02:30 1.00 WHSUR P RUNCMP RU to circulate freeze protect diesel. -Spot and hook up Hot Oil. Held PJSM with HOT OIL. 02:30 - 04:00 1.50 WHSUR P RUNCMP Test lines to 3500 PSI. Pumped 140 BBLS diesel down IA: - 2 BPM, 400 PSI at start - 2 BPM, 550 PSI at end 04:00 - 05:30 1.50 WHSUR P RUNCMP U-TUBE Diesel. 05:30 - 06:30 1.00 WHSUR P RUNCMP Cameron install BPV. Hot Oil test from bottom 1000 PSI for 10 min. 06:30 - 08:00 1.50 WHSUR P RUNCMP Install blank flanges. Remove double valve. -Secure Tree & cellar. Release Rig ~ 08:00 hrs. T/I/O = 0/0/0 Printed: 9/2/2008 11:46:56 AM 08/25/08 ~_ 3 ~,, S ., ~~ O ./'"' ~ASti~ ~,~~ ~~Fl~~~~~r~~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh !t ~~~.~~i~N~~ S E P ~ U 200$ Inn Ilncrrinfinn N0.4826 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ft~4u RI f`nlnr rr1 A-02 12086677 RST ~ - ( 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 A-13 12086676 RST (~ ~f 07/23/08 1 1 G-02A 11968945 RST s ~ 06/08/08 1 1 B-19A 12017500 RST / ~~ 06/14/08 1 1 15-18A 12005216 MCNL - ~ (~ -" 06/24/08 1 1 C-02 11982437 RST / O 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - G / 04/21/08 1 1 B-37 12034907 CH EDIT PDC-GR 06/10/08 1 V-207 11999031 MDT 07/23/08 1 1 V-207 11999031 MDT OUICKLOOK "~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /ip 08/iti/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) - ~ Q 07/28/08 1 1 B-18 11978471 USIT .. ~ / (p ~ ~ 08/04/08 1 1 05-31A 12057635 LDL - '~ 6 07/21/08 1 1 13-29L1 11962614 LDL Q - ~ 07/30/08 1 1 13-29L1 11966271 USIT - /(p 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 +~- ~ -at rLGMJC MV n1YVYYLCVVG I'SCVCIYI DT AIUIIVIIVU HIVU rTCI UFfIV11Vta VIVO GVYY CAI:rI IU: BP Exploration (Alaska) Inc. Petrotechnical Data Censer LR2-i ,~ .~.~ ~, ,~„.?~ 900 E. Benson Blvd. ~ { Anchorage, Alaska 99508 ~~~~~ ~~ ~ ~~~~1 Date Delivered: sl1 1. „ ~:~C;'T '':"ii Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth Received by: • fZ~ • • ~ ~ ~ ~ ~ ~: SARAH PALIN, GOVERNOR ALAS OII< A1sD lfA-7 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COMIIIISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~~~~ JUL ~ ZD08 Anchorage, AK 99519-6612 ~ d~~ ,fib ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-11 Sundry Number: 308-262 Dear Mr. Reem: 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, Jr. Chair DATED thi~ day of July, 2008 Encl. ~~~ ~ ~ ~ STATE OF ALASKA ~'~~~ ~` ALA OIL AND GAS CONSERVATION COM11~101~ ~ ~~ ~j-~ APPLICATION FOR SUNDRY APPROVAL ~~ ,.; 20 AAC 25.280 x,133(+3 e,,; ~' ~" 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time E en~sion ® Alter Casing _ ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 180-068 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20485-00-00 - 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: PBU H-11 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028284. 76.5' - Prudhoe Bay Field / Prudhoe Bay Pool 12- PRESENT WELL COND{TION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): "Plugs (measured): Junk (measured): 9875' - 9464' - 9830' 9420' 9070' None Casin Len th Size MD TVD Burst Colla se . Structural Conduct r 110' 20" x 30" 110' 110' Surface 2696' 13-3/8" 2696' 2696' 4930 2670 Intermediate 8942' 9-5/8" 8942' 8564' 6870 4760 Production Liner 1482' 7" 8391' - 9873' 8046' - 9462' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 9136' - 9304' 8749' - 8910' 4-1/2", 12.6# 13Cr80 8440' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW'HBBP' packer Packers and SSSV MD (ft): 8285' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 27 16. Well Status after proposed work: Commencin O erations: July?~1' 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: GINJ ^ WINJ ^ WDSPL ^ WAG ~ Commission Representative: ,, 18. I hereby certi .hat the foregoing is true and correct to the best of my knowledge. Contact Howard west, 564-5471 Printed Na a avid Re Titte Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~y a~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~LBOP Test ^ Mechanical Integrity Test ^ Location Clearance v~~ll S ~ ~ I ~ ~'~b~ Other: 3~p®~, l~~ ~~ Subsequent Form quired: ~~~-~ APPROVED BY ~ /~~ A roved B - COMMISSIONER THE COMMISSION Date VV Form 10-403 Revised 0 '006 j~J)RI~IIOIAL S ~: ~~11-. 2 9 2DDB Submit In Duplicate • • by c,~~ H-11 Expense Rig Workover Scope of Work: Pull 4-~/z" completion, cut and pull 9-5/8" casing, run and cement 9-5/e" casing to surface, run 4-'/z" 13Cr-80 tubing with Baker S-3 packer set at 8,100' MD. MASP: 2400 psi Well Type: Ivishak Producer Estimated Start Date: July 21, 2008 Production Engineer: Jennifer Starck Intervention Engineer: Howard West Pre-rip prep work: S 1 Drift for 4.5" 'et cutter. Set 4-1/2" ~unk catcher in XN ni le at 8,428'. E 2 Power Jet cut 4-~/z" 13Cr-80 tubing at 8267' MD, in the top third of the 1S pup joint above the TIW acker. Reference tubin tall dated 11/06/92. F 3 Circulate well with seawater and diesel thru the cut. CMIT TxIAxOA to 2000 si W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Doyon 14. ND tree. NU and test BOPE pipe rams to 3500 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 4-~/z" tubing string down to the tubing cut. 3. Run USIT log to determine top of cement in the 9 6/s" casing. 4. Set and test 9 5/e" RBP approximately 100' below estimated TOC. Note: The VBRs in the BOPs will NOT be changed over to 9-5/e" pipe rams as the barriers to the reservoir will be the tested 9-5/8" RBP and IBP in the 4'/z" tubing. 5. Cut and pull 9 5/8" above TOC. 6. Run and fully cement 9 5/8" casing to surface. 7. Pressure test new casing to 3500 psi 8. Drillout 9 5/8" shoe track. 9. Retrieve 9-5/8" RBP. 10. Remove junk. catcher in XN nipple at 8,428. 11. Run 4-'/z" 13Cr-80 tubing with Baker S-3 packer set at 8,100' MD. 12. Displace the IA to packer fluid and set the packer. 13. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 14. Set BPV. ND BOPE. NU and test tree. RDMO. E= 6-3/8" MCEVOY WELLHEAD,= -- - -- MCEVOY ACTUATOR = OTIS KB.'ELEV = 76.49' BF. ELEV = 47.29' KOP = 3200' Max Angle = 22 @ 8300' Datum MD = 9269' Datum N D = 8800' SS H -11 S NOTES: ***4-1/2" CHROMETBG*** 1967' 4-1/2" OTIS HXO SSSV NIP, ID = 3.813" 2608 - 9-5/8" DV PKR 13-3/8" CSC, 72#, L-80, ID = 12.347" ~-~ 2696' GAS LIFT MANDRELS Minimum ID = 3.725" @ 8428' 4-1 /2" OTIS XN NIPPLE OF 7" LNR ~~ 8391' ~~ 4-1/2" TBG 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~ 9-5/8" CSC, 47#, L-80, ID = 8.681" ~--{ $942' PERFORAT~N SUMMARY REF LOG: SWS-BHCS ON 09/14/80 ANGLE AT TOP PERF: 16 @ 9136' Note: Refer to R-oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9136 - 9146 C 04/19/90 3-3/8" 6 9156 - 9192 G 04/19/90 3-1/8" 8 9206 - 9244 C 05/08/81 3-1/8" 4 9254 - 9265 C 05/08/81 3-1/8" 8 9286 - 9304 C 06/14/81 PBTD 9830' 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 9873' ST MD ND DEV TYPE VLV LATCH PORT DATE 5 2998 2921 6 MERLA DMY RK 0 05/16/04 4 5076 4878 21 MERLA DMY RK 0 05/16/04 3 7224 6877 21 MERLA **DMY RK 0 05/16/04 2 7869 7484 21 MERLA DMY RK 0 1 8243 7908 22 Mff2LA PKT P142 RK 0 05/16/04 *"STATION if 3 = DMY I1AS EXTENDED PACKING $262' 4-1/2" OTIS X NIP, ID = 3.813" $2$3' LATCH ASSY 8285' 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 3.875" 8321' 4-1/2" OTIS X NIP, ID = 3.813" $42$' 4-1/2" OTIS XN NIP, ID = 3.725" $440' 4-1/2" TBG TAIL ID = 3.958" $431' ELMD TT LOGGED 11/11/92 9070' SAND TOP (01/05/08) 9100 3-3/8" BAKER IBP (01/05/08) 9181 --SAND PLUG 924 MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/19/80 ORIGINAL COMPLETION 09/25/05 MOR/TLH PXN TTP SET (10/08/04) WELL: H-11 01/07/92 RWO 05/29/06 CO/DTM PERF CORRECTION (6/13/2004) PERMff No: 1800680 08/15/01 RWKAK CORRECTIONS 01/08/08 Rtv~-USV SET IBP & SAND DUMP (01/05/08 ) API No: 50-029-20485-00 01/16/04 JLJ/TLH GLV GO SEC21, T11N, R13E, 1873' SNL & 1264' WEL 02/02/04 MWlTLP CHROME TBG CORRECTION 05/16/04 KSB/KAK GLV GO BP 6cploration (Alaska) TREE = 6-3/8" MCEVOY WELLHEADr MCEVOY ACTU~TOR = OT1S KB.'ELEV = _ 76.49' BF. ELEV = 47.29' KOP = 3200' Max Angle = 22 @ 8300' Datum MD = 9269' Datum TVD = 8800' SS ~ H -11 Proposed Completion S NOTES: ***4-1 /2" CHROME TBC~`** 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 3.725" @ 8428' 4-1 /2" OTIS XN NIPPLE TOP OF 7" LNR I-( 8391' ~~ 4-1/2" TBG 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 8942' PERFORATION SUMMARY REF LOG: SWS-BRCS ON 09/14/80 ANGLE AT TOP PERF: 16 @ 9136' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9136 - 9146 C 04/19/90 3-3/8" 6 9156 - 9192 C 04/19/90 3-1/8" 8 9206 - 9244 C 05/08/81 3-1/8" 4 9254 - 9265 C 05/08/81 3-1/8" 8 9286 - 9304 C 06!14/81 ~ PBTD ~ 9830' 7" LNR 29#, L-80, .0371 bpf, ID = 6.184~ 9873' 2100' 4-1/2" HES X NIP, ID = 3.813" 2608' 9-518" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV 5 4 3 2 1 4-1/2" HES X NIP, ID = 3.813" 9 5/8" X 4-1 /2" BAKER S-3 PKR 4-1/2" HES X NIP, ID = 3.813" 4-1 /2" HES XN NIP, ID 3.725" 8283' LATCH ASSY 8285' 9-518" X 4-1 /2" TNV HBBP PKR ID = 3.875" 8321' 4-1/2" OTIS X NIP, ID = 3.813" 8428' 4-1/2" OTIS XN NIP, ID = 3.725" $440' 4-1/2" TBG TAIL ID = 3.958" 8431' ELMD TT LOGGED 11/11/92 9181' I-ISANDPLUG 9249' I-I MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 09/19/80 ORIGINAL COMPLETION 09/25/05 MOR/TLH PXN TTPSET (10/08/04) WELL: H-11 01/07/92 RWO 05/29/06 CO/DTM PERF CORRECTION (6/13/2004) PERMff No: 1800680 08/15/01 RN/KAK CORRECTIONS 01/08/08 RMWSV SET IBP 8~ SAND DUMP (01/05/08 ) API No: 50-029-20485-00 01/16/04 JLJ/TLH GLV GO SEC21, T11N, R13E, 1873' SNL i~ 1264' WEL 02/02/04 MW/TLP CHROME TBG CORRECTION 05/16/04 KSB/KAK GLV GO BP Exploration (Alaska) • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ 1'iY~~o°,~ DATE: January 5, 2008 P. I. Supervisor ~~ ~~~ ~~~~ .1AN ~ ~: 200 FROM: John Crisp, SUBJECT: Well Secure Pressure test Petroleum Inspector PBU: H-11 BPX _... __ ...~.~. - PTD-'1~80-068 January 5, 2008: I traveled to BP's PBU to witness well secure sand tag & pressure test on well H-11. 7" liner top @ 8391'. Top perforation in 7" liner @ 9136'.9 5/8" x 4'/2" packer set @ 8285'. Coil tubing service Rig 8 set IBP @ 9100'. Sand was placed on IBP for well secure. I witnessed sand tag @ 9070' with coil tubing 3 1/8" OD nozzle. 700 Ibs ~ were placed on sand 3 times with no movement of sand top. I witnessed pressure test thru tubing of 7" liner from TOS @ 9070' to TOL @ 8391'. I witnessed pressure test of 9 5/8" casing from TOL @ 8391' to perforation side of packer @ 8285'. Pretest pressures Initial pressures 15 min. test pressure 30 min. test pressure Summary: Successf Tubing - 0 IA - 0 OA - 0 Tubing - 2895 IA - 0 OA - 0 Tubing - 2852 IA - 0 OA - 0 Tubing - 2793 IA - 0 OA - 0 ultuhing-casing test & sand plug tag witnessed. ~' Attachments: BPX H-11 well plat~f." `~~~e.c NON Confidential PBU H-11 well secure O1-OS-08 jc.doc TRFF= R-3/8"MCEVOY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 76.49' BF. ELEV - 47.29' - Angle = _ 3200' 22 @ 8300' Datum MD = 9269' batum TV D = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" I-i 2696' Minimum ID = 3.725" @ 8428' 4-1 /2" OTIS XN NIPPLE Qi° '~ ~ U~ ~ vS ' TOP OF 7" LNR ~ 8391' `~ ~~1 Wtu.9 P~~ TBG 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 8~ 9-5/8" CSG, 47#, L-80, ID = 8.681" I-i 8942' PERFORATION SUMMARY REF LOG: SWS-BHCS ON 09I14I80 ANGLE AT TOP PERF: 16 @ 9136' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 9136 - 9146 C 04/19/90 3-3/8" 6 9156 - 9192 C 04119!90 3-1/8" 8 9206 - 9244 C 05/08181 3-1/8" 4 9254 - 9265 C 05/08/81 3-1/8" 8 9286 - 9304 C 06/14/81 PBTD -j 9830, 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9873' H-11 r C - -'' :~ NOTES.: ***4-1 /2" CHROME TBG*** 4-112" OTIS HXO SSSV NIP, ID = 3.813" 9-518" DV PKR r_n c I IFT MA NnRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2998 2921 6 MERLA DMY RK 0 05/16/04 4 5076 4878 21 MERLA DMY RK 0 05/16/04 3 7224 6877 21 MERLA **DMY RK 0 05/16/04 2 7869 7484 21 MERLA DMY RK 0 1 8243 7908 22 MERLA PKT PKR RK 0 05!16/04 ""S7 A I IUIV iF 3 = UIYI 7 FWa Cn~ crnury rr~~.rv~~.a 8262' 4-1/2" OTIS X NIP, ID = 3.813" 8283' -'LATCHASSY I 8285' 9-518" X 4-112" TNV HBBP PKR, ID = 3.875" 8321' 4-112" OTIS X NIP, ID = 3.813" 842$' 4-1 /2" OTIS XN NIP, ID = 3.725" 8428' 4-1/2" PXNTTP(10/08/04) 844Q' 4-1/2" TBG TAIL ID = 3.958" 8431' ELMDTT LOGGED 11/11!92 40`70 _.`S~ ~° ,~- g~~- l-Z,soo lbs SIac1c c~ ~ ~~, 800 lb s q~DOt ,33 8 8~.1~..eC- z R~ _ caw ~ ~- ~-~,q {~ g181'~ SAND PLUG MARKER JOINT . r, TE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff ~.~t9/80 ORIGINALCOMPLETION 09/25/05 MOR/TLH PXNTTPSET(10/08/04) WELL: H-11 01/07/92 RWO 05/29!06 CO/DTM PERF CORRECTION (6/1312004) PERMIT No: 1800680 08!15/01 RWKAK CORRECTIONS API No: 50-029-20485-00 ' ' 01/16/04 JLJ/TLH GLV GO WEL SNL & 1264 SEC 21, T11N, R13E, 1873 02/02/04 MW/TLP CHROME TBG CORRECTION 05/16104 KSB/KAK GLV GO BP Exploration (Alaska) • • Page 1 of 1 Maunder, Thomas E (DOA) From: Grimaldi, Louis R (DOA) Sent: Wednesday, January 02, 2008 7:59 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Subject: FW: H-11 Attachments: H-11 IBP Sand Final Program.pdf If you guys have not seen this program, here it is. Pretty sick well. Lou Page 1 of 1 Maunder, Thomas E (DOA) _. _ _ _ _ _ _ . __ _ _ __ _ _ _ From: Grimaldi, Louis R (DOA) Sent: Tuesday, January 01, 2008 1:56 PM To: Harris, Robert M Cc: Regg, James B(DOA); Maunder, Thomas E(DOA) ~_ Subject: RE: H-11 ~ ~7 ~.~~-O('o~ Hi Mark, Thanks for sending the program, I understand a Iittle better the objectives now. I think a witness of the pressure test on the I.B.P. set in the casing below the packer and above the perforations. I would like to be there before the sand slurry is ~aid on top to verify the depth of the plug (below TT). If things go very quickly call me when I.B.P. is in place or in the morning, which ever comes first. Thanx, Lou 659-3607 „ ~~.~~~~~; #~C? ~a' .~. ~ ~0~~ __ _ _ __ _ _ _ _ __ _ _ _ _ __ _ _ ___ _ From: Harris, Robert M [mailto:HarrisRM@BP.com] Sent: Tuesday, January O1, 2008 1:32 PM To: Grimaldi, Louis R (DOA) Subject: H-11 • ~p To: J. Bixby/C. Olsen Weli Operations Team Leads From: Kirk Forcade, Design Engineer Doug Cismoski, Wells Team Lead Jennifer Starck, H-Pad Engineer Subject: H-11 Well Secure AFE: PBHPDWLII-M Cost: $250 M Est.IOR: N/A Please perform the following well work to secure this weil. CAUTION: AOGCC needs to witness ALL work on this well. Call 24 hours prior to commencing any weliwork. 1. DHD Regular monitoring of WHP's and FL's while awaiting coil. (BIN B) (Need secondar containment in cellar 2. C Pull TTP ron and lu , set IBP, sand dum , CMIT T X IA (BIN B Current Status Gas Lift mandrels Last Tests Deviation: Deviation at Perfs Last Tag: Last Well Op.: Last TD Tag: Min. Restriction: H2S Info Gas Lift Producer - Shut-in w/TTP, Non-operabfe due to T x IA, Possible IA x OA, Surface Casing Leak, and Packer Leak All G~M dummied off 19-Apr-04: 5018 BFPD, 589 BOPD, 16,799 GOR, WC 88%, 16J MMSCF/D Max deviation is ~ 22 Degrees at 6,900' md. 13 to 17 degrees through perforated interval 4-Jun-05: 8,703' slm w/3.5" OD Tapered LIB 8-Jun-05: GLV change out - catcher sub at 8,702' slm 17-May-04: 9,281' corrected (current WBD incorrect) 3.725" ID @ 8,428' No Data - Max on Pad H-22 = 130 ppm SIBHP/T: 17-May-04: 3,184 psi, 227 Deg F Wellbore Volume: 605 bbls -(443 bbls in IA + 162 bbls in TBG & Liner) Tubulars: Tubing 4-1/2" 13-CR, Liner 7" L-80, Prod Csg 9-5/8" L-80 Packer TIW: Packer leak found with Sensa LDL WELL HISTORY: The well was drilled and completed in Sep of 1980. In Sep-92, the well was sanded back to 9,181' md. In preparation for the frac, the tubing ruptured resulting in a RWO to run a new 4-1/2" 13CR tubing string which is currently in the well today. The well was fraced in Nov-92 and the subsequent flowback resulted in a final TD of 9,280' md, approximately • Date: November 30, 2007 • . 100' deeper than the initial sand back depth, and exposing all but the bottom 14' of perforations. In Nov-03 while bleeding the OA, the fluid level came to surface. Subsequent monitoring showed OA re-pressurization indicated possibie IA x OA communication. The weli was online at this time. In Jan-04 a TIFL failed and a caliper was run indicating the tubing was in good condition. A plug was set and the GLV's were dummied off (except STA #5) and a LDL was run. A significant leak was found at the bottom of STA #1. In May-04 more GLV work was done resulting in DGLV's set in all stations. An MIT T to 3,000 psi passed. The TTP was pulled, SIBHP's taken, and the well returned to production. In Sep-04 an OA artic pack flush was attempted but the OA broached to the conductor during the second pressure cycle at 2,000 psi. The well was shut-in and the cellar bubbling stopped. A TTP was set and the OA was monitored and over a 17 day period the OAP increased 30 psi. In Nov-04, an MIT IA was attempted but failed at 0.7 gpm. In Jun-05 the MIT-T and CMIT T x IA both passed however in Sep-05 an MIT IA failed and during this test the tubing pressure increased ~ 250 psi and remained after the IA was bled down. In Jan-06 a Sensa Tube LDL was performed and found a leak at the packer. The well has remained shut-in since Sep-04. As of this time, the well is listed as having OA x surface communication, tubing x IA communication, possible IA x OA communication, and a confirmed leak at the packer. Based on historical pumping volumes, the both the IA and tubing are primarily fluid packed with crude. In addition to crude, minor volumes of diesel 50/50 exist in both tubing and inner annulus. The GLM's are dummied off and a PXN is set in the "XN" at 8,428' md. The current fluid levels are at or very near surface in both the IA and tubing. Over the time period from 22-Jun-07 to 26-Nov-07 the tubing pressure has increased from 260 psi to 320 psi. The IA pressure has increased from 100 psi to 210 psi and the OA pressure has remained at zero. The current estimated hydrostatic pressure in both the IA and tubing is estimated to be ~ 3,400 psi. When combined with WHP's, and based on the last SIBHP of 3,184 psi in May-04, the current hydrostatic overbalance is approximately 400 psi. Please note this well has special AOGCC requirements for notification. The AOGCC must be qiven 24 hours notification to witness ANY work prior to the actual performance of anv work in this well. If you have questions or concerns regarding this program, please contact Jennifer Starck at (907) 564-5811 (o), (907) 240-8552 (c) or Kirk Forcade (303) 898-0334 (c) or poug Cismoski at (907) 564-4303 (w), (907) 240-8041 (c), or (907) 345-3662 (h). cc w/a: Well File ~ • JOB OBJECTIVES Secure well due to surface casing leak, possible IA x OA, T x IA communication and confirmed packer leak. The well will be secured with an IBP set in the 7" liner above the perforations with ~ 50' of 20/40 river sand dumped on top. A CMIT T x IA will be attempted and in the event the CMIT T x IA fails, a LLR will be established to determine the forward plan to be covered in a future program. BASIC PROGRAM PHASES ~ Install secondary containment in cellar if not already done • Coil to puli prong and plug • Run in hole and set IBP at ~ 35' above the top perforated interval • Circulate tubing dead and liquid pack IA • Dump ~ 1,150#'s of 20/40 river sand on IBP • Circulate well to inhibited seawater and freeze protect • Once at surface perform CMIT T X IA to 3,000 psi. • If CMIT T x IA fails, determine LLR RISKS AND DISCUSSION • Well control plans and a task hazard assessment should be in place in the event of a well control problem. Review well control basics and ensure sufficient kill fluids are available on location at ail times during this work. In the unlikely event of a well control situation the most probable scenario is that a barrier is lost and the surface casing can't contain reservoir pressure. Review well control plan at each shift change. Rig up equipment so that in the event of a well control situation the following general steps, at a minimum, can be executed: o Pump down the production tubing (with or without coil in the hole), taking returns up the IA until the IA is liquid packed and dead. o Continue pumping down the production tubing (with or without coil in the hole) while taking returns from the OA until the OA is liquid packed and dead, if conditions warrant. • The well has T X IA and has also exhibited intermittent, but not confirmed, IA x OA communication. The OA has broached surface and there is a confirmed packer leak. • Any overpressure or overbalance could ultimately result in significant pressure buildup in the OA. As the well has broached surface casing close monitoring of the conductor, OA and IA is necessary. This program attempts to minimize difference in hydrostatic gradients as much as possible by not loading the tubing with KCL until abso4utely necessary. Avoid bullheading down tubing if possible and keep OA pressure bled off. • Several scenarios were reviewed in the preparation of this work scope. Although S/L could pull the prong and plug and E-line could set the IBP, there is a small risk of the well swapping to gas during the various steps. Coil was chosen for the entire work scope as the well would always be attended, a pump rigged up to the well and fluids always on location. The coil unit offers significant advantages for the monitoring and loading of the well throughout the entire job. The well is a high water cut well ~ 88%; the associated gas rate is ~ 10 MMSCF/D with a total fluid production of ~ 5,000 BFPD. With gas to surface, historic SIWHP has been 2,350 psi. ~ • • Until the IBP has been set, the program was based on trying to leave the well in its current balanced and stable state as well as keeping the hole full. • Once IBP has been set and sand dumped on IBP, a CMIT T X IA will be performed. If this test fails, the leak rate will be determined to develop the forward plan to be executed at a later date. • An OORT (annulus pressurization test) was discussed and it was decided that the most prudent action, given the current stable well conditions, would be to proceed with securing the well and then further investigate this issue at a later date. • The final well balance between IA and tubing is important. With T X IA, and a heavy column in the tubing, the IA may not immediately bleed to zero and may confuse the well status. To mitigate this risk, the tubing hydrostatics should be kept in balance with the IA at the end of the job. • A drift run for the IBP was discussed and determined not to be necessary as coil will have just pulled the TTP and its only 12' to the TT. CAUTION: AOGCC needs to witness ALL work on this well. Give 24 hour notice prior to any well work. PR E-CTU AND RIGUP CONSIDERATIONS 1. Ensure a cellar liner has been installed to adequately contain any fluids which ma come from conductor. 2. Rig up all equipment for coiled tubing work including UR's, tank farm, PIS, IA tie- in, and associated hardline. Rig up separate OA tie-in for contingency bleeding or returns in the event of OA pressurization or flow. (Note OA has arctic pack - excellent plugging agent in small bleed hoses). Rig up so that IA and OA can be bled independently. Maintain sufficient fluids on location for well control contingencies at all times. Have dirty vac truck on location. CO IL~~ "~'~BING SCOPE £° ~ `' 3. MIRU CTU with 1-3/4' service coil. 4. MU BOT MHA with jars, and hydraulic pulling tool to pull prong from PXN plug. PT as per standard procedures, open well and RIH. Take displacement returns as necessary while RIH, maintaining at least initial static SIWHP. NOTE: Check OD of hydraulic pulling tool for centralization, may need a skirt to ensure proper centralization. 5. RIH to ~ 8,350' md and get up/down weights. RIH slowly and latch prong at ~ 8,428' md. 6. Pull prong and POOH. Watch for change in WHP and note any changes. POOH replacing voidage down the backside with 60/40 methanol water maintaining initial SIWHP. Kee hole full. 7. Lay down prong and pulling tool, make up GS, PT and RIH. Get up/down weights form ~ 8,350' md. RIH slowly and pull plug body from 8,428' md. Keep hole full and maintain SIWHP. PUH 30' and fla i e for de th control for IBP settin . 8. POOH re lacin voida e+~10% down the backside with 60/40 methanol water ~ ~ maintainin initial SIWHP. 9. MU BOT MHA with 3-3/8" OD IBP to be set in 7" liner. Pull test connector and pressure test MHA. Pressure test down backside as per BOT procedures. Confirm IBP s ecs and note in WSR. 10. Open well and RIH with IBP, kill well with 1% KCL only if necessary, cap with 60/40 methanol water. 11. RIH with IBP to flag, correct depth for CEL. Slowly RIH to set depth. In the event of a pre-mature tag, PUH 10' and set IBP. The objective is to get the IBP set in the 7" liner with ~50' of sand on top therefore a high tag should not be a problem unless its close to the tubing tail. NOTE: Make the usual corrections to the flag for BHA length changes and difference between tally depth and ELMD. Based on 11/11/92, TT ELMD is 8,431'. Taily depth is 8,440' - See wellbore dia ram. 12. Set IBP above perforations at ~9,100' ELMD (~ 36 feet above top perf - confirm with casing tally/log for collars). Inflate with KCL and set as per BOT procedure with a minimum of 3 hours for temperature stabilization. Set down weight and or/tag to confirm set as per BOT. Pump sufficient KCL ahead of ball to ensure methanol water is clear of IBP and IBP setting area. CAUTION: If tagging, make sure OD of setting tool can not get along side of neck on IBP inadvertently opening equalizing port or get hung up. NOTE: If casing collars crowd setting depth of ~ 9,100', move up hole rather than down for setting depth. This wiil ensure IBP is not set in perfs while avoiding collars as best as possible. 13. Once IBP is set, PUH and re-paint flag if necessary for next run as depth controi for sand dump. As well is chrome, may need to change pipe flagging depth to account for pipe management pipe cutting or make fourth run. Consider getting an IA FL if the IA is suspected of having a large void. NOTE: This fiag is critical to ensure that the IBP is NOT tagged when running back in hole for the sand dump. Tagging the IBP could open the equalizing sleeve or get coil hung up around the fishing neck. 14. Start POOH and pumping down the coil taking returns up the backside to kill the well and remove any gas from the tubing in preparation for the sand dump. Hold back pressure until no more gas is seen at surface and the tubing is liquid packed. Depending on the IA/OA communication, it may be necessary to keep the hydrostatics in balance with the IA by swapping to diesel on the way OOH after all gas is out of the well. Lubricate and bleed IA to liquid pack, if necessary. CAUTION: Once again, monitor IA/OA/Conductor for problems. As long as there is not significant IA to OA communication and no fluid is coming from the conductor the overbalance should be ok. The IA and/or OA may need to be bleed as the well thermals up. Keep the OA pressures bied off if they build during the job. 15. Once at surface, note current OA, IA and tubing pressures. Closely monitor cellar, OA, IA and tubin ressures. ~ ~ 16. MU CTC, no checks , two stin ers, and BDJSN 17. RIH to no closer than 20' above IBP using flag from previous run and BHA length changes. PUH and park coil. Do not tag IBP or get along side of it as the e ualization ort could easil o en u. 18. Once at sand dump depth, perform a circulation test checking for 1:1 returns while lining up to dump sand. The well should be dead and circulate without losses. Maintain minimum WHP in the unlikely event additional gas is present. Monitor the OA and conductor. 19. Line up and dump 50' of 20/40 river sand on top of IBP in a single dump - ensure gel breaker specs are correct for SIBHT and time to get sand to bottom. Pump the following down the coil. a) 5 bbls FW and PT b) 3 bbls of gel ahead c) ~5.2 bbls of 20/40 river sand slurry (1,150#, 7 ppa) d) 3 bbis of gel e) XX bbls of 1% KCL to displace coil NOTE: Pull surface samples of slurry to ensure gel breaks in a timely manner. 20. Once sand is at the nozzle, lay in sand 1:1 while taking returns and staying above the top of the sand. Once all slurry is out of the nozzle continue laying in remaining gel and KCL until coil is cfear. PUH sufficiently above top of gel and sand slurry. Circulate at minimum rate down coil while waiting for sand to fall. Wait at least one hour before first tag. Re-tag sand and make wash down runs as necessar to consolidate sand. 21.Once sand top is consistent, swap well to inhibited KCL while POOH, freeze protect tubing with diesel from 4,800' md. This will provide ~ 250 psi overbalance on sand plug and IBP while maintaining balance with the IA. Make sure IA and tubin are balanced as best as ossible. 22. Once at surface perform a CMIT T x IA to 3,000 psi (~ 3,300 psi dp on IBP). IA may/may not respond but must be liquid packed. Max expected IAP is 2,800 psi. Monitor OA and conductor, if any significant or abrupt increase is seen, shut down immediatefy. 23. NOTE: In the event the CMIT T X IA fails, establish a LLR if possible. 24. Bleed IA and TBG to zero. Monitor for flow. SI well. Bleed OA down to zero and monitor. RDMO. Contact WIE with final status and request follow up fluid levels and monitorin . 25. Ta tree as lon term shut-in with IA and TBG fluid acked. RE: H-03 & H-ll MIT Forms ) ) Subject: RE: H-03 & H-ll MIT Forms From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Wed, 13 Ju12005 17:29:23 -0800 To¡:: James Regg <jim....;regg@admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> Hi Jim, Re: H-11 test pressures DHD bled the tubing pressure of well H-11 to approximately 900 psi following test #2. Finding no fluid returned to surface, it was determined that the tubing was not fluid packed. Little Red Services loaded the tubing with approximately 7 bbl of crude prior to the pre-test tubing pressure reading of test #3. In the process of loading the tubing, tubing pressure increased to 2360 psi. Please call if you have any other questions. Thanks Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Office: 1-907-659-5525 Pager: 1-907-659-5100 #1923 Eg.þ'..~..~.~....:...~~..~..!.~.~..~.þ'P...:...~.S?.!.Ð. ~.. ...., ....,..~....'.'...t,I(!~~ '\ .' ',,'; "U I' " -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Wednesday, July 13, 2005 1:24 PM To: NSU, ADW Well Integrity Engineer Subject: Re: H-03 & H-11 MIT Forms Thanks; according to your data, was the tubing pressure between tests 2 and 3 bled from 3100 psi to 900 psi or 1900 psi? Inspector Lou Grimaldi's test report shows pressure bled from 3100 psi to 1900 psi (attached) . Please clarify. Jim Regg AOGCC SC,ANNED JUL 2 2 2005 NSU, ADW Well Integrity Engineer wrote: Hi Jim, Looking over the MIT records on 06/14/05 for H-11, test 1 & 2 were performed from 7:00 AM to 11:29 AM and tests 3 & 4 were performed from 1:01 PM to 10:35 PM. Because there was a small amount of gas in H-11's tubing, Lou Grimaldi's suggested DHD bleed the gas while the pumping crew went over to perform the MIT on H-03. After H-03 passed the MIT, they went back to H-11 to start the 3rd test. Hopefully this clarifies the discrepancy. Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr ---------------------------------------------------------------------- *From: * James Regg [~?:.~.l...~.~~....t~~~~~.9.g.~?..~.ª~~.~~...:_~_t..~t..~_:..9:..Js...:...~..§.] lof2 7/14/2005 8:11 AM 20f2 7/14/2005 8:11 AM \C(fJ~ ob<6 Thanks, Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Office: 1-907-659-5525 Pager: 1-907-659-5100 #1923 .;:g.~?.~.!..:~:...:..~~.~..~.!..~.~.~~þP'...:...~S?':~ Please call if you have any questions. «MIT PBU H-03 06-14-05.xls» «MIT PBU H-11 06-14-05.xls» Attached, please find the MIT forms for wells H-03 and H-11. Hello Jim and Winton NSU, ADW Well Integrity Engineer wrote: Jim Regg AOGCC The tubing pressure between tests 2 and 3 were bled from 3100 psi to what pressure - 900 psi or 1900 psi? Why the pretest repressurization in tubing pressure from 900 psi or ~900 psi to 2360 psi? re: PBU H-11 MITs ') *Sent:* Monday, June 2~.)2005 3:24 PM *To:* NSU, ADW Well Integrity Engineer *Cc:* Winton G Aubert; Bob Fleckenstein *Subject:* Re: H-03 & H-11 MIT Forms RE: H-03 & H-ll MIT Forms ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Emaíl to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc. FIELD I UNIT I PAD: Prudhoe Bay / PBU / H Pad DATE: 06/14/05 OPERATOR REP: Don Reeves AOGCC REP: Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Well H-11 Type Inj. N TVD 7,947' Tubing 1,200 3,100 2,960 2,890 Interval 0 P.T.D. 1800680 Type test P Test psi 3,000 Casing 465 560 615 640 P/F F Notes: MIT-T for new waiver Outer 10 10 5 5 Pumped 11.5 bbls of crude during test. Well H-11 Type Inj. N TVD 7,947' Tubing 2,985 3,100 3,100 3,100 Interval 0 P.T.D. 1800680 Type test P Test psi 3,000 Casing 720 3,000 2,940 2,915 P/F F Notes: CMIT-TxIA for new waiver Outer 5 5 5 5 Bled tubing :)ressure from 3100 to 900 psi. in 30 mins. All gas, tests inconclusive. Well H-11 Type Inj. N TVD 7,947' Tubing 2,360 2,980 2,870 2,805 Interval 0 P.T.D. 1800680 Type test P Test psi 3,000 Casing 1,325 1,360 1,395 1,380 P/F P Notes: MIT - T for new waiver Loaded tubing with 5.5 bbls of crude. Bled tubing to IA for CMIT-TxIA. Well H-11 Type Inj. N TVD 7,947' Tubing 1,720 2,940 2,940 2,930 Interval 0 P.T.D. 1800680 Type test P T est psi 3,000 Casing 1,720 2,940 2,940 2,920 P/F P Notes: CMIT - TxlA for new waiver Bled IA pressure from 2920 psi to 1520 psi in 15 mins. All liquid. Well H-11 Type Inj. N TVD 7,947' Tubing 2,930 2,705 2,605 2,570 Interval 0 P.T.D. 1800680 Type test P Test psi 3,000 Casing 2,920 1,520 1,590 1,605 P/F P Notes: MIT-T for new waiver Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2005-0614_MIT _PBU _H-11_ 5tests_lg .xls ) ) Is 'Q.ert ¡.{ zò 0 H-11 Combo and diagnostic MIT's 06-14-05 Lou Grimaldi W/L plug set in Tubing Tail. Pump rigged up on tubing. 11.5 bbl's dead crude pumped in tubing. pre initial 15 30 LA. 465 560 615 645 a.A 10 10 5 5 Tub. 1200 3100 2960 2890 :!~.oo ''''0 -"~-' :;:eoo. . ~oc.o . ~ .' . , .' ; '-:. -" ~ .. t~=::=~;J '!lOO~:';-~\ '000 000' o '" ,. ~ ~' .' . . ~ Plug set in nipple in Tubing Tail. Pump rigged up on LA. 5 bbl's dead crude pumped in LA. pre initial 15 30 LA. 720 3000 2940 2915 a.A 5 5 5 5 Tub. 2985 3080 3100 3100 ¡~~::'-. .'y~..<:"'-<"". '".::..., ~~':: .,' ':100 I' '. .. " ., . . ", ,cœ ..;"" " '~",.'." <: L,",:> ,._~ ~", .' ... .. E-,·Aj ~'_.', -0,'" '.NT~. . --.-.- '. ". L, . ·.....:..·...·1··.. ......'.' In lllt! 30 0, ODfS'. ___ JBII.. 7/'4/05 ; ~e e~ The Tubing was bled off at this point for approximately 30 minutes (3100 psi to.:L900 psi) to a bleed ~ 12.. Mielke. trailer with no fluid present in bleed. I advised that the tubing had to be loaded and purged and we (ßp) would retest. I did another MIT on a different well (H-3) and left for Milne point.! was gone for approx.3 hours. When I returned the well seemed purged adequately. We restarted the tests. Tubing/LA. loaded w/ dead crude. Pump on tubing. < 1 bbl pump~d. pre initial 15 30 45 I.A. 1325 1360 1395 1380 1390 a.A 5 5 5 5 5 Tub. 2360 2980 2870 2805 2750 __"" _ .,' _. I, - _ ~-,-~ , ,_.. ."'-1' . '. . ...,.......-... .\-W"y\w... '000 ~ooo zuw ( !GOO ..... 1000 . '00 . , r-I.A·l ==~;. LA. and tubing tied together and equalized. Combo MIT performed. No gas present. 2 bbl pumped. pre initial 15 30 LA. 1720 2940 2940 2920 a.A 5 5 5 5 Tub. 1720 2940 2940 2930 3!100 "CO "00 '000 '000 1=-:-,"1 ·""·,·,·"",·,,:,,,,·,·,';';·'TL.tI '000 TOO .' , ........,.-,.-, ------,.-..-------.- LA. bled to slop tank (all fluid approx 1 bbl or less) five minute readings taken. pre initial 5 10 15 20 25 30 35 40 45 LA. 2920 1520 1550 1570 1590 1600 1605 1605 1610 1610 1610 a.A 5 5 5 5 5 5 5 5 5 5 5 Tub. 2930 2705 2650 2630 2605 2590 2580 2570 2560 2550 2545 --- ----,------ ~ l£¡~L;; . . .,,~~.;~.,,'. .., ..¡'~~,.:'..'..: "~~: ,~ ...:" 1000: "" 'V.",' r"' .'. " 500 :. .. ',_ :. o . ,.. E;;JA -OA '~~,. ·'·'Tub, l__ 25 , STATE OF ALASKA ') ALASI'\. .blL AND GAS CONSERVATION COI\tIIl/~SSION Mechanical Integrity Test ~·.-':T2.,.\I.-.r.·~ .Í;¡ I 3t ù5 Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us - J-' OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I H Pad 06/08/05 Donald Reeves \%1:>/ () ~ Packer Depth Well H-11 Type Inj. N TVD 7,947' P.T.D. 1800680 Type test P Test psi 3,000 Notes: Pre state witnessed MIT-T to 3000 psi Tubing Casing OA Pretest 2,820 200 o Initial 3,000 200 o 15 Min. 30 Min. 2,900 2,850 Interval 220 230 P IF o 0 o P .,/'"' Well H-11 Type Inj. N TVD 7,947' Tubing 2,850 3,000 2,950. 2,925 Interval 0 P.T.D. 1800680 Type test P Test psi 3,000 Casing 2,940 3,000 3,000 3,000 P/F P Notes: Pre state witnessed CMIT-TxIA to 3000 psi OA ° 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: /" SCANNED ·JUN 2 JP 20D5 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2005-0608_CMIT_PBU_H-11.xls ') ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg <í7 ðnû rl ('16(04- P.I. Supervisor ~ II -{ DATE: Wednesday, November 17,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC H-ll PRUDHOE BAY UNIT H-ll \ ~ Ó-"Ot?tÇfj FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \.-f.ß.£- Comm Well Name: PRUDHOE BAY UNIT H-ll Insp Num: mitCS041116195614 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20485-00-00 Permit Number: 180-068-0 Inspector Name: Chuck Scheve Inspection Date: 11/1612004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well H-ll Type Inj. N TVD IA 0 3000 2900 2800 P.T. 1800680 TypeTest SPT Test psi OA 20 20 20 20 Interval OTHER P/F F Tubing 740 780 780 780 Notes: This well has a plug set in the tubing tail and the IA had been loaded with dead crude. The IA was repressured 4 times over a two hour period with a stable leak rate of 100 psi per 15 minutes established. The stable Tubing and OA pressures indicate a leak from the 9 5/8 casing to formation. SCANNED DEC 1 4 2004 Wednesday, November 17,2004 Page I of 1 03/04/04 Scblumbepgep NO. 3123 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Prudhoe Bay Well Job# Log Description C-04A ~~rr: --eye¡~.:). 10649975 RST-SIGMA N-21A'~ tJ - '1 ( r"' - 10703973 LEAK DETECTION LOG D.S. 15- 7 J9 Ó '(",ð.If 10703977 LEAK DETECTION LOG H-11 I~O'~(s'" 10703978 LEAK DETECTION LOG K-317B ~,\ - \ t:::) (¡J 10708049 SBHP SURVEY Color Date Blueline Prints CD 06/26103 1 1 /tJ..L-! "7:;< 02115/04 1 02/23/04 1 02/24/04 1 02/06/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 -""^6l"\~^~ ,- '.. - "'U I . . ., . . ¡ , , .n.:"" ....~ ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECEIVED Date Delivered: .¿}. ú C:':: :,,¡: :Ci!~, :cmr.:~:;;' ) :~r,h!)íage Received:~\\«\ ~ ~~~").,-,....è'\...-1'X>V'--'\ --K~O\\\~ MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner ~'~ ?J:~ ~ ~ Tom Maunder, P. I. Supervisor ~, 1~- c.% \ FROM: Lou G~ldi, SUBJECT: Petroleum Inspe~or DATE: April 22, 2001 SVS Misc. tests BPX H pad Prudhoe Bay Field Sunday, .Ar)HI. 22, 2001: I witnessed the first of the one-month retests of the SVS systems on BPX H pad wells in the GC-2 area of the Prudhoe Bay Field. Merv Liddelow (BP Rep.) performed the SVS tests today. All components functioned properly and held their pressure tests. The new style pilot boxes were installed on most of the wells, which combined with the reliability of the electronic pilots helped to produce these great results. The well houses were all clean with pilot valves in proper position. SUMMARY: I witnessed the SVS test on twenty BPX H pad wells in the Prudhoe Bay Field. 20 wells, 40 components, No failures. Wellhouse Inspections; 33 wellhouses, No problems noted. Attach,men,ts: svs PBU H-pad 4-22-01 LG.XLS NON,-C,ON FI.DENT,IAL, SVS PBU H-pad 4-22-0t LG ( Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Lou Grimaldi Submitted By: Lou G. Date: Field/Unit/Pad: Prudhoe Bay field, H-pad Separator psi: LPS 157 HPS 22-Apr 650 - WellData ~ "? -- ~.Pilo~ --- - SSV SSSV Retest.W~Ty~..e_ - . - 4,2 ~ '~ ,~ ' -~ : ~ ~ ii i 1 i i I I i ~ I i ii Well Permit Separ Set Test Test Test Date oil WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS orCYCLE H-01A 1951100 H-02 1710160 H-04 1710220 H-05 1710240 650 550 550 P P OIL H-06 1770020 157 1251 125 P P OIL H-07A 2001280 H-08 1770230 ~I-ll 1800680 157 125 100 P P H-12 1800670 H-13 1810170 650 550 525 P P OIL H-14A 1980680 H-15 1810610 157 125 125 P P OIL ,,W~ , ~000~0 ~-17A ~971~20 '~S0 ~0 ~10 P P Om H-18 1822100 ~-1~ 1~so~4o ~o ~o ~no P P ' om H-20 1830070 H-21 1860710 650 550 525 P P OIL H-22A 1970480 157 125 125 P P OIL H-23A 1950850 650 550 550 P P OIL ,H-24 1853050 157 125 115 P P OIL iH-25 1852680 650 550 550 P P OIL iH-26 1852770 157 125 95 P P OIL ,H-27 1852360 H-28 1880440 H-29^ 1980380 650 550 530 P P ' OIL H-30 1880350 650 550 525 P P OIL H-31 1940140 H-32 1940250 157 125 100 P P OIL H-33 1940380 650 550 515 P P OIL H-34 1971640 157 125 125 P P oIL H-35 1951490 650 550 515 P P OIL H-36A 2000250 H-37 1971020 157 125 125 P P OIL W~I~'l/16/O! 20 Components: p~_~eqa~u~es: 0 F~~ padO .aO_g_~_~ . I'Permit / ~epar ' Set I L/P Number I Number / PSI PSI I Trip Test Code ( Test / Test / Date I ou, WAG, GINJ, Code ] Code ! Passed] GAS or CYCLE Remarks: Great test, no failures. RJF 1/16/01 Page 2 of 2 SVS PBU H pad 4-22-01 LG A _.,A OIL AND GAS CONSERVATION COMMIS . .q REPORT OF SUNDRY WELL OPERATIONS . 1. Operat,:)ns performed: Operation shutdown . Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other :x _ 5. Type of Well: 6. Datum elevation (DF or KB)' ~_,,,~ KBE= 76.49 A. MSL tc~t~ 2. Name of Operator BP E,~q~loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1873' SNL, 1264' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 1457' SNL, 2005' EWL, SEC. 21, T11N, R13E, UPM At effective depth 1365' SNL, 1891' EWL, SEC. 21, T11N, R13E, UPM At total depth 1337' SNL, 1863' EWL, SEC. 21, T11N, R13E, UPM Development X Exploratory Strat~jraphlc 7. Unit or Property name Serv,:e Prudhoe Bay Unit 8. Well number H-11 (22-21-11-13) PBU 9. Permit number/approval number 80-68 / 10. APl number 50- 029-20485 11. F~eld/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural o- Conductor 110 Surface 2667 Intermediate 8913 Production -- Liner 1482 Perforation depth: measured 9875 feet BKB 9464 feet 9702 feet BKB 9295 feet Size Plugs (measured) Junk (measured) Cemented 20x30 8 c.y. 13 3/8 4092 c. f. 9 5/8 1568 c.f. 7 428 c.f. 9206'-9244', 9254'-9265', 9286'-9304' fill at 9702' MD (03/89) Measured depth True vertical depth BKB 139 139 2696 2696 8942 8563 8391-9873 8045-9462 true vertical subsea 8816'-8910' (three intervals) Tubing (size, grade, and measured depth) 4 1/2' L-80 to 8329' with 4 1/2" tailpipe to 8433' RECEIVED AU G 11 199; Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 8529'; 4 1/2" SSSV at 2OOO~jaSj~a 0il & Gas Cons. C0mrniss~n 13. Stimulation or cement squeeze summary See Attachment ~,nch0rage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or In!action Data Od-Bbl Gas-Mcf Water-Bbl Casing Pressure 5620 9428 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1338 0 259 Service 16. Status of well classification as: Od ~ Gas Suspended 17. I hereby c, emfy that the foreg_mng is true and correct to the best of my knowledge. Signed ~ - O ~ ~ Title Senior Technical Assistant I Form 10-40z~ Rev 06/15/8~ Date SUBMIT IN DU~LIC~ATE 11/15/92 WELL H-11(22-21-11-13) Hydraulic Fracture Treatment A Frac(Ivishak) was performed using the following fluids: FLUIDS PUMPED DOWNHOLE 29 BBLS DIESEL TO SET TREE SAVER 200 BBLS 20# GEL INJECTIVITY TEST DATA FRAC # 1: 20 200 145 125 FRAC: 20 390 122 2.6 30 34 35 36 37 258 145 BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD W/*.*% ESL (GAL) BBLS 20# GEL DATA FRAC FLUSH BBLS DSL TO FREEZE PROTECT WELL & LINES. BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD W/*.*% ESL (GAL) Dirty 1 PPG Dirty Z PPG Dirty 3 PPG Dirty 4 PPG Dirty 5 PPG Dirty 6 PPG Dirty 7 PPG Dirty 8 PPG Dirty 2.0# LINEAR GEL FLUSH Oh 5/3/93 RECEIVED AU 6 1 1 199;~ Alaska Oil & Gas Cons. 6or~missiov Anchorage A OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1873'SNL, 1264' WEL, SEC. 21, T11N, R13N, UPM At top of productive interval 1457' SNL, 2005' EWL, SEC. 21, T11N, R13E, UPM At effective depth 1365'SNL, 1891'EWL, SEC. 21, T11n, R13E, UPM At total depth 1337' SNL, 1863' EWL, SEC. 21, T11N, R13E, UPM 5. Type of Well: Development Exploratory S~'aagraphlc Sennce 6. Datum elevation (DF or KB) KBE = 76.49 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-11 (22-21-11-13) PBU 9. Permit number/approval number 80-68/Conservation Order 258 10. APl number 50- 029-20485 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9875 feet BKB 9464 feet 9702 feet BKB 9295 feet Plugs (measured) Junk (measured) fill at 9702' MD (04/90) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length true vertical Tubing (size, grade, and measured depth) Size Cemented [ 4 1/2" tubing 12.6tl FOX 13CR/at 8440'. Measured depth True vertical depth REEEIVED DEC 1 5 1992 Alaska O/J & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 9 5/8" TIW HBBP Perm. Packer at 8285'; 4 1/2" Otis HXO SVLN ~$~...9CR at 1967,. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re.oresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~"'")/~'/.~---~ Title Drilling Engineer Supervisor Form 10-404 Rev 06/15/~8 /~../"/~/?'~ Date SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS~ PAGE: 1 WELL: H-ii BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/02/92 03:00 SPUD: RELEASE: 11/07/92 12:30 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 11/02/92 (1) TD: 9873 PB: 9830 PULL BPV MW: 0.0 MOVE RIG & CAMP TO H-ii, SPOT TANKS, TAKE ON SEAWATER, R/U ON TREE TO DISPLACE WELL, PULL BPV 11/03/92 (2) TD: 9873 PB: 9830 11/04/92 (3) TD: 9873 PB: 9830 11/05/92 (4) TD: 9873 PB: 9830 11/06/92 (5) TD: 9873 PB: 9830 11/07/92 (6) TD: 9873 PB: 9830 POH L/D 4-1/2" COMP. STRING MW: 0.0 TAKE ON SEAWATER, CIRC WELL UNTIL CLEAN, N/D TREE & ADAPTOR FLG, CK TIE DOWN BOLTS, NU BOPE & TEST, BACK OUT LOCK DOWN SCREWS, PULLED TO 200K, PULLED HGR TO FLOOR, CIRC TBG STRING, SOME GAS IN RTNS, L/D TBG HGR, L/D TBG, R/D OTIS, POH L/D TBG RIH W/BHA #2 MW: 0.0 L/D 4-1/2" TBG, TBG BADLY CORRODED ON PIN & BOX ENDS, CLEAR FLOOR, INSTALL WEAR BUSHING, M/U BHA #1, P/U DP, TG SLICK STICK @ 8302', POH W/FISH, RECOVER SLICK STICK, L/D OVERSHOT, M/U & RIH W/BHA #2 RIH W/BHA #3 MW: 0.0 MILL ON 9-5/8" SAB PKR @ 8329', 1ST 2' MILLED IN 3 HRS, PKR STARTED SPINNING, DRY DRILLED, TOOK 8 HRS TO MILL FINAL 6', PKR DROPPED, PUSHED TO LINER TOP @ 8380', CBU, CIRC OUT GAS, POH W/FISH, LOST 30BBLS ON TRIP OUT, L/D PKR, TAILPIPE ASSEMB & FISHING TOOLS, CHG OUT MIDDLE RAMS TO 3-1/2"X6" VARIABLES, TEST RAMS TO 5000 PSI, SLIP & CUT 57' DRLG LINE, M/U JET BASKET & 9-5/8" SCRAPER POH-L/D DRILLPIPE MW: 0.0 RIH TO 9150' W/JET BSKT & CSG SCRAPER, PU KELLY, TAG SAND @ 9190', PU 30' & CBU, DROP REVS BALL, WASH DOWN THRU SAND FILL & WORK JET BSKT, POH, L/D JARS,SCRAPER & JET BSKT, MU 7" RETREIVABLE TEST PKR, & RIH TO 8428' SET PKR & TEST LINER LAP & 9-5/8" CSG TO 3500 PSI FOR ~0 MINS, GOOD TEST, RELEASE PKR, PULL BACK TO ABOVE LINER TOP, REV CIRC WELL TO CLEAN SEAWATER, POH LAYING DOWN DP RE-ARRANGE BOPE. MW: 8.5 Seawater L/D DP. RIH W/ 4-1/2" 13 CR TBG W/ 9-5/8 .... HBBP" PKR. P/U TBG HGR, CNTRL LINES. TEST SAME. LAND TBG. SET PKR W/ 3500 PSI. TEST TBG, ANNULUS. N/D BOPE. R£ EIVED Anchorage WELL : H-II OPERATION: RIG : DOYON 16 PAGE: 2 11/08/92 (7) TD: 9873 PB: 9830 RIG RELEASED. MW: 8.5 Seawater N/U TREE. TEST TREE. SHEAR RP VALVE. F/P W/ 12 BBLS DIESEL. SET BPV. SECURE WELL. SIGNATURE: (drilling superintendent) DATE: RECEIVED DEC 1 § 1992 Alaska 011 & Gas Cons. Commissio,' Anchorage BP EXPLORATION BP Exploration (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RECEIVED DATE: 11/20/92 T# 84091 PBU/BP CASED HOLE LOGS En'closed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ;,-27 -,o .CNL #1 H-11 ~"-~CCL 11/11/92 #1 M-10~;- Z~ PRODUCTION LOG 11/13/92 #1- M-24~_~ PRODUCTION LOG 11/13/92 #1 P-03 $~,I~ PRODUCTION LOG 11/14/92 9800.00-10679.00 ATLAS 5 " 8950.00- 9713.00 ATLAS 5 " 8200.00- 9186.00 ATLAS 5 " 9150.00- 9666.00 ATLAS 5 " 9050.00- 9380.00 ATLAS 5 " 10150.00-10520.00 ATLAS 5 " Information Control Well Records MEMORANDUM ALASKA STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh A Griffin Commissioner date: file: November 12, 1992 JER11021 .DOC thru: Blair E Wondzell ~,/~.~ Sr Petr Engineer from: ~rBt Herring Petr Inspector subject: B.O.P. Test Doyon 16 PBU Well H-11 Prudhoe Bay Field Monday, November 2, 1993: I witnessed a B.O.P. Test on Doyon 16 which was relocated from ARCO Prudhoe D.S. 12 to B.P. Prudhoe H-Pad. Doyon 16 is to workover well H-11 by replacing split tubing. The B.O.P. Test had several problems. Tool pusher, Jim Willingham, had difficulty with the tooling conversion between D.S. 12 and H-Pad. Delays were encountered because of mixed variables. The test began at 1:30 P.M. leaks were discovered on the mud choke manifold and on the B O.P. stack. Leaks occurred at the flanges and were stopped by tightening the stud bolts. Leaks probably were due to the rig move. The problem was repaired on the accumulator pump. The variable pipe ram did not hold and was replaced with a 4 1/2" ram. Due to tubing being in the hole, a test plug could not be inserted. Also due to spacing limitation, the rams could not be changed out until the tubing was pulled. In summary, the rig was clean and in good condition. I received quality help from company consultant, Everett Potter. The test was completed in six hours. The three failures were repaired and retested during the six hour test. Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg , Operator _~ ~, Well H --II Wkvr ~ DATE /! - 7~- . . TEST.' Initial / Weekly Other Rep.,, ~J~m~ po'r-'T-~ ~ Rig phone # Permit # 50-aZ~- 20~$~Location: Sec Z~ T il R Drlg contrctr D~//~)~I~i ~ ~$' csg set ~ ~)~' ,~ft Location (general) Housekeeping (general) Rsrve pit i ACCUMULATOR SYSTEM: Well sign ~ Full charge pressure 3~)0~ Rig NP Press after closure 1~)0 Pump incr clos press 200 ps~g psig psig sec -MUD SYSTEMS: Visual Trip tank ~/' J Pit gauge / J Flow monitor U/ J Gas detectors / J BOPS,, STACK :~ Annul ar preventer Pipe rams Blind rams Choke line valves / Test Pressure Full charge press attained ~- min ~'-~- sec . '° , ~l~l psig. ~~ Controls: Master. ~ Remote ~ ~ Blind s.itch cover ~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly bi( Test pressure Lower Kelly Ball type Inside BOP Choke manifold Number valves HCR valve Number flanges ~-~0 Kill line valves Check valve ~F~ ./~~ OK Adjustable chokes ~J/J~ Hydraulically operated choke j TEST RESULTS: Failures ~,~ Test time ~ ~' ~) hrs --~/'~ ~ // ~0/~./1~..l~%r''''~%J Repair or replacement of failed equipment to be made within (~ days. Notify,~l~J~g_~J~-- '-'- - I nspector~ and follow with written/FAXed [27~-7542] verification to Commission off~ ce. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/92) STATE WITNESS REQUIRED? yes ~ no 24-HR NOTICyGIVEN? yes__%__ no Waived by: Witnessed by: ~ AOGCC phone~79-143(~ - FAX 276-754¢ BP EXPLORATION BP Exploration (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/12/91 T# 82998 BP CASED HOLE FINALS Enclosed is your copy of the materials listed questions/ please contact BP Well Records at H-11~ PRODUCTION LOG 11/01/91 #1 below. If you have any (907) 564-4004. 9050.00- 9697.00 SCH Information Control Well Records Adrian J. Martin RECEIV[D I~IOV 1 9 I991 Alaska Oil & Gas Oons. Commission Anchorage BP EXPLORATION BP Exl31ora~on (Alaska) Inc 900 East Benson Boulevar(~ PO Box 196612 Anchorage, Alasl<a 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:06-01/90 T#:81197 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below, If you have any questions, please contact BP Well Records at (907) 564-4445. a-2 PERF 05/13/90 #1 11100-11250 HLS 5" a-11~ PERF 04/20/90 #1 9150-10025 HLS 5" H-11 PERF 04/19/90 #1 9000-9350 HLS 5" M-21 PERF 04/18/90 #1 9900-10240 HLS 5" W-ll PERF 05/09190 #1 13114-13522 HLS 5" W-32 PERF 05/11/90 #1 9208-10020 HLS 5" Distribution: ARCO ~ c v.o. V EXXON GEOSOIENCES MOBIL J U ~~ PHILLIPS Naska 011 & Gas Cons. commissio[t ~~vO!R~E OF ~,~~ ~chomge ARCHIVES STATE OF ALASKA REPORT OF SUNDRY WELL OPERATIONS Stimulate Plugging Alter casing .... Repair well 5. Type of Well: Development ~ Exploratory Stral~graphic Service Plugs (measured) Perforate X Other 8. Datum elevation (DF or KB) KBE = 76.4g..AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-11 (22-21-11-13) PSU 9. Permit number/approval number 80-68 / 90-229 ,i 10. APl number 50- 029-20485 ,i 11. Field/Pool Prudhoe Oil Pool 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1873' SNL, 1264' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 1457' SNL, 2005' EWL, SEC. 21, T11N, R13E, UPM At effective depth 1365' SNL, 1891' EWL, SEC. 21, T11N, R13E, UPM At total depth 1337'SNL, 1863' EWL, SEC. 21, T11N, R13E, UPM 12. Present well condition summary Total depth: measured 9875feet true vertical BKB 9464feet Junk (measured) fill at 9702' MD (04/90) Effective depth: measured 9702feet true vertical BKB 9295feet Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 x 30 8 c.y. 139 Surface 2667 13 3/8 4092 c.f. 2696 Intermediate 8913 9 5/8 1568 c.f. 8942 Production -- Liner 1482 7 428 c.f. 8391-9873 Perforation depth: measured 9136'-9146', 9156'-9192', 9206'-9244', 9254'-9265', 9286'-9304' true vertical subsea 8672'-8833' (five intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8329' with 4 1/2" tailpipe to 8433' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. True vertical depth BKB 139 2696 8563 8045-9462 Intervals treated (measured) Treatment description including volumes used and final pressure ~e.oresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 480 296 798 1990 204 Service 221 Subsequent to operation 2830 4229 1048 2010 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas .. Suspended . 17. I hereby c.~rtify that the f~rego~g is true and correct to the best of my knowledge. _Signed.Z,/~' '~' ~/~_.,). ~7'"~~ Title Supervisor Gravity/Drainage Form 10-404 Rev 06/15/88 ~ Date .~-~-~?~ SUBMIT IN DUPLICATE WELL H-Il (22-21-11-13~ PBU ADD'L. PERFORATION OPERATIONS The following additional intervals was perforated April 19, 1990, using Halliburton 3 3/8" carrier guns at 6 spf: 9136' - 9146' MD BKB 9156' - 9192' MD BKB All depths are referenced to BHCS, 9/14/80. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations, then tested. jam 5/24/90 BP EXPLORATION BP Exploration (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Aoril 11, 1990 Alaska Oil & Gas Conservation Commi, sion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well H-ii (22-21-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform remedial/capacity sustairment work on the well. ~Tru;~ R. B. Frazier Supervisor Gravity Drainage RBF: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File RECEIVED APR 1219?'l OiJ & Bas Cons, Commissiop ~' gnchorag~ ' /' STATE OF ALASKA .~. [ ~oKA OIL AND GAS CONSERVATION COMI~,.'i,'~,,..)N APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon Suspend Operation Shut~k~vn Re-enter euspended well Alter caling Repair well Plugging Time exten~ion Stimulate Change aplXoved program Pull tubing Varlan~ Perforate X OIh~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Dev~opmont X KBE - 76.49 AMSL feet Explora~/ 3. Address SlzatlgraphiG 7. Unit or Property name P. O. Box 196612, Anc~e, Alaska 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1873'$NL, 1264' WEL, $EC. 21, T11N, R13E, UPM H-11 (22.21-11-13) PBU At top of productive interval 9. Permit number 145'7' $N/., 2005' EWL, SEC,. 21, T1 IN, R13E, UPM 80-68 At effective depth 10. APl number 136~' $NL, 1891' EWL, SEC. 21, T11N, R13E, UPM 50- 029-2048~ At total depth 11. Field/Pool 1337' SNL, 1863' EWL, SEC,. 21, T11N, R13E, UPM Prudhoe Oil Pool 12. Present well condition summary Total depth: measured 9875 feet Plugs (measured) true vertical BKB 9464 feet Effective depth: measured 9702 feet true vertical BKB 9295 feet Junk (measured) fill at 9702' MD (03/89) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 x 30 8 c.y. 139 139 Surface 2667 13 3/8 4092 c.f. 2696 2696 Intermediate 8913 9 5/8 1568 c.f. 8942 8563 Production -- Liner 1482 7 428 c.f. 8391-9873 8045.9462 Perforation depth: measured 9206'.9244; 9254'-9265', 9286'.9304' true vertical subsea 8816'8910' (three intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8329' with 4 1/2" tailpipe to 8433' RECEIVE ' A, PR 1 ~k~ .0]]' & Gas Cons. C0mmissi01~ Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 8329'; 4 1/2" SSSV at 2000' ~ ! ~llc['iora~ 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation Apr//1990 16. If proposal was verbally approved Oil X Gas Name of apj~'~3ver ,., Date approved Service 17. I hereby~~r,, t7 th~oi~is true a,nd correct to the bast of my knowledge. Sit]lned /~. /~ TitleSu,~,rvisorGrav~/Draina~]e Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance . Mechanical Integrity Test Subsequent form required 10-' ~.~ ~ 15. Status of well classification as: Suspended~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LUhiqiE C. ,., ....... IApproval No. ~',,9 ..- ,,.7' ,,~. ~ ~pproved CoPY ~ ReturneCl SUBMIT IN TRIPLICATE AL WELL I-I.1! (22.21-11.13~ Pl~lJ ADD'L. PERFORATION PROPOSAL We propose to perforate the following additional intervals during April 1990: 9136' - 9146' MD BKB 9156' - 9192' MD BKB All depths are referenced to BHCS, 9/14/80. A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jam 4/10/90 'APR ',.~,~,a.OiJ & 8as Cons, Commission, ~, ~nchorag~ BOWEN PACKOFF FLOW TUBES & PACKOFF ]~-' HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE FLOWLINE VALVE GREASE LI N,..,~ ~, ~nchora~ GREASE / MANIFOLD GREASE PUMP RISER ..-GREASE RESERVOIR BOP BP EXPLORATION BP Exploratton (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO ARCO EXXON PHILLIPS STATE OF ALASKA Date: 04/10/89 Tg: 79943 SYSTEM Tape & Transmittal Only ARCHIVES BP MAGNETIC LIS TAPE & LISTING The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: B-11 Z-01 CH/CNL-D 4 Pass 03/29/89 91 8900-9699 TP9 06419 Sch973252 1600bpi API950-029-20485 CH/CNL-D 4 Pass 2.5" 03/31/89 91 10089.5-10802 TP9 06420 Sch973259 1600bpi API950-029-21830 ARCHIVES ONLY: H-11 CH/CNL field tape 03/29/89 1600bpi API950-029-20485 Z-01 CH/CNL field tape 03/31/89 1600bpi API950-029-21830 91 91 TP9 06421 TP9 06422 Sch973252 Sch973259 Received: Date: Informatio ntrol Well Records LR2-1 J. Dietz/S. McCurry ,! BP EXPLORATION HOUSTON ARCO BP ~l~lorat,on (Alaska) Inc.. 900 ~ Benson Boulevard PO. Box 19~12 Anchorage. Alaska 99519-6612 (907) 561-5111 CEE~ON TO.- EXXON TEXAuO MOBIL PHILLIPS Da*e: 04-06-89 T~: 79929 STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES BP CASED HOLE FINAL LOGS The following ma?eriai Is being submlt'l'ed herewith. Please acknowledge receipt by signing a copy of this let'l'er and returning It to this office: A-13 B-05 D-25 H-11 J-19 J -23 PROD-F 03-29-89 #1 9200-9558 Sch 5" PROD-F 03-30-89 #1 11500-11850 Sch 5" CNL-GR 03-28-89 #1 9900-1~862 Sch 5" CNL-GR 03-29-89 #1 8900-9699 Sch 5" PITS 03-28-89 #1 9800-10230 Sch 5" CNL 03-30-89 #1 8950-9842 Sch · 5" Received Date APR 1 o Alaska Oil & Gas Can=. Commission Anchorage , Shirley R. McCurry INFORMATION CONTROL Well Records LR2-1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage Alaska 99519-6612 (907) 561-5111 TO HOUSTON ARCO CHEVRON EXXON TEXACO MOBLE PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHVIES Date:03/14/89 T#: 79885 BP CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: E-21 Perf-R 03/06/89 #l 10400-10595 Sch ,5" H-04 Prod 03/04/89 #l 11300-11838 Sch 5" H-11 Prod 03/03/89 ~ #1 9100-9695 Sch 5" J-08 Prod 03/06/89 #l 11940-12410 Sch 5" Z-25 Perf-R 03/03/89 #1 11478-11700 Sch 5" X-19 Pord 03/05/89 #l 9600-9963 Sch 5" Z-25 CET 03/02/89 #1 10735-11748 Sch 5" Z-25 CBT 03/02/89 #l 10735-11727 Sch 5" Received: Date: Information Control Well RecordsLr2-1 ~J. Dietz/S. McCurry SOhiO ALASKA PETROLEUM COMPANY - March 17, 1986 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE {907) 561-5111 P O BOX 6612 ANCHORAGE, ALASKA 99502-O612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well H-ii (22-21-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB: JAM ~ s~pA. Bragg u U ervisor Production Operations Enclosures (2) cc: Drilling Well File (MB12-1) Well Records (LR2-1) H-11 Well File (r STATE Of ALASKA (' ~ ALASKAtUIL. AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Perm,t No STANDARD ALASKA PRODUCTION COMPANY 80-68 3 Address 8. APl Number P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50-029-20485 4. Location of Well At surface: 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5 Elevatlonlnfeet(indlcateKB, DF, etc.) KBE = 76.49' AMSL 6. Lease Designation and Serial No. ADL 28284 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number H-11 (22-21-11-13) 11FieldandPool Prudhoe Bay Prudhoe Oil Pool PBU 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit ~n Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [-I Stimulate [] Abandon [] Stimulation J~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pull,ng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operat,ons (Clearly state all pertinent details and g~ve pertinent dates, includ~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170). A combination 44 bbl. EDTA/59 bbl. scale inhibitor matrix squeeze with a 300 bbl. sea- water overflush was performed on the following perforated intervals via coiled tubing on March 12, 1986. 9206' - 9244' BKB 9254' - 9265' BKB 9286' - 9304' BKB The well was shut in 24 hours after the treatment. The SSSV was removed prior to the stimulation and reset after the job at 2000'. RECEIVED 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge. .. The sp~/~elow for Comm,ssion use ('/(~. A. Bragg Condl ~nnn~ of Approval, if any Date By Order of Approved by COMMISSIONER the Commission Form 10-403 Date - ~ Submit "Intentions" in Tr~phcate Rev 7-1-80 and "Subsequent Reports" ,n Dupl,cate SOHIO ALASKA PETROLEUM COMPANY February 21, 1986 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P O BOX 6612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well H-Ii (22-21-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM ~ ~;aorggProduction Operations Enclosures (3) cc: Drilling Well Files (MB12-1) Well Records (LR2-1) H-11 Well File ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL:I~] OTHER Fl 2 Name of Operator 7 Perm,t No SOHIO ALASKA PETROLEUM COMPANY 80-68 3 Address P, 0. BOX 196612, Anchorage, Alaska 4 Locat,on of Well At surface: 99519-6612 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5 Elevat,on ,n feet (,nd,cate KB, DF, etc ) KBE = 76.49' AMSL Lease Des,gnat,on and SerIal No ADL 28284 12 8 APl Number 50-029-20485 9 Un,t or Lease Name Prudhoe Bay Unit 10 Well Number H-11 (22-21-11-13) PBU 11 F,eld and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Ind,cate Nature of NotIce, Report, or Other Data NOTICE OF INTENTION'TO: SUBSEQUENT REPORT OF: (Submit ,n Tr,phcate) (Submit ,n Dupl,cate) Perforate [] Alter Casing r-] Perforat,ons [] Alter,ng Cas,ng St,mulate J~ Abandon []] Stlmulat,on [] Abandonment Repa,r Well [] Change Plans [-J Repa,rs Made [] Other Pull Tub,ng [] Other [] Pulhng Tub,ng [] (Note Report muir,pie completions on Form 10-407 w,th a subm,tted Form 10-407 for each complet,on ) 13 Descr,be Proposed or Completed Operat,ons (Clearly state all pert,nent deta,ls and g,ve pert,nent dates, mctudmg est,mated date of start,ng any proposed work, for Abandonment see 20 AAC 25 105-170) A combination 2000 gal. EDTA/50 bbl. scale inhibitor matrix squeeze with a 300-bbl. seawater overflush is proposed for the following perforated intervals via coiled tubing. 9206' - 9244' BKB 9254' - 9265' BKB 9286' - 9304' BKB The well will be shut in 24 hours after the treatment. The SSSV will be removed prior to the stimulation and reset after the job at 2000'. This work is scheduled to commence in February/March, 1986. 14 I hereby cert,fy that the forego,rig ,s true and correct to the best of my knowledge C°nd,t,o~/s of Approval, ,f any J. A. Bragg Title Supvr. Production Operations Date Approved by l! LONItI£ G. $1111lll - COMMISSIONER 8¥ Order of the Corem,ss,on Date .............. j Form 10-403 Rev 7-1-80 Subm,t "lntent,ons'° ,n Tr~phcate and "SubseQuent Reports" ,n IDuphcate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 31 11 'C" STREET ANCHORAGE. ALASKA TELEPHONE {907) 265-0000 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99 502 TO SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only). Date: 8/8/83 CC#: 74627 REFERENCE //TeH. IO CASED HOLE= FINAL LOGS followmgmatenal~sbe,ng subm~ttedherew~th Please acknowledgerece,pt bys,gmnga copy of th~s letter and return,ng ~t to th~s off~ce - SFO/UNIT/STATE: ~, E-18 ,,E-! 9 7B-22 ,-M-2 ~-X-4 /X-13 Jrt-11 ,,X-14 ,-A-23 ~,~X-18 ,,R-6 CNL 6/14/83 Vi 10250-11184 Sch 5" DDNLL/GR 3/20/83 #1 10850-11730 Dres 5" Spinner 7/17/83 #2 10800-11100 Otis 5" Temp. 7/20/83 #1 10000-10350 Otis 5" Temp. Diff. 7/22/83 #1 9500-10050 Otis 5" Temp. Diff. 7/24/83 Vi 10000-10480 Otis 5" C/O 4/1/83 Vi 9130-9600 Dres 5" CEL 5/24/83 Vl 11000-11205 Sch 5" PFC/GR 3/23/83 #- Dres 5" PFC/GR 4/7/83 #- Dres 5" C.A.T. Log 4/9/83 #1 100-9209 Dres 5" (4/82) RECEIVED DA I'E I 9 Victoria Aldridge Development Geology Well Records TP1-5 SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON _m .{q 1 1 (' STREE1 ANCHOHAGE, ALASKA TELEPHONE (907) 265 0000 MAIL POUCH 6 612 ANCHORAGE. ALASKA 99502 GETTY TO SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only') ,, CENTRAL FILES (CC#' s-Transmittal Only) Date: 5/17/83 CC#: 74452 REFERENCE ~IO CASE_____~D HO_.__LE FINAL LOGS - /The following matenal is being submitted herewith Please acknowledge recetpt by slgmng a copy of th~s letter and returning ~t to th~s ofhce:- SFL/UNIT/STATE: G-7 TDT-M 3/13/83 #2 10350-11357 Sch 5" R-20 TDT-M 3/4/83 #1 11200-12096 Sch 5" E-13 Spinner 4/8/83 #2 10900-11300 Otis 5" X-18 Spinner 4/26/83 #1 10630-11115 Otis 5" B-1 Fluid ID 4/21/83 #1 9550-9850 Otis 5" R-18 Temperature 4/30/83 #4 9800-10400 Camco 5" A-22 Completion 3/14/83 #1 10680-12235 Sch 5" C-2 E?L 4/14/83 #1 9800-10110 Sch 5" 'F~l GST 3/7/83 #2 9142-9566 Sch 5" (4/82) DATE ~/~ ~'/~' ~x~.. ~.~__~ Victoria Aldridge ~ ] ~ ~.~ Development Geology ~9 Well Records TP1-5 Ansho~a~e SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON GETTY TO SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS < BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmittal OnlM) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 1907) 265-0000 MAIL POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 1/24/83 Trans.#: 3059 CC#: 56059 REFERENCE O CASED HOLE FINAL LOG. S Ilowmg material ~s being submitted herew,th Please acknowledge receipt by signing a f this letter and returning it to th~s office - H-Il H-ii H-ii H-ii H-Ii GST Activation 11/24/82 #1 8900-9700 Sch 5" GST Inelastic 11/24/82 #1 8900-9700 Sch 5" GST Capture 11/24/82 #1 8900-9700 Sch 5" TDT-M 11/22/82 #1 8900-9801 Sch 5" EPL-Gradio Log 11/22/82 #1 8900-9800 Sch 5" (4/82) RECFIVED DAlE -"~'"~~"~ Victoria Aldridge JAN2 7 198~evelopment Geology ~9 Well Records TP1-5 Alas~ Oil & Gas Cons. Commissio~ Anchorage SOHIO ALASt,,, PET~OLEUr,,,1 COMPANY SFO ARCO EXXON lO PHI LLIPS .- "STATE OF CENTRAL FILES(CC#'s-Transmittal Only AI,:'CHO[IAG[. ALASKA I[LEPHONE (907) 265-0000 MAIL' POUCH 6.612 ANCHORAGE. ALASKA 99502 Date:_, 1-1 9.-83 Trans.~: 3012 CC~: 56012 REFERENCE: ~place-* ~nt tape) OHIO MAGNETIC LIS TAPES & LISTINGS ~ ~he following material is being submitted herewith. Please acknowledge receipt by signing a ~ copy of this letter and returning ~t to th~s ofhce:-- Tape Pos. S-14~-0~ DIL/BHC/FDC/CNL/GR 10/19/82 #1&2 65641 -~2149 A-28/OH DIL/BHC/FDC/CNL 10/20/82 #1 66022 02150 C-26' OH DIL/BHC/FDC/CNL/GR 11-1-82 #1 66033 02148 D-21~' OH DIL/BHC/FDC/CNL/GR 11-1-82 #1 66032 02143 A-4 -- CH CNL 11/22/82 #3 66105 02146 H-17/OH DIL/BHC/LDT/CNL/GR 12/18/82 #1 66223 02145 A-25 OH DIL/BHC/FDC/CNL. 8/18/82 #1 65546 02144 D-12 CH CNL 11/28/82 #1 66167 02143 A-29 OH DIL/BHC/FDC/CNL/GR 11/22/82 #1&2 66162 02142 D-4 CH CNL 11/28/82 #9 66166 02141 0-7 CH CNL 11/14/82 #1 66124 02140 A-27 OH DIL/BHC/FDC/CNL 9-26-82 #1&2 65662 02139 B-7 CH CNL 11/20/82 #3 66132 02138 C-8 CH CNL 11/21/82 #4 66131 02137 S-13 OH DIL/BHC 10/7/82 #2 65222 02136 B-24 CH CNL 10/9/82 #1 65723 02135 R-9 CH TDT 12/6/82 #1 66152 01234 E-2 CH CNL 11/16/82 #11 66074 02133 S-6 OH. DIL/BHC/FDN 11/28/82 ~2 66164 02132 H-ii CH TDT - 11/22/82 #1 66172 02131 J-11 CH CNL 11/29/82 #1 66170 02130 B-8 CH CNL 11/23/82 #7 66111 02129 ',/82) *SFO & EXXON: An Asterisk:(*) next received the Tape(s) and Listing(s) Please confirm this. RECEIVED _---- DAVE ....... · to a listing above means you should have directly from the respective service ~~//// ~ '7~/~"' ~'~'Develo ment Geology Alas~ 0il & Gas Cons. Comm~sio. ~chorage company. S0H I 0 C0?IF I DEII [IAL SOHIO ALASKA PETROLEUM COMPANY ARCO Cl,t~ roQ Getty TO SFO/UNIT/STATE ~,og,! _ (-Marathon) 3111 ' C" S][~[E1 Ar,IcHoIqAGE. ALASKA ]'£tEPItOt.'E 1907) 265-0000 MAll POUCI4 fi 612 ANCt4ORAGE. ALASKA 99.5,02 Date: 8/21/81 C ~ 1000 F REFERENCE SOHIO FINAL DATA CAsed hole final data follow~ng mate.al is being submitted herewith. Please acknowledge recmpt by s~gning a copy of this letter and relurn,ng ~t to this office:-- B-14 D-3 ~- F-2 J-13~ TDT-M (Sch) 7/30/81 #1 Spinner (Camco) 7/7/81 t/-- TDT-M (Sch) 8/1/81 #1 TDT-M (Sch) 7/21/81 #4 TDT-M (Sch) 7/30/81 #1 EPL (Sch) 8/3/81 #2 (Sch) 7/2]/81 #1 (Sch) 7/19/81 #1 Kuparuk St.)TDT~M 22-11-12 o/) EPL 5w! 5~ 5~ 5'~ 5'~ 5~ 5~ 5~ ,' logy {ecords SOH I O CONF I DEI1T I AL SOHIO ALASKA PETROLEUM COMPANY ARCO TO SFO/UNIT/STATE: Mo~d ii (-Marathon) P~lhl~ ......... - BPAE ..... - · 31 11 ' C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265 0000 MAIL. POUCH 6 612 ANCHORAGE, ALASKA 99502 Date: 8/21/81 # 1000 E REFERENCE ~h~~efolOHIO FINAL DATA CASED HOLE FINAL DATA ~/~he followi.g mate.al ~s bern§ submitted herewith. Please ack.owled§e receipt by si§nm§ a copy of th~s letter and returning it to this office:-- A-8" B_6w// B-8'~ B-8 D-3 j D-12j D-13 D-15 [~ F-4 J F-10~ F-ii F-13~ H-Ii -21/ X-llV CNL (Sch) 6/25/81 #4 5" TDT-M (Sch) 7/2/81 #2 5" TDT-M (Sch) 7/22/81 #2 5" TDT-M (Sch) 7/28/81 #1 5" CNL (Sch) 5/29/81 #1 5" DDNLL (Dres) 5/25/81 #1 5" DDNLL (Dres) 6/13/81 #1 5" DDNLL (Dres) 7/12/81 #1 5" DDNLL (Dres) 7/27/81 #1 5" CNL (Sch) 6/27/81 #2 5" CNL (replaces final log (Sch) 5/21/81(correct date) #7 5" incorrectly dated 5/2/81) DDNLL (Dres) 6/24/81 #1 5" DDNLL (Dres) 6/23/81 #1 5" DDNLL (Dres) 6/25/81 #1 5" DDNLL (Dres) 7/13/81 #1 5" TDT-M (Sch) 6/29/81 #2 5" DDNLL (Dres) 5/8/81 #1 5" DDNLL (Dres) 7/15/81 #1 5" RECE. DATE ,,_.,~,,'!c~ f)~l 8. (;:~ O,,ms Ar, d~oragc ' ©pment Geology Records SOHIO CONFIDENT!AL SOHIO ALASKA PETROLEUM COMPANY TO. SFO/UNIT/STATE: 3111 "C" STREEI' ANCHORAGE, ALASKA · TELEPHONE {907! 265-0000 MAIL' POUCH 6-612 ANCHORAGE, ALASKA 99502 M~ ..... -- Date: 7/31/81 # 969 i, REFERENCE. /~OHIO FINAL DATA //,/The following material is being' ~ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: ,.(-Marathon) SOHIO PRESSURE SURVEY DATA B-4 BottomHole Pressure Data Form & Survey ~1~-II,,~ " " " ,, ,, ,, (Go) .5/15/81 (Camco) 6/29/81 (08) 7/20/81 RECEIVED Alaska 0il & Gas Cons, Conlmission DATE Anchora~ ~ Carol Krieter Development Geology Well Records Logs l~dc×ed B-5 B-10 B-13 C-il F-4 F-ii Q-2 Q-5 SOH I 0 CONF I DENT I AL SOHIO ALASKA PETROLEUM COMPANY · ARCO 31 1 1 "C°' STREET ANCHORAGE, ALASKA TELEPHONE (907) 265 0OO0 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 TO Date: 7/13/81 914 REFERENCE. SOHIO FINAL DATA CASED HOLE The following malerial,sbem~'submltted herew,th Please acknowledge receipt by s,gmnga copy of th~s letter and returning it to th~s offlce:- CNL (Sch) 5/9/81 (t3 EPL (Sch) 5/6/81 #1 5" CCL/perf. (Sch) 5/12/81 #2 5" CNL (Sch) 5/16/81 #1 5" CNL (Sch) 5/2/81 #7 5" Spinner (Go) 6/13/81 #1 5" CCL/Perf/Tie In (Go) 6/14/81 #1 5" CNL CNL (Sch) 5/15/81 #3 5" (Sch) 5/14/81 //3 5" DATE AI~,cho~ age Carol Krieher Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY June 23, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL' POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Co~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Wells D-12, D-13, H-10~ Enclosed, in duplicate, are the following forms for the above- named wells: 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notices & Reports on Wells; 3. Form 10-404, Monthly Report of Drilling & Workover Operations. ( 'G: J. I Pl~sg.a_ ~ ~ Distriet( Field Engineer GJP:ja Enclosures cc: Well File #17 S. R. Bundy A. E. Leske Geology JUL 0 8 Alaska Oil & 6as Co.s Anchorage STATE OF ALASKA ~ ALASKA ILAND GAS CONSERVATION C ,1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class,f,cat,on of Serwce Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number Sohio Alaska Petroleum ~y 80-68 3 Address 8 APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20485 4 Locauon of well at surface 9 Un,t or Lease Name 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval 10 Well Number 1373' SNL, 2009' EWL, Sec. 21, TllN, R13E, UPM H-11 (22-21-11-13) At Total Depth 11 F~eld and Pool 1337' SNL, 1863' EWL, Sec. 21, TllN, R13E, UPM Prudhoe Bay 5 Elevat,on ,n feet (,nd,cate KB, DF, etc ) 6 Lease Des,gnat,on and Ser,al No Prudhoe Oil Pool KBE = 76.49' AMSL ADL 28284 12 Date Spudded 13 Date T D Reached 14 Date Comp , Susp or Aband 115 Water Depth, ,f offshore 116 No of Compleuons 8/31/80 9/13/80 5/8/81I feet MSLI one ,TTotalDepth(MD+TVD, 18 Plug Back Depth ,MD+TVD) 19 D,rect,onalSurvey I 20 Depth where SSSV set 121Th,ckness of PermafroSt 9875'MD 9464'TVD 9830'MD 94201TVD YES ~ NO [] 2000 feet MD 1950' GL 22 Type Electric or Other Logs Run SP/GR/DIL, DIL/BHCS/SP/GR, FDC/QN-L/Cal, GR, RF2, sidewall cores 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulated ConductoI Surface 110' 36" 8 cu.vds, concrete 13 3/8" 72~ L-80 Surface 2696' 17 1/2" 4092 cu. ft. Arcticset II 9 5/8" 47~ L-80 Surface 8942' ,12 1/4" 1438 cu. ft. Class G: 130 cu. ft. Arcticset I 7" 29# L-80 8391' 9873' 8 1/2" 428 cu. ft. Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) MD TVD SIZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool -- Top: 9206' 8816' 4 1/2" 8433' 8329' Bottom: 9304 ' 8910 ' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9206-9244'BKB 0.5"@8spf~Ref. BHCS/GR, 9/14/80) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9254-9265 'BKB" " *( " ) 9286-9304 'BKB " 4spf ( " ) * shot in 4 spf increments 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc..) 5/8/81 Flcwing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~ I Flow Tubm.g Casing Pressure CALCULATED OIL-BBL G'AS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 24-HOUR RATE ~ 28 CDR E DATA Dr,cf descrlpt,on of Ilthology, poros,ty, fractures, apparent dips and presence of od, gas or water Subm,t core ch,ps ~EEEiv~. None JUL 0 8 I ~,~ ~ias~a Oil & ?"~' ~r~r,~orag-~C°ns c Form 10-407 Submit ~n duplicate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 3O GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT DEPTH GOR, and t,me of each phase BKB Subsea Sag River SST. 9005 ' 8547 ' Shublik 9038' 8578' Ivishak 9128 ' 8664 ' 31. LIST OF ATTACHMENTS None 32 I hereby c~,rtl~y ~(~lng Is true and correct to the best of my knowledge ' S,gne~]"-,. ~ ~ (;[.-'[~. T,tle District Field Date ~ ('/ ~ / /~/ 'G~ J,./Ylisga ,~ Engineer / '/ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If th~s well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 // STATE OF ALASKA O~I ALASKA (OIL AND GAS CONSERVATION C v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator Sohio Alaska Petroleum Company 3 Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5 Elevation in feet (~ndicate KB, DF, etc ) 6 Lease Designation and Serial No KBE = 76.49 ' AMSL ADL 28284 12 7 Permit No 80-68 8 APl Number 50-029-20485 9. Un,t or Lease Name Prudhoe Bay Unit 10. Well Number H-ii (22-21-11-i3) 11 F~eld and Pool Prudhoe Bay Prudhce Oil Pool (Submit ~n Triplicate) Perforate [] Alter Casing [] . Perforations Stimulate [] Abandon [] Stimulation Repmr Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit m Duplicate) [] Altering Cas,ng [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) The following intervals were perforated on May 8, 1981, using GO Int'l. 3 1/8" carrier guns at 4 spf: 9206' - 9244' BKB (Ref. BHCS/GR, 9/14/80) 9254' - 9265' BKB ( " ) 9286' - 9304' BKB ( " ) An SSSVwas set and tested in the ball valve nipple ca. 2000'. 14 I hereby ce~il~)fY/I th~t'~~~J ~s true. and correct to the best of my knowledge S,gned _/~/~.~~3 ~ --~-- T,tle District Field Enqineer Thespac{19~elow'forC.~m,sslonuse ~ ~. Plisga Conditions of Approval, ~f any JUL o 8 i~, Alaska Oil & C~a.~ COns Anchorag~ Date ~/~- ?/(~'/ By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Tr~phcate and "Subsequent Reports" ~n Duplicate MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1 Drdl~ng well [] Workover operation [] 2 Name of operator 7 Permit No Sohio Alaska Petroleum ~y 80-68 3 Address 8 APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20485 4 Location of Well at surface 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5 Elevation ,n feet (~nd~cate KB, DF, etc ) 16 Lease Designation and Serial No kq~R = 76.4g' AI~qT,I ADT, 2R2R4 9 Umt or Lease Name Prudhoe Bay Unit 10 Well No H-11 (22-21-11-13) 11 F~eld and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of June ,19 81 12 Depth at end of month, footage drilled, fishing jobs, d~rect~onal drdlmg problems, spud date, remarks 13 Casing or I~ner run and quantities of cement, results of pressur9 tests 14 CorIng resume and brief description 15 Logs run and depth where run 1 6 DST data, perforating data, shows of H2S, m~scellaneous data See attachment I hereby ~;if~at the ~6~7 is true and correct to the best of my knowledge LS'GNE , .[y~.~L-~'"'"-.~ ~ d~-~_ TITLE District Field Engineer DATE F,~ / ~)- q F J ri ~ / I NOTE--~rport on tl~s__~orm is required fc~ each calendar month, regardless of the status of operations, and must be fll{~d in duplh:::ate/wlth and Gas ConservatCo"n Commission by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Rev 7-1-80 the Alaska Submit ~n duphcate PERFORATING DATA - Well H-il May 4, 1981: Pressure tested tubing and inner annulus. May 8, 1981: Rigged up GO Int'l. and perforated the following intervals using 3 1/8" carrier guns at 4 spf: 9206'-9244' BKB (Ref. BHCS/GR, 9/14/80) 9254' - 9265' BKB ( " ) 9286' - 9304' BKB ( " ) Put well on production. May 22, 1981: Shut well in to prepare for static pressure survey. May 24, 1981: Ran static pressure/temperature survey at 8800' TVDss. May 26, 1981: Set and tested SSSV in ball valve nipple ca. 2000'. Well on production. - SOHIO C0 IF]DEIITIAL , SOHIO ALASKA PETROLEUM COMPANY o ARCO ~o SFO/UN~T/ST ~o~ ..... 3] 11 ' C" SIREEI ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL POUCH 6 61:2 ANCHORAGE, ALASKA 99502 Date: 6/3/81 REFERENCE SOHIO FINAL DATA The following mater~al ~s being submitted herewith. Please acknowledge receipt by mgnmg a copy of this letter and returning ~t to th~s office'-- SFO/UNIT/STATE': (-Marathon) ~L/A/-' 6 Flowmeter p/p/B_4 Spinner ~B-13 Perf.CCL/Tie In Log ~/~B-16 CCL Perf. CCL/Tie In Log CCL/Tie In Log //6/J-11 DDNLL DDNLL p/Y- 2 (Cased Hole Finals) (go) 5/19/81 #1 (go)' 5/17/81 #1 (go) 5/19/81 #1 (go) 5/12/81 #1 (go) 5/8/81 #1 (go) 5/10/81 #1 (dres) 4/18/81 #1 (dres) 4/16/81 #1 Diff.Temp.Log , (go) 5/7/81 RECI~IVED _ q~' Of< ~'.' " 11 5II 5~ 5" 5~ 5'~ 5" 5~ #1 5" Development Geology Well Records it SOHIO ALASKA PETROLEUM COMPANY April 2, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 J MAIL POUCH 6-61 I I ~NG ANCHORAGE ALASKA~12-1 E _ ~)~. · 2E JJ 1 STAT T~C ~ STA~ TEC Attn: Mr. H. H. Hamilton Gentlemen: Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate the wells. (~urs very truly, GJP:ja Enclosures cc: Well File #17 S. R. Bundy A. E. Leske - .~. AND GAS CONSERVATION ,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I~: COMPLETED WELL [] OTHER I-I 2 Name of Operator 7 Permit No. Sohio Alask~ Petroleum Company 80-68 3 Address 8 APl Number ~ouc, l 6-612, Anchorage, Alaska 99502 s0-029-20485 4 Location of Well 9. Unit or Lease Name At surface: Prudhoe Bay Unit 10. Well Number 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM H-ii (22-21-11-13) 11. F~eld and Pool Prudhoe Bay 5. Elevat,on in feet (ind,cate KB, DF. etc.) 6. Lease Des,gnation and Ser,al No. Pru(~aoe Oil KBE = 76.49' AMSL ADL 28284 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF: (Submit ~n Tripl,cate) (Submit In Duplicate) Perforate l~ Alter Casing [] . Perforations [-1 Altering Casing Stimulate [] Abandon [-] Stimulation (-I Abandonment r~ Repmr Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during April/May 1981, using GO Int'l. 3 1/8" carrier guns at 4 spf: 9206' -9244' BKB (Ref. BHCS/GR, 9/14/80) 9254' - 9265' BKB ( " ) 9286' - 9304' BKB ( " ) An SSSV will be set and tested in the ball valve nipple ca. 2000'. RECEIYEO APR - 6 1981 RNa, la 011 & G~ Cons. Comml~sio. ,, , 14 I hereb rtif true and correct to the best of my knowledge. Approved Returned : ' By Order of Approved by t / ~ COMMISSIONER the Corem,ss,on Date 4 ~-~'--~-r Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" in Duphcate SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: A~C0 EXXON PHILLIPS REFERENCE: ANCHORAGE, A L~__~A4 TELEPHONE (907);~- ~ ~..~ MAIL: POUCH 6~2 ANCHORAGE, ALASI~A ~T' TEC ii ~ --I~TfT TEC ! .... ~o/3o/8o SOHIO MAGNETIC TAPES c Yohe following materia~ is beim§ submitted herewith. P~ease ackmow~edge receipt by sigmimg a p¥ of this ~e~er amd returmimg it to this office:- !_1 ....... ~agnetic LIS Tape ~l&2 ~61014 9/14/80 X-14 Magnetic LIS Tape ~1 ~61107 10/15/80 Well Records RECE~' '~ DATE 19 SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO. ARCO / 3111 'C" STRE ANCHORAGE, AL TELEPHONE (907) MAIL: POUCH I ANCHORAGE, ALAS', EXXON 10/28/80 ¢/4 PHILLIPS SFO STATE ~ SOHIO MAGNETIC LIS TAPES /T,H~owing materialisbeingsubm~tt~ herewith. Pleaseacknowled~ rece~ptbysigninga ~/'cop¥ofthisle~erandreturningittothisoffice:- //H-l~_~~Magnetic LIS Tape 10/15/80 #1&2 (SFO-Magnetic Tape sent directly from Ventura) #61103 X-12 Magnetic LIS Tape 8/25/80 #1 Carol Kriet&r Well Records #60762 ' ~ T.2, g 19~?~ ;FO/UNIT/STATE: SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO' SFO/UNIT/STATE REFERENCE: 3111 "C" STR A ANCHORAGE, TELEPHONE (907) MAI L: POUCH ANCHORAGE, ALASI Mol)il Philhps BPAE SFO 9/30/80 #384 i 5I! 2" & 5" 2" & 5" 2" & 5" 2" & 5" 9/ /80:State TheO FINAL DATA following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- H-11 RFT 9/14180 #1 H-il BHCS 9/14/80 #2 H-ii FDC/CNL 9/14/80 #1 H-11 FDC 9/14/80 #1 H-Ii DIL 9/10/80 & 9/14/80 #1&2 STATE ONLY: H-ii H-11 H-11 Magnetic Single Shot Survey Gyroscopic Survey Sidewall Summary Sheet 9/1-14/80 9/20/80 19 Carol Krieter Well Records SOHIO ALASKA PETROLEUM COMPANY October 8, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 1 co~ ANCHORAGE A~S~ARES ~I~O / TELEPHONE (907) ~;,~ ~A,L: POUCH ~-~ ~,~-~ lZi STAT TEC- Attn: Mr. H. H. Hamilton Gentlemen: Well H-Ii (22-21-11-13) Enclosed, in duplicate, is Form P-7, Completion Report, for the above-named well together with the Well History, Well Logs, Directional Surveys, and Sidewall Core Data Sheet. This well has been suspended pending perforating operations. RHR: ja Enclosures cc: Well File 917 Geology Yours very truly, R. H. Reiley District Drilling Engineer Form P--7 / SUBMIT IN DUP ,TE* STATE OF ALASKA (See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLi I DRYD Other b TYPE OF COMPLETION NEW WORK [--I DEEP- PLUG DIFF WELL F-~ OVER I I EN D [--I RESER BACK D Other 2 NAME OF OPERATOR Sohio Alaska Petroleum Company 3 ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 99502 4 LOCATION OF WELL (Report location clearly and in accordance with any State reclulrements)* At surface 1873' SNL, 1264' At top prod interval reported below top 1477' SNL, 2035' At total depth 1337' SNL, 1863' WEL, Sec. 21, TllN, of Sag R. SST. EWL, Sec. 21, TllN, R13E, UPM R13E, UPM EWL, Sec. 21, TllN, 13 DATE SPUDDED 114 DATETD REACHED 8/31/80I 9/13/80 18 TOTAL DEPTH, MD & TVD 119 PLUG BACK I DEPTH 9875'MD 9464'TVD I 9830'MD 22 PRODUCING INTERVAL(S). OF THIS COMPLETION - TOP. BOTTOM. NAME (MD & TVD)* None 15. DATE COMP, SUSP, OR ABAND 9/19/80 MD & TVDI20 IFHowMULTIPLEMANY~ COMPL . 9420 'TVD I 5 APl NUMERICAL CODE 50-~20485 ,6 LEASE DESIGNATION AND SERIAL NO ADL 28284 7 IF INDIAN, ALLOTTEE OR TRIBE NAME B UNIT, FARM OR LEASE NAME Prudh~e b~y 9 H-11~ 22-21-11-131 10~E-L'O'~ND POOL. OR WILDCAT Prudhoe Ba¥,Prudhoe Oil Poo 1 SEC, T, R, M, (BOTTOM HOLE OBJECTIVE) Sec. 21, TllN, R13E, UPM 12 PERMIT NO R13E, UPM 80-68 16 ELEVATIOh)6"~, RKB, RT, GR, ETC)* 1~7 ELEV CASINGHEAD KBE =~76~49' AMSL IBF = 47.29' AMSL ~._.~.-- I 21 ROTARY TOOLS INTERVALS Dm HILLED BY CABLE TOOLS Total 23 WAS DIRECTIONAL SURVEY MADE Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN SP/GR/DIL, DIL/BHCS/SP/GR, 25 CASING SIZE 20 "x30" 13 3/8" 9 5/~" 7" 26 SIZE IWEIGHT, LB/FT /GRADE! DEPTHSET(MD) Insulated C~nduct~r 110' / / 47# IL-80 / 8942' 29{ IL-80 183,~'-~87~' LINER RECORD BOTTOM (MD) TOP (MD) 28 PERFORATIONS OPEN TO PRODUCTION FDC/CNL/Cal, GR, RFT, Sidewall Cores CASING RECORD (Report all strings set in well) HOLE SIZE I CEMENTING RECORD I AMOUNT PULLED 36" 8 cu.yds, concrete 17 1/2 14092 cu. ft. Arcticset II 1/2" I 428 cu.ft, class G I 27 I TUBING RECORD SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 4 1/2" 8433' 8329' 29 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED (Interval. size and number) None 3O DATE FIRST PRODUCTION DATE OF TEST HOURS TESTED ICHOKE SIZE ~ PROD'N FOR I TEST PERIOD FLOWTUBING CASING PRESSURE ~CALCULATED OIL--BBL 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc ) PRODUCTION 32 LIST OF ATTACHMENTS Well History, IPRODUCTION METHOD (flowing, gas lift, pumping--size and type of pump) OIL-BBL Well Logs, Directional Surveys, I WE LL STATUS (Producing or shut-In) GAS--MCF WATER-BBL IOIL GRAVITY-APl (CORR) I OCTIO WITNESSED BY Sidewall Core Data Sheet 33 I hereby certify tha~t~e foregot~g and aj~Al~hed Information Is co~nplete and correct as determined from all available records. SIGNED 'R. H. Reil~¥ ---~k,~ *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: Th~s form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indmate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on this form and ~n any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in ~tem 22 show the producing ~nterval, or ~ntervals, top(s), bottom(s) and name(s) (~f any) for only the ~nterval reported in item 30. Submit a separate report (page) on th~s form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such ~nterval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on th~s form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUEVERT DEPT BKB Subsea Sag River SST. 9005' 8547' Shublik 9038' 8578' Ivishak 9128' 8664' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER ..... See attached sheet. WELL: H-11 pg. 1 · SIDEWALL CORE REPORT DEPTH 9795' 9758' 9720' 9694' 9650' 9620' 9585' 9550' 9528' 9496' 9492' 9488' 9484' 9480' 9450' 9425' 9400' 9380' 9365' 9355' 9344' 9325' 9305' 9286' 9261' 9235' 9274' 9135' 9125' 9025' 9735' 9707' 9675' 9667' 9634' 9601' 9575' 9541' 9488' 9467' 9415' 9405' 9395' 9371' 9365' 9361' 9352' 9344' 9335' 9325' 9277' 9246' 9225' 9215' 9187' 9157' 9111' 9095' 9077' RECOVERY Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes No Yes Yes Yes Yes Yes Yes No Yes No Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes No Yes Yes Yes No Yes Yes Yes No Yes No Yes Yes Yes No No No Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes LITHOLOGY Shal6 SS SS SS SS SS SS SS SS SS SS SS SS SS SS SS SS Congl. SS SS SS SS SS SS SS Limestone SS ? SS SS SS SS SS SS SS SS SS ? ? ? SS SS SS SS SS SS Limestone Shale Shale WELL: DEPTH 9768' 9748' 9714' 9688' 9657' 9645' 9626' 9611' 9566' 9557' 9523' 9515' 9505' 9475' 9455' 9443' 9434' 9310' 9296' 9265' 9197' 9166' 9143' 9130' 9122' 9104' 9063' 9030' 9013' 8995' H-II pg. 2 SIDEWALL CORE REPORT RECOVERY Yes Yes Yes Yes Yes Yes No Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes No Yes Yes Yes Yes Yes Yes Yes Yes Yes No LITHOLOGY SS SS SS SS SS Siltstone SS SS SS SS SS SS SS SS SS SS SS SS SS SS SS Shale Shale Limestone Limestone SS SS Shale Well H-Ii (22-21-11-13) WELL HISTORY August, 1980 Spudded well at 0600 hours, August 31, 1980. Drilled 17 1/2" hole to 1750'. September, 1980 Continued drilling 17 1/2" hole to 2700'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2696'. Cemented with 4092 cu.ft. Arcticset II cement. Installed and tested BOPE. Cleaned out to 2649', tested casing to 3000 psi, okay. Drilled out to 2714', ran leak- off test to 0.66 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8948'. Ran open hole logs. Ran 229 jts. 9 5/8" 47# L-80 Buttress casing to 8942'. Cemented in two stages: First stage with 1438 cu.ft. Class G cement; second stage through D.V. ~acker at 2608' with 130 cu.ft. Arcticset I cement preceded by Arctic Pack. Cleaned out to 8900', tested casing to 3000 psi, okay. Drilled out to 8972', performed formation competency test to 0.7 psi/ft, gradient. Directionally drilled 8 1/2" hole to 923-~'. Ran open hole logs and sidewall cores. Ran 37 jts. 7" 29# L-80 Buttress casing to 9873'. Cemented with 428 cu.ft. Class G cement. Cleaned out to 9830', tested casing to 3000 psi, okay. Changed well over to NaCl; ran CBL. Ran 197 jts. 4 1/2" 12.6# L-80 IPC tubing to 8433'. Landed tubing with ball valve at 1997'. Installed and tested tree. Displaced tubing to diesel, set packer at 8329'. Tested tubing to 3500 psi, okay. Released rig at 0700 hours, September 19, 1980. P.O. F~X 11~9 PAi~'~I~,~R. Ai. AS~,A 99645 September 19, '1980 Mr. Brian ~ose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AX 99502 Magnetic Single Shot Survey Job No. A0980-014 Well H-11 (22-21-11-13) Predhoe Bay Field North Slope, Alaska Date of Survey: 9/1/80 to 9/14/8o Dear Mr. Rose: Please find enclosed the "Original" and six (6) copies of our Magnetic Single-shot Survey on the above well. 'The method used in calculating this survey was radius of curvature. The depth interval of the survey was 2696 to 9875. Thank you for giving us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants Directional Supervisor CON~PLETION REPORT SOHIO ALASKA PETROLEUM MAGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE METHO[) OF COMPUTED FOR CDC BY FM L INDSP_Y COMPUTAT I ON & ASSOC · 15 SEP 80 WELL H-11 K B E LEV 75.89 RECORD OF ALL CALCULATIONS PFRFORMED BY TR~JE M~AS. DRIFT VERTICAL DEPTH ANGLE DEPTH D ~4 SUB DRIFT SEA DIREC DEG, 0 0 0 ASSUMED VFRT!CAL T O,OO -75,89 N O,OUE O 2696, 2606 0 0 2606,00 2810 1 45 2809,9~ 2903 4 0 2902,85 2996 6 0 2995,50 3091 8 15 3089.76 3185 11 0 3182,42 3278 13 30 3273.30 3374 16 0 3366.13 3469 1R 30 3456.85 3562 20 4.~. 354~,44 4008 21 0 3961.16 447B 21 15 4399.58 4946 20 45 4836,49 5417 21 0 5276.58 5881 21 30 5709.03 6191 20 45 5998.19 6~6 21 30 6282.69 6745 21 15 6514.56 7217 20 G5 6955,21 7687 19 0 7397e20 ~037 21 0 7726.08 2620,11 2826,96 2~19,61 3013.87 3106,53 3197.41 3290,24 3380,96 ~6~.55 3P85,27 4323.69 4760,60 5200.69 5633.14 ~922.30 6206,80 6438.67 6879.32 7321.31 7650.19 N O,OOE $68,00W N81,OOW N74,00W NTn,OOW N82,00W NBS,00W · NS~,OOW' Ng0,oow SS~,OOW S88,00W S89.00W sg0.oow S90.OOW N87,00W N87.00W ~185,00W N83.00W N74,00W N&2,00W N56.00W &URVEY ELECTRONIC COMPUTER TOTAL COORDINATES 0.00 S 0,00 W CLOSURES DISTANCE ANGLt D M 0,00 S 0 0 0 W 0.00 S 0,00 W 0.82 N 1.22 W 0,30 N 5,80 W 2.05 N 13,71W ~,90 N 25,14 W 7,63 N 40,61 W 9.86 N 60.21 W 11,36 N 84,60 W 11.85 N 112,77 W 11.30 N 143.99'W 5.76 N 302.82 W 1,32 N 472,15 W 0,13 S 639.86 W 0,13 S 807,69 W ~e26 N 975,78 W 10,11N 1087,35 W 17.77 N 1197,00 W 27.26 N 1287,25 W 60,95 N 1452,84 W 120.69 N 1600,71 W 182.32 N 170~.27 W 0,00 S 0 0 0 W 1.47 N 55 59 59 W 5,81N 86 59 b8 W 13.86 N 81 27 58 W 25,61N 78 57 19 W 41.32 N 79 21 8 W 61.01 N 80 41 32 W 85,36 N 82 21 8 W 113.39 N 84 0 0 W 144.44 N 85 30 3~ W 302,87 N 88 54 36 W 472.15 N 89 50 20 W 639,86 $ 89 59 1~ W 807.69 S 89 59 25 W 975,79 N 89 4~ 58 W 1087,~0 N 89 28 1 W 1197.13 N 89 8 56 W 1287,5~ N 88 ~7 11W 1~94,11 N 87 3~ 9! W 1605.25 N 85 41 16 W 1713.00 N 8~ 53 24 W DOG LEG ~EVERITY DEG/iOOFT 0.000 0.000 1.538 , 2,429 2.152 2,370 2.930 2,69~ 2,615 2,640 2,~34 0,056 0.060 0.110 0,053 0,138 0,242 O.Z61 0,146 0,262 0,~60 0,612 SECTION DISTAl, CE 0,00 0.00 1,38'-- 5.71 . 13,81 25,59 60,85 112,~1 142,64 ' 295,76 622,07 785,24 9~9.70 1359,55 1167.95 1257.91 la25.78 10o~.66 WELL H-Il SINGLE SHOT SURVEY RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 1~ SEP 80 _ TRUE '~EAS, I)RIFT VERTICAL SUB DRIFT DEP Trt ANiGLE DEPTH SEA DIRFC __ D _~M . DEG, TOTAL COORDINATES 84~1 21 0 8140.59 6064.70 'N49.00W 8735 lq 15 8379.07 8303.18 N'64,0QW 8861 18 45 8498,20 8422,31 N64,00W 9~27 12 15 9428,57 9352,68 N43.00W 279.12 N 1829.42 W 327,22 N 1902,09 W 345,20 N 1938,96 W 497,81N 2145.21W TD EXTENDED TO 9875, 9575 12 15 9~75.48 9399.~.~9 N4~,Dg_w 505,26 N 2152.15 W HOLE CLOSURE 2210.67 FEET AT N 76 47 16 W -, C L O $ U R E b DISTANCE ANGLE D M 1850,59 N 81 19 ~0 W 1930,03 N 80 14 19 W 1969,45 N 79 54 18 ~ 2202.21 N 76 56 6 ~ 2210,67 N 76 47 lb W DOG LEG SEgERITY DEG/iOOFT 0,565 0,942 0.397 0,680 ,0,000 SECTION DISTANCE 18~3,96 2202,14 2210,63 . ! SOHIO WELL H-Il SINGLE SHOT SURVEY INTERPOLATED TRUE VFRTICAL DEPTHS, COORDINATES AND C~LOSURES FOR GIVEN DEPTHS TRUE --'CODE MEASURED VFRTICAL I',IA~4E DEPTH DEPTH TOfAL C~D6~D i N~T~'~'~ C L 0 ~ URgE DISTANCE ANGLE D M $ 15 SEP BO SUB SEA Aq~) OTHFI,~ VEPTICAL DLPTH I)ATA SLJt~ Si A S Ir~(.,L[ SHOT SURVL, Fbi-: EVI:.RY LVbt4 lDO FELT ~'~D-TVD DIFFER[ NCF: VbR r I CAL CORRLCT I Of: I SUb SL A TOTAL L.,LP Tt-t. 176 2 '~ G 376 4'76 676 77& ;~ 76 1~576 1176 !776 1376 1476 1~76 ]676 1776 tn75 2(~76 ?116 22?6 2~76 ~776 ,'~76 2076 3A77 .317R ~506 176, 276, '%76, 476, 576, 676, 776. ~76. 97b. 1076, 1176, 1276. 1~76. 1476. 1576, ]676. 1776, 1976 · 2076 · 2176, 2276. 2376, 2476, 2576, 2676. 2776. 2876, 2976. ~076 , 3176, 3276. 3376, 3,476 · ~ll76 , ]00 0 U 200 0 0 400 0 0 .500 0 0 600 0 0 700 O 0 8 C)O 0 900 0 0 lOoO o 0 1100 0 0 1200 0 0 1300 1400 1500 0 0 1600 O 1700 0 0 1800 0 0 lOC0 0 0 200 0 0 0 2100 0 0 2200 0 0 230o 0 0 2400 0 0 2500 0 0 2600 0 0 2700 0 0 2800 0 0 2900 0 . 0 3000 1 1 3100 2 1 3200 5 3 33 0 0 8 3 3400 13 5 350O 20 7 O,uu O.dU 0.00 d,OO v,O0 d.Ou d,du o,Ou u.Ob O.OO u. Ob O,CO o. OO U,O0 4.48 7,44 9.92 ll. B2 lO · 89 LJe~O Om,JO ~JeUL) O, UO C,Ud J O,OU ,).49 ~.0~ il, fo ~9.31 oO, h'3 110.19 lbb.gC ,A I SOHIO WELL H-11 MEASURED DEPTH AND OTHER TRUE HEASURED VERTICAL DEPTH DEPTH DATA SUB SFA SINGLE SHOT SURVEY FOR EVERY EVEN 100 FEET OF SUB SEA MD-TVD VERTICAL DIFFERENCE CORRECTION TOTAL DEPTH. COORDINATE5 15 SEP 8O 3703 3676. 3810 3776. 3917 3876, 4024 3976, ~+131 4076. 4238 z+176. 4345 4276, G560 ~667 4576, a77~ ~676, ~881 G776. G988 ~876. 5095 Gg76, 5202 5076. 5309 5176. 5G16 5276. 5523 5376. 5631 5476, 9738 5576, 5845 5676. 5953 5776, 6060 5876. 6167 5976. 6274 6076, 6381 6176. 6~89 6276, 6596 6376. 6703 6a76, 6811 6576. 6918 6676. 7025 6776, 7132 6876. 7239 6976. 7346 7076e 3600 3700 3800 3900 4000 4100 420O 4300 4400 4500 4600 4700 4800 ~gO0 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 27 7 4! 7 48 7 55 7 62 7 69_ 7 77 8 SI+ 7 91 7 98 7 105 7 112 7 119 7 126 7 133 7 140 7 1~,7 7 155 8 162 7 169 7, 177 8 184 7 191 7 198 7 205 7 213 8 220 7 227 7 235 8 242 7 249 7 256 7 263 7 270 7 9,56 N 8,23 N 6,90 N 5,56 N 4.32 N 3.22 N 2.28 N le~9 N 0,85 N 0,37 N 0,05 N Oell S 0.13 S 0,13 S 0,13 0,13 $ 0,13 0,09 N 0,79 N le-96 N 3,60 N 5.63 N 7,66 N 9,66 N 11.79 N 14.41 N 17.54 N 21,22 N 25,45 N 30.~2 N 96,65 N ~4.19 N 53.02 N 63,14 N 74.63 N 193.87 W 231.95 W 270,15 W 308,47 W 346e91 W .385.43 W 424.03 W 462,9~ W 501,75 W 540,35 W 578.71 W 616.79 W 65~,74 W 692.7~ W 730,8~ W 769,03 W 807.33 W 845.77 W 884,65 W 923e60 ~ 962,62 W 1001,96 W 1040,69 W 1078,85 W 1116,85 W 1155.26 W 1194.33 W 1233,41 W 1272.12 W 1310,85 W 1348e97 W 1386.63 W 1~23.72 W 1460.3~ W 1~95.85 W SO~ilO WELL H-Il SINGLE SHOT SURVEf __ MEASURED DEPTH AND OTHLR DATA FOR gVgRY EVEN lO0 FEET OF SUB SEA DEPTH. TRUE r,~EASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION 7452 7176. 7100 276 6 7559 7276, 7200 _ 263 7 766~ 7376. 7300 288 5 7770 7476. 7400 294 6 7877 7576. 7500 .__ 3QQ _~ 6 7983 7676. 7600 ~07 7 8090 7776. 7700 314 7 ~197 787~, 780Q ~. 3~1 ......... 7 8305 7976, 7900 ~29 8 ! 8~lZ 8076, 8000 336 7 8519 8176. 8100 34'3 7 8625 8276. 8200 349 ' 6 8732 8~76. 8300 356 7 S837 8476. 8400 361 5 8943 8576. 8500 ~67 6 90~8 8676. 8600 ~72 5 9153 8776, 8700 377 5 9257 8876. 8800 38i 9361 8976. 8900 ~ 385 4 9464 9076. 9000 ~ 388 3 9568 9176. 9100 392 9670 9276. 9200 394 2 9773 937~. 93QQ_~ _3~7.~_ ' TOTAL COORDINATES 87.52 N 101.76 N 117.18 N 133.83 N 152.11N 171,74 N 193.05 N 215,~2 N 238.82 N 263.00 N 287.75 N 309.27 N 326.73 N 341.81 N 356.93 N 372.51 N 388.53 N 404.90 N 421,54 N 438,35 N 455.26 N 472.17 N 489.00 N 1530.04 1562,84 1594,07 1624.69 165b,95 1687,~3 171~,93 1750,08 1780,72 1810.52 1839.75 1869.80 1901.09 1932.01 1962.11 1990.31 2016e70 2041.28 2064,06 2085,07 2104.31 2121,80 2137.58 SOHIO WELL M--ll ' SINGLE SHOT SURVEY INTEPPOLATED VALUES FOR EVEN 100() FEET OF MgASURED DEPTH. TRUF ~,IEASURED VERT I CAL ,SUB DEPTH DFPTH SEA TOTAL EOORD INATE$ 1000 1000. 924. 2000 2000. 1924, t000 2999. 2923. 4000 3953. 3877. 5000 4886. 48'11. 6000 5819. 5743, 7000 6752, 6676. 8000 7691, 7615, 9000 8630. 8554. 0,00 S 0,00 W 0.00 S 0,00 W 2.17 N 14,11W 5,86 N 299,95 W 0.13 S 659.00 W 6,53 N 10%9,06 W 42.31N 1377,84 W 175e02_ N __ 1692,27 W 365.34 N 1977e63 W 15 SEP 80 l ..... SOHIO ALASKA PETROLEUM WELL H- II ...... t ~" R-AD'IU~r*OF'-CURg~TURE ...... MAGkETIC- SINGLE ........ -~ - SCA.F-1" ~- I000' ..... CEP ~-16rlBSO - _ , - * !AL*~ DEPTHS SHOWN ' --*-~ _ ! ARE TVD sperry-sun d A Fouch~ President Mr. Gary Plisga Sohio Alaska Petroleum Company 3111C. Street Anchorage, Alaska 99503 September 24, 1980 Re: Our Boss Gyroscopic Survey Job No. Boss-16668 Well H-11 (SEC21TllN R13E) Prudhoe Bay Field North Slope, Alaska Date of Survey: September 20, 1980 Operator: John Samec Dear Mr. Plisga: Please find enclosed the "Original" and eighteen (18) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours Very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclosures SPERRY-SUN WELL SURVEYING ANCHORAGE, ALASKA COMPUTATION DATE SEPTEMBER 22, 1980 IS_OH ! O_.A_~_K A_. P~ E T RP L E U_~_ C_Q.~iP_&N_Y H-11 (SEC 21 TllN RZ3E) PRUDHOE BAY _ALA SI<_A _ _ T~R U E ..... S U_B..~- S_E._A MEASURED VERTICAL VERTICAL INCL DEPTH DEPTH DEPTH DE COMPANY PAGE 1 [iALLO~_&UJ~V~..Y__~P_I EM B E R_~ 20 ,:._198_0_ BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16668 KELLY__B.U. SJiI.~.G_EJ_EV_.. : 76.49 FT,__. ..... OPERATOR-JOHN SAMEC COU. RSE. __.COURSE INATION DIRECTION SEVERITY G MIN DEGREES DEG/IO0 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 0 0.00 -76.49 100 100.00 23.51 200 .... 20p,.O0 ~3.51 300 299.99 223.50 400 399.99 323.50 ~00 599.98 523.49 O0 699.98 623,49 900 899,98 823,49 1000 999,98 923,49 ~.1~_0 ...... 1999.9__8 ....... !023.~9 1200 1199.97 1123.48 1300 1299,97 1223,~8 0 0 N O. 0 E 0.00 0.00 0 24 N 54.39 W .41 .21 N 0~33 S 89.89 W ............... ,32 .~2 N 0 2~ S 73. 0 W .20 .31 N 0 30 S 62.79 W .13 .00 N .O.__2.3___S._55_._O_W .............. 0 7 S 28.19 W .29 ,70 S 0 25 N 26,89 E .Q__.IZ ..... S .2.~ · 1_9_j~ ................. ,_65 ................ ...,3_.L$ 0 18 S 40. 0 E .08 .79 S 0 13 S 52.59 E .10 1.11 S 0 28 S 5~.39 E ,19 1,84 S 0 25 S 73.30 E ,16 2.19 S 0.00 0.00 · 29 W .33 1 ..0,,.6 W l_,_.l 3__ 1.88 W 1.90 2.62 W 2.54 3.2 9_ u ...... 3.61 W 3.33 3.49 W 3,28 3_,..22 _ _ u 3_, .0_~ 2.95 W 2.67 2.62 W 2.28 , . 2_,.~9 W 1,_88__ 1.77 W 1.27 1,07 W ,51 __1~0_______ 1399.97 ...... 152_3.78 1500 1~99.97 1~23.~8 1600 1599.97 1523.~8 1700 1699.97 1623.48 1800 1799,96 1723,47 1900 1899,96 1823,47 2000 1999,96 1923,47 2100 20~9-2~'~ ...... 202%,4'f 2200 2199.95 2123.46 2300 2299.91 2223.~2 20 S 86,80 E ,12 0 20 S 86.50 E .00 0 12 N 62.40 E .20 0__10 N 32_.~90 E .10 15 N 42 13 N 75 16 S 45 24 S 62 8 S 49 .59 E .09 · 0 E .14 , 0 E .25 · 69 E .17 . 89 E .75 · 39 E .7~ S 39 ~.1 $ ............ .43 ,W ......... 2.35 S .17 E -.73 2.28 S .62 E -1,15 2.08 S .85 E -1.33 1,79 S 1,08 E -1,48 1,58 S 1.42 E -1,76 1,70 S 1,78 E -2,1~ 2.03 S 2.27 E -2.69 2.83 S 3.35 E -3.93 4.71 S 5.12 E -6.10 2400 2399.86 2500 2499.81 2600 2599,77 2700 2800 2900 2699.75 2799.73 2899.62 2999.26 2323.37 1 2~23.32 1 2523.28 1 2623.26 1 2723.24 1 2823.13 3 2922.77 5 52 S 40, 0 E 57 S 35, 0 E 13 S 30,19 E 2 S 35.60 E 16 s 63.39 W 54 N 79, 0 W 37 N 71,79 W .05 ,18 .73 .22 1.76 3.00 7.20 S 7.19 E -8.71 9.85 S 9.22 E -11.32 12.17 S 10.73 E ........... -13.35 13.83 S 11.80 E -14.79 15.07 S 11.34 E -lq.6q lQ.gl S 7,01 E -10,40 1.83 12,73 S ,99 W -2.11 ALASKA PETROLEUM COMPANY PAGE SOHIO SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE, ALASKA H-11 (SEC 21 PRUDHOE BAY ALASKA TllN R13E) COMPUTATION DATE SEPTEMBER 22, 1980 DATE OF SURVEY SEPTEMBER 20, 1980 BOSS ~Y'RO~S~C'Op~c SURVE'Y JOB NUMBER BOSS-16668 KELLY BUSHING ELEV. = 76.49 FT. oPERATOR"DOHN SAMEC TRUE SUB-SEA MEASURED VERTICAL V E ~'l~'~-~ DEPTH DEPTH DEPTH COURSE INCLINATION DEG MIN COURSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/iO0 TOTAL RE~'T-A'NGULAR CO'oRDINAy'F'S ..... VE"]~-'F'I~-C~[ NORTH/SOUTH EAST/WEST SECTION 3100 3098.51 3022.02 3200 3197.01 3120.52 3300 3294.51 3218.02 3~00 3390.92 3314.43 3500 3485.99 3409.50 ~_6~_0_.___~9.78 3~_2~ . 3700 3672.96 3596.q7 3800 3766.05 3689.56 4000 3952.35 3875.86 4100 4045.53 3969.04 4200 4138.7~___~_t~.8 4300 231.89 4155.40 4~00 4324.93 4248,4~ 4500 418.oo 434i.51 4600 4510.99 4434.50 4700 4604.03 4527.54 4800 4697.25 4620.76 4900 4790.52 4714.03 5000 4883.75 4807.26 5100 4976,86 4900,37 8 22 11 26 14 8 16 35 19 28 21 6 21 25 N 78.70 W 2.86 N 80.10 kl 3.09 N 84. 0 W 2.83 9.78 S 12.79 W 10.05 6.6~ S 29.71 W 27.22 3.66 S 51.65 W 49.23 N 86.70 W 2,54 N 89. 0 W 2.98 S 87.39 W 2.05 1.56 S 78.05 W 75.37 ,44 S 108.99 W 105.65 .97 S 143.65 W 139.16 S 87,29 W ,.32 2.65 S 179.88 W 173.92 21 26 S 87.70 W 2_1_._14 .............. 7.6 o w ..15 .21 4.24 S 216,39 W 208.96 5.73 S 252.74 W 243.88 21 25 21 8 21 13 21 32 21 27 21 27 S 88.10 S 88.29 S 88. 0 .26 .29 7.10 S 289.08 W 278.82 8.24 S 325.36 W 313.74' 9.40 S 361.48 W 348.51 10,68 S 397.92 W 38~6 S 88. 0 W .31 S 88.20 W S 89.29 W .12 11,89 S 434.54 W A18.81 12.69 S 471.11W 454.10 13.17 S 507.89 W 489.68 21 42 S 89.20 .25 21 17 21 8 S 89.70 W N 88,50 W N 87.89 W N 87,.70 W 21 6 21 17 21 29 .29 .40 .29 .20 13.52 S 544.54 W 525.16 13.49 S 580.73 W 560.29 12.90 S 616.78 W 595-41 11.76 S 652.93 W 630.77 10.36 S 689,38 W 666,q8 5200 5070.05 5300 5163.45 5400 5256,78 5500 5349.94 5600 5442,99 5700 5535,91 5800 5628.80 59OO 5721.70 GO00 5814.66 6100 5907.69 4993.56 5086.96 5180.29 5273,45 5366.50 5q59.~2 5552.31 564-5.21 5738.17 5831,20 21 20 21 21 21 21 21 21 21 21 2 50 14 23 34 42 32 28 N 86.89 W N 86.60 W N 86.89 W N 87. 0 W N 87.89 W N 87.50 W N 87.89 N 87.50 N 87.39 N 87. 0 .54 .23 .~1 .16 .38 .25 .16 .15 .1G ,16 8.65 S 725.61 W 702.04 6.63 S 761.29 W 737.16 4.59 S 797.13 W 772.43 2,66 S 833,44 W 808.~3 1.03 S 870.04 W 844,04 · 45 N 906,95 W 880.22 1.94 N 943.97 W 916.50 3.43 N 980.93 W 952.72 5.06 N 1017.75 W 988.85 6.86 N 1054.38 W 1024.[3' I S 0 H I O_A_.L.A..S_K A H-Il (SEC 21 PRUDHOE BAY IA~LASKA MEASURED V DEPTH PET_R_OQLEUM COMPANY TllN R13E) TRUE SUB-SEA ERTICAL VERTICAL DEPTH DEPTH INC D SPERRY-SUN WELL SURVEYING COMPANY PAGE ANCHORAGE, ALASKA .............. : ............... DAIE_~E__S~R_~Y_,%EP_L[EB_,'~__.~8.0 ....... COMPUTATION DATE BOSS GYROSCOPIC SURVEY SEPTEMBER 22~ 1980 JOB NUMBER BOSS-16668 _,~ KELLY B~SHING ELEV, :..76,~9 FT_,., OPERATOR-dOHN SAMEC C 0 UB.._S_E COURSE DOG-LEG ................... TOTAL ....... LINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL EG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 6200 6000,91 5924,42 6300 6094.21 6017,72 6400 6187,28 6110.79 6500 6280,11 6203,62 6600 6372,99 6296,50 6800 6558,91 6482,42 6900 6651,73 6575,24 20 58 N 87.20 W 21 12 N 86,29 W 21 57 N 84,60 W 21 32 N 83, 0 W ~1 .... ~6 .......... 21 42 N 79,50 W 21 59 N 78,60 W ......... 7_0_0_0 .......... 6_l._4_~_,_~_9 ............ 666.8.,_0.0 ............ 21 ....... 5.2 .... ~_76., 3.9_W · 52 8,69 N 1090,54 W · 40 . 10,73 N 1126,45 W · 27 16.94 N 1199,96 W · 72 20,94 N 1236.80 W .~.2 .... ~5.-~7 N . .1273_.2~.u . ,78 31,93 N 1309,65 W · q4 39,00 N ' 1346.19 W 7100 6837,54 6761,05 21 6 N 73,60 W 1,28 7200 6930,89 6854,40 20 55 N 72.60 W .Al ______7_~_O.O .... 7_0_2_~_,_~0 ...... 6~,_0_1. 20 ~i~ .... N_7_~,~.O__W 7400 7118,50 7042,01 19 40 N 68,29 W 7500 7212,80 7136,31 19 10 N 65,79 W 7640 7~07.31 ~[}~m~ Z 1_9____0 ......... ~_6 ~9_W .................... ,.8.~ 7700 7325,21 7800 7419.18 7~09 ........ %5.1~78 8000 7606,04 8100 7698,98 8200 7791.74 8300 8400 8500 860O 8700 880O 7401.70 19 34 N 60.10 W 7495.67 20 24 N 58.50 W 7682,53 21 30 N 54,79 W 7775,47 21 50 N 53.79 W 7868,23 22 0 N 52, 0 W 7960.92 7884.43 22 5 N 50.50 W 8053,62 7977.13 21 58 N 48.29 W __8146.54 8070.05 21 24__ N 453~ W 8240,07 8163,58 20 4 N 54, 0 W 8334.16 8257.67 19 36 N 63,39 W 56.55 N 66.97 N ....... 1,!! ....... 7.~,_2_0_N ,8q 90,31 N · 97 . 103.27 N ................ LI_Z_._3_L_N 1.20 132.97 N 1.00 150.43 N ........ ,_E6 .. . :L6_~,_2~_._N 1,06 189,45 N · 50 211,00 N .......... ,69 233,52 N · 57 257,01N · 83 281.~2 N 1.14 306.63 N 3,26 329,50 N 3,22 347.11 N ...,89 ............... 3_6_2)~..N ............. l_~.2_~,~O.~.W 1,14 378,13 N 1955,05 · 87 394,79 N 1979.40 1,24 ~27,49 N 2027,52 8900 9000 . ?_IAO. 9200 8 4.~8 · 5 4 83_.5_%,_0 5 L8 ~ 8 N._6_1_.,_5_g 8523,33 8446.84 18 8 N 59.10 8618,35 8541,86 18 11 N 56,29 B_'LL3_._7_O ....... 8 637 ..al. 16.___ 52____N_5.EL._l.0__~ 8809.68 8733,19 15 ~2 N 54.60 1418.02 W 1452.33 W ._1485,64 W .... 1517,55 W 1548,16 W 1577,68..W 1606.74 W 1636.13 W 166~.89_~W 1695,75 W 1725,74 W 1755,5~ .... W 1784.79 W 1813,26 W 1840,.27. W 1867,21 W 1896,11 W 1060,36 1095,71 ~l.31_,~Z.__ 1168.54 1205.25 1241.~1 1278,60 1315,76 ........ 1353~.09 1389.71 1425,52 1460_,~6 1494,45 1527.28 1591.30 1624.04 . 1657 1691.32 1725,62 ...... 12~ · 9 5 1794.03 1827,56 1859,86 1891,52 1923,81 1986,57 2016.15 ~L,A_9 2070,74 SOHIO ALASKA H-11 (SEC 21 PRUDHOE BAY ALASKA PETROLEUM COMPANY T11N R13E) SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE, ALASKA DATE OF SURVEY SEPTEMBER COMPUTATION DATE BOSS GYROSCOPIC SURVEY SEPTEMBER 22, 1980 JOB NUMBER BOSS-16668 KELLY BUSHING ELEV. : PAGE A 20, 1980 76,49 FT. OPERATOR-UOHN SAMEC TRUE SUB-SEA MEASURED VE~Y-iCAL V ERT-i'cA L DEPTH DEPTH DEPTH COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST V~RTICAL SECTION 9300 8906.05 8829.56 15 13 9400 9002.67 8926.18 14 qO 9500 9099.50 9023,01 14 lq 9600 9196,q3 9119,94 14 1~ 9700 9293,~8 9216,99 13 38 9775__ 9366t~3 9289,94 1~ .... ~2 9875 9463,78 9387.29 13 12 N 52.10 ~ .83 .......... 4'43.39 N 2048.91 W N 51,29 W ,58 '459,38 N 2069.16 W N 50.20 W .52 475.17 N 2088.50 W N 48.29 W .AT 491.23 N 2107.13 W N 45.70 W .87 507.65 N 212..75 W N 45.39 W ,58 519.84 N 2137.18 W 2095.35 2118.85 2141.43 N 45.39 W 0.00 535.88 N 21 W 53.45 2163.39 2184.46 2199.46 · HORIZQN~T_.AL_D_IA?_LACEMENT : 2219.13 FEET AT NORTH, ...... 76..DEG, ....... 1..MI,.N.,..W~.E.S..T AT. MD = 9875 2219,13 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. O_ H_I_O_._A_L~A S_. K &_P E_T_R Q L E U M _.C_O M P I H-11 (SEC 21 T11N Ri~E) PRUDHOE BAY SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE~ ALASKA COMPUTATION DATE SEPTEMBER 229 1980 PAGE ,5 ........ D_A__TE___O_F .... S_UR_B_Y.-E__Y_~_.S~~':J_8 0 · dOB NUMBER BOSS-16668 KEL.L.Y___B_U~_U!NG_E_LE~..=. 7E-~ F~. OPERATOR-UOHN SAMEC _ I N.T..E'_.~R~P O].,._A_ZTE_B V A_L. P_'E_.& F OR. ~_ E V_ EN._.i O._O...O~_~EEF_,.T .... O.F ,. M TRUE SUB-SEA TOTAL MEASURED__ V_ERI]..CAL___~£~T_.T..CAL__REC_T~ULAR___COgED.I. NA.T_E&____.-J~D~%YD r'~ ~~C~L DEPTH DEPTH DEPTH NORTH/SOUTH EAST/wEsT DIFFERENCE CORRECTION 1000 999.98 923.49 1.11 S 2.62 W .02 .02 2000 1999.96 1923.~7 1.70 S 1.78 E .04 .01 ~ 3~_.Eo. _~2~_,Z& ....... 2~2Z,Z.'L ...... ~2,~3__..S _,...9_~__W . ,.7~ ..... "/_0 t- 4000 3952.35 3875.86 7.10 S 289.08 W ~7.65 46.92 5000 4883,75 4807.26 11.76 S 652,93 W 116.25 58.59 .... 6~_O_Q______.5~i~_..66___5~38~i.Z __5..06__N .... 1013._7_~83_._3_~., 7000 6744.49 6668.00 47.08 N 1382.6~ W 255.51 70.17 8000 7682.53 7606.04 189.~5 N 1695,75 W 317.~7 61.96 .... c)_O_O_Q _.8 61.8,3 5_ .8 5 ~ 1 ,.8 6 ............... ;~_.9_q_.,_7 9._..._N ~l.?)_7_9.,.~t_O_W .... 3_ 8_1 ,.$_5 6~_, 18 9875 9~+63.78 9387.29 535.88 N 2153.45 W ~11,22 29.57 H~.E~C.A_L_C_U L_A.T I O..N _.P_R OC E D .U._R_E. S_ A.R_E...~ B .AAE D__qN~_ ? H E_ U S E _Q F___:T.HR.~_E D I ME.N S_~_I~R A.~._D_I_U_,S ___OLC._U~~.D_, SOHIO ALASKA H-11 (SEC 21 PRUDHOE BAY ALASKA PETROLEUM COMPANY TllN R13E) SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGF~ COMPUTATION DAT'E' SEPTEMBER 22, 1980 PAGE 6 · DATE OF SURVEY SEPTEMBER 20, 1980 dOB NUMBER BOSS-16668 KELLY BUSHING ELEV. : 76.A9 FT. INTERPOLATED OPERATOR-JOHN VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH SAMEC MEASURED TRUE SUB-SEA VERTICAL VERTICAL TOTAL , RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH 0 0.00 -76.z+9 76 76,A9 0.00 176 176.~9 100.00 276 276.49 200,00 NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION o.oo ............. 0., 0._0 ............................. 0,.o..0 ............ · 11 N ,1_5 W .00 .00 .A2 N .84 U .00 .00 · 36 N 1.72 W .01 .00 376 376,A9 300.00 ~76 qY6,q9 ~00,00 5.7~ ......... 5~6,~9__ 500.,~0 676 676.~9 600,00 776 776.A9 700.00 ~76 876~.~9 800,00 976 976,~9 900,00 1076 1076.49 1000.00 1176 1176,q9 1100,00 1276 1276.~9 1200.00 1376 1376.49 1300.00 1~76 1476.49 1400.00 1576 1576,49 1500,00 1676 1676.q9 1600,00 1776 1776,49 1700.00 · 10 N 2.~4 W ,01 ,00 · 31 S 3,16 W ,01. ' .00 .6~_$ ................ ~,~,5.~.~,.'. : .... .o2 -OP ................ · 62 S 3.57 W .02 .00 · 25 S 3.27 W .02 .00 .69 S 3.02 U .02 .00 1.05 S 2.70 W .02 1.73 s ............... 1...e~ .... U~ ............ ~.o2 2,14 S 1.24 W .03 2.30 S ,57 W 2.3_9 S ..... ,. .03 E .03 2.:32 S ,5~ E ,03' 2.14 S .81 E 1,87 $ 1,01 E ,03 ,00 .00 .00 .00 .00 .00 .00 ,00 ,00 LS SPERRY-SUN WELL SUnVEYING ANCHORAGE, ALASKA _O]~LI.Q._A_.I. ASKA PETROLEUM COM.P.,A_NY H-Il (SEC 21 TI1N RI3E) COMPUTATION DATE PRUDHOE BAY SEPTEMBER 229 1980 ._~LA~.K A , ...... COMPANY PAGE 7 ~rA,,T,E...OF . S,URVEY.._._S.EPTEMBE.R ~0J__19___8__0 ....... · JOB NUMBER BOSS-16668 KEkk_Y__B.U_.%JJI.N_Cz__~_LE.Y_, : 76,~9 F_T,~__ OPERATOR-dOHN SAMEC · IJ~_T_E_B_P_P_L _A.~ E D_Y_A .L~U,_E..S F .O_R_._ E_V_E _N_i_O_O _. F E E T ..0 F... S_ U B. ,-. S E .A .... O E.P,T.H ................. · TRUE SUB-SEA TOTAL _B E_A..S/JJ~_L~E RT LC.A/._ V_E RT_I C.A L.. ..... FLE C_T_AJ~_G.U LA LC_O_O E_D/.N. AT ES ........ MD- T,VD ..... VE R T !C_AL DEPTH DEPTH DEPTH NORTH/SOUTH 1976 1976,49 1900,00 1,62 S 2076 2076.q9 2000.00 1.95 S ____g_k7_6 .....E1.7_6,_,~L9 .....?.I~O.,.EO _2.._5_3_$ 2276 2276.49 2200.00 4.13 S 2376 2376.49 2300,00 6,61 S EAST/WEST DIFFERENCE CORRECT 1.70 E 2.12 E 2.,~9. E .05 4-64 E .07 6.69 E .13 2576 2576.49 2500.00 2676 2676.49 2600.00 ..... 27.76____2LT_E~33 ..... 2/~0..0 2876 2876.49 2800.00 2977 2976.49 2900.00 ....... 3_~~.3~76~,_~ ....... 3i79 3176.49 3100.00 3281 3276.49 3200.00 3489 3476.49 3400.00 3596 3576.49 3500.00 11,74 S 10.48 E 13.49 S 11.56 E ._3,~_,.8.9_ $ ...... 1,.,1~8 0.. E 15.15 S 8.42 E 13.44 S 1.14 E k0~3.2_$ .............. 9,.2LS..W 7,34 S 25.7~ W 4.15 S 47.22 W ......... k,_8_O._S ........... · 51S 105,68 W · 91S 142.38 W .23 ,25 .27 ..... L,_27,.. 2.60 q,gq 13,45' 19,99 ............. 27,~0 ............ ION .00 .00 ,03 ' ,05 .°05 .05 .02 .07 · 1.33 2.34 4.99 6.54, 7.31 L~H_I_.O_ A L A~S K A PETROLEUM COMPANY SPERRY-~UN WELL--s'-ORVEY I NG ANCHORAGE. ALASKA COMPANY DATE OF SURVEY PAGE SEPTEMBER 20, 1980 .~ H-11 (SEC 21 PRUDHOE BAY ALASKA TllN R13E) COMPUTATION DATE SEPTEMBER 22, 1980 JOB NUMBER BOSS-16668 KELLY BUSHING ELEV. : 76,q9 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OPERATOR-JOHN SAMEC OEPTH MEASURED DEPTH · TRUE VERTICAL DEPTH 3811 3776.49 3918 3876.49 4025 3976.49 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 3~7.7_0_0.00 q.41 S 22.0,,;.99..,W ..... ' 34.73 3800.00 6.01 S 259.46 W 42.07 3900,00 7,41 S 298.55 W q9,44 VERTICAL CORRECTION 7.43 7.34 7.38 4240 4347 4276,49 ~ 4_5.5 ........... 4562 4670 4777 4884 4992 ~.}099 5206 5076.49 5313 5176.49 5421 5276.49 5528 5376.49 5636 5476.49 5743 5576.49 4~000.:~0_0 8.59 S_______.___337.33 W 56.71 4100.00 9.92 S 376.12 W 63.98 4200.00 11,29 S 415.51W 71.46 4400.00 12.98 S 494.16 W 86.38 4500,00 13,47 S 533.81W 93,95 4600.oo 13.55 s 572.70 w 101.25 7.26 7.27 7,49 7.45 7.47 7.58 7.30 ~700,00 13.04 S 611.36 W 108.47. 7.21 4800.00 11.86 S 650.10 W 115.71 7.25 490~0 10.36 S 689.23 W ....... !.23.~..~ ......... 7.~0 5000.00 8.52 S 728.08 W 130.41 7.30 5100,00 6.33 S 766.24 W 137.46 7.06 5200,00 ~.18 S 804.78 W 144,66 7,19 5300.00 2.11S ~q3.83 W 152.03,' 7.37 5~00.00 .54 S 883.28 W 159o54 7.51 5500.00 1.16 N 923.14 W 167.21 7,67 LS_O]:fI_O__&LA__$_K A_P_E_T RQLE U M .... C_OPP_A NI H-11 (SEC 21 PRUDHOE BAY _ALASI{A TllN R13E) SPERRY-SUN WELL SURVEYING COMPANY PAGE ANCHORAGE, ALASKA .......... ' ............... DATE...~F__~_U~VEY .... SEPTEMBER~.~__198.0 ....... COMPUTATION DATE ' SEPTEMBER 22~ 1980 dOB NUMBER BOSS-16668 K_E_LJJ__B_USHING_ELEV. = 76.49 FT. OPERATOR-dOHN SAMEC .... I N_T.E BP_O.LA_IKD_Y. AL.U E~_EQE_E_V. EJ~O_O ::, FEET.,:__O,F,, ,S UB-SEA. DE.P TH TRUE SUB-SEA TOTAL ~_U]tEL.__V_E]{.TJ_CAL___V_EJt]'_LC_~L ._ REC_T_AN.G_ULAR: . CO]IB~.T_E s TH DEPTH DEPTH NORTH/SOUTH EAST/WEST 5_8_5.1____ 56.76,5.9 560~O_,..O_O ....................... 2_,~65~N ~ 6_P.,.,_9._~._W 5958 5776,/.+9 5700,00 ~,,38 N 1002,69 W 6066 5876./+9 5800.00 6.21 N 1042.12 W MD-TVD .... V.ERTICAL. -'-D i-FEE R~NC E CORRE'cTI 0N ...... :! .......... ~7_5_,~ ............ 7,_6..~. 182.~7 7.62 189,98 7,51 j ..... :' -280 ooo.oo / z88 loo.oo t ............ 6~_~6 ............. 6_276.~9 ....... 6200,~00 ______ 6603 6376.~9 6300.00 6711 6q76,q9 6400.00 ...... 68~8 ....... 65_76,A~___. 6500 ,~ Q 6926 6676,~9 6600,00 703~ 6776,~9 6700,00 10,29 N 1119,59 W 204.50 13,16 N 1158,6~ W 211,89. 21,11N 1238,17 W 227,28 26,48 N 1277,37 W 25~,82 ~0,98 N 1355,99 W 250,21 50,10 N 1395,1~ W 257,99 7-3~ 7.14 '7.39 .7.~.72 7.67 7.54 7.63 7.78 7.77 7]~1 68%6.,q9 680.p.~.00_ 72~8 6976,49 6900,00 7355 7076,49 7000,00 7q61 7567 7276,~9 7200,00 767~ 7376,~9 7300,00 7779 7476,~9 7400,00 72.23 N lq68.89 U 272.31 7.05 8~.77 N 1503.57 W 278.89 6.58 112.5~ N 1568,20 W 290.92 5,85 128.51 N 1598.98 W 296.76 5.8~ 1~6,70 N 1650.05 W 50~.05 6.29 SOHIO ALASKA H-11 (SEC 21 PETROLEUM COMPANY TllN R13E) SPERRY-SUN 6/ELL SURVEYING COMPANY ANCHORAGE9 ALASKA COMPUTATION DA'iE PRUDHOE BAY ALASKA SEPTEMBER 229 1980 PAGE 10 DATE OF SURVEY SEPTEMBER 209 1980 JOB NUMBER BOSS-16668 KELLY BUSHING ELEV. : 76.49 FT. OPERATOR-JOHN SAMEC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEA~.URED VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7886 7576.49 ' 7500.00 166.57 N 7993 7676,/+9 7600.00 8101 7776.49 7700.00 8.2_0~ 7876,49__ 8316 7976,49 7900,00 8424 8076.49 8000,00 ........... 8_5,32 ........... 8638 8276.49 8200.00 87~4 8376,49 8300,00 88~.0~.__8476. t99__ ..... 8~0~.,..~0 8955 8576.49 8500.00 188,07 N 211.24 N 235.57 N 261,03 N 287.56 N 336,93 N 353.87 N 37O .27 N 387.18 N 1661.82..W ..... ~,.ym{ ~09'8~ 6'79 1693'81 6/ 317'02 7'18 1726'07 6/ 32/+'61 7'60 1758'14 tV 332'/+2 7'80 1789,67 W 340,32 7.90 1820.15 W 348.17 ~.86 18/+8.75 W 355.63 7./+5 1878,1/+ 6/ 362.25 6.63 1909.56 W 368./+/+ 6.19 1939,79 6/ 374.19 5.75 1967.9/+ 6/ 379.45 5.26 9061 8676.~9 8600,00 9165 8776,49 8700,00 9269 8876.49 8800.00 9372 8976,~9 8900.00 9476 9076.49 9000,00 9579 9176.49 9100.00 9682 9276,49 9200,00 9785 9376.49 9300,00 405,25 N 422,08 N 458,45 N 455.09 N 471.44 N 487.86 N 50q,77 N 521,50 N 1995,06 W 384,63 5.18 2019,91 6/ ~ 389,0z+ 4.41 20/+2.56 6/ ~' ............. 3'~"~';'87 3.~'3 2063,81 W 396.~+5 3.58 2084,01 W 399,77 2103.35 ~d 402.94 3,17 23.2~.8o w 406.03 3.09 2 i 38..86 ...... u ............. i .... ~.08..8.4 ......... ~. 82 H-Il (SEC 21 TllN R13E) CO', .,- ~vF~ bAlE PRUDHOE BAY SEPTEMBER 22, 1980 COMPANY PAGE 1 1. D A.T E...OF .... S._U.B..V_E.Y~SE P T E M B E R._ 2Q_~_l_~8.0 ..... JOB NUMBER BOSS-16668 KE. LL.Y__B~I_NG_E._LEV~ _= __ 7 G.._~9__F_~. .... OPERATOR-JOHN SAMEC IN_IE.B. EO L A. _T_E D__V_ALU E_S_EO R.. E.V..EN_IJkO ._. F [F._I_OLS. U_B '_t_$_E A :: DEP T H TRUE SUB-SEA TOTAL .BEA_S_U.E_E.D_____ V_ER~T.I£AL____V_EJt_T..I.CA L ..... R E CJ_A N G UL AFt__C.O_O.J)JiI.6LAT_E S ....... M D - T V_D DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE _VY.,.B_T I C A L CORRECTION THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN ._.____.LbiE_N~.S~O_OJL_~=(~ERDI~__EAD_LU_$._O_E_C_UB,_VA.TUR E_).. PO IN TS , i~ '1 ~ i 'r ~ , , ''~ ,' ,"~, , ~i '' , f ill, , ,, i; i :~:on~o Aiasl(~ LFetr¢ 1,eUm (:o )~ ,tl --~ i i t Sc ~ I" - I I II ~,~ , , 11 I I , ' i I ,I ~ t , , , r , r ~ , , , , ~ ~ , , , Check Form for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: Date Completion Report Well History Samples Required Core Chips Core Description Registered Survey Plat ' Date Received , Remarks Yes Yes t Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports /~0 ,'4/'~'~ Logs Run Yes /~-. Digitized Log Data SOHIO ALASKA PETROLEUM COMPANY October 6, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 3111 °'C" STREEt / "'J _~1'~_ ~L ANCHORAGE, ALAI~ TELEPHONE (907) 26, :~-'~1 _[::."N S _~ MAIL' POUCH6-6 2 J 2 E~-~', IFIiF: ---[ Attn: Mr. H. H. Hamilton Gentlemen: Well H-ii (22-21-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations for the above-named well for the month of September, 1980. RHR:ja Enclosures cc: Well File #17 Yours very truly, R. H. Reiley District Drilling Engineer Form No 10-404 REV 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE ( d~e, $ APl NUMERICAL CODE 50-029-20485 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 6. LEASE DESIGNATION AND SERIAL NO ADL 28284 Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612o Anchorage, Alaska 99502 4. LOCATION OF WELL At surface: 1873' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM & UNITFARMORLEASENAME Prudhoe Bay Unit 9 WELL NO. H-11 (22-21-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bayt Prudhoe Oil Pool 11 SEC. T. R. M (BOTTOM HOLE OBJECTIVE) Sec. 21, TllN, R13E, UPM 12. PERMIT NO. 80-68 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. September, 1980 Continued drilling 17 1/2" hole to 2700'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2696'. Cemented with 4092 cu.ft. Arcticset II cement. Installed and tested BOPE. Cleaned out to 2649', tested casing to 3000 psi, okay. Drilled out to 2714', ran leak-off test to 0.66 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8948'. Ran open hole logs. Ran 229 jts. 9 5/8" 47# L-80 Buttress casing to 8942'. Cemented in two stages: First stage with 1438 cu.ft. Class G cement; second stage through D.V. packer at 2608' with 130 cu.ft. Arcticset I cement pre- ceded by Arctic Pack. Cleaned out to 8900', tested casing to 3000 psi, okay. Drilled out to 8972', performed formation competency test to 0.7 psi/ft, gradient. Directionally drilled 8 1/2" hole to 9875'. Ran open hole logs and sidewall cores. Ran 37 jts. 7" 29# L-80 Buttress casing to 9873'. Cemented with 428 cu.ft. Class G cement. Cleaned out to 9830', tested casing to 3000 psi, okay. Changed well over to NaC1; ran CBL. Ran 197 jts. 4 1/2" 12.6# L-80 IPC tubing to 8433'. Landed tubing with ball valve at 1997'. Installed and tested tree. Displaced tubing to diesel, set packer at 8329'. Tested tubing to 3500 psi, okay. Released rig at 0700 hours, September 19, 1980. 14. s:~eNr;b/ cer~ TITLEDistrict Drilling EnqineerDATE lo. '~. ~O NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SOHIO ALASKA PETROLEUM COMPANY September 12, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well H-ii (22-21-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of August, 1980. RHR:sw Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE ( STAT E 0 F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE #50-029-20485 6. LEASE DESIGNATION AND SERIAL NO. ADL 28284 2. NAME OF OPERATOR 8 UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Ccmpany Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, Alaska 99502 H-11 (22-21-11-13) 4. LOCATION OF WELL At surface: 1873' SNL, 1266' WEL, Sec. 21, TllN, R13E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11 SEC T. R M. (BOTTOM HOLE OBJECTIVE) Sec. 21, TllN, R13E, UPM 12 PERMIT NO. 80-68 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. August 1980 Spud w~ll at 0600 hours August 31, 1980. Drilling 17 1/2" hole to 1750'. NOTG-Report on this form is required for eagh~endar month, regafdle~ o( the ~ztus o~ operation, and mu~ be filed in dupligate ~ith the oil and ~as gonservafion gommi~ by the lS~h of ~he sugg~in~ moflth,unl~ otherwise mAm~ o~'m~ (~ (n~mwk~ ~zc~ To witness B.O.P.E. Test '~...11 NO. H-11, SOHIO, 'sec. 21-T]]N-R13E ~PM Pezmtt No. 8O-68. ~ 1, 1980 I left Soh/~s Pad X where I witne~sed a B.O.P.E.~ ~ c~ w~ No. 13, eo ~ ii, ,~, ~'~'~~~~ ~.0.~'.~. ~ m ~~. ~ f~ ~o. % O&G #4 4/80 STATE OF ALASKA ' ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspect. ion Report Inspector /~/~ Operator ~ Well -/~ -II Location: Sec Drilling Contractor Date..2~ ~- ~'-O ;;ell I~ -/{ Rig Representative_ Permit # _~ ~Q /~% Casing Set Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure~ ~ ~ ~9 psig Pressure After Closure ~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: / N2 2~¥O0,21F~gz~.,%~'O0, ~%¥~ psig / ' / X ' Controls: Master Remote min~O sec min ~ sec Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves / 7 NO. flanges ~g Ad3 ustable Chokes / Hydrauically operated choke Test Results: Failures ./[//~/~"Z~' Test Time Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: ~--~V ~3-~ _O/Q ~'.F,3'~' / Test Pressure Test Pressure Test Pressure Tenet Pressure... Test Pressure hrs. days and Distribution orig. - LO&GCC cc - Operator cc - Supervisor June 20, 1980 ar. R. H. Reilmy District Drilling Sngineer Sohio Alaska Petroleu~ Cmspany Pouch 6-6X2 ~uohorage, Alaska 99502 Prudhoe Bay Unit H-IX Sohio Alaska Petroleum Company Permit No. 80-68 ~. I~C.s XS?3*SNL, X265'~, Sec 21, TI~, R131~, UPM. ~t~ole ~.t 1630'SNL, 1830*~, Sec 31, TIXN, RX3E, Dear Mr. Reiley~ Bnclooed is the approved application for permit to drill the above referenced well. Well samples, core chips and a mud log are not required. A d~rectional survey is required. If available, a tape contain- &rig the digitZsed log ~n£ormat~on on all logs shall be Sub- mitted for copFing except exper~ntal logs, velocity surveys and d/pester surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migrat~on of anadrosmus fish. Operations in ~ese areas are subJec2 to ~S 16.50.870 and ~e r~ulati~s pr~lgat~ ~ereunder (Title 5, Alas~ ~~istrative Code). Prior to c~enoing o~rat~ons y~ ~y ~ oontact~ by ~e Habits2 C~rdt~tor~8 office, ~par~nt of F~sh and ~me. Pollution of any. waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ./ ~r. a. H. Reiley PFudhoe Bay Unlt H-11 June 20, 1980 eommncAn9 operations you may be contaeted by a representative of the ~epertnent o~ Znvironnontal Conservation. Pursuant to AS 38.40, Local Hire Under S~ato Leases, ~he Alaska mepaz~n~ of Labor is being notified of the issuance of this penuit to dri! !. To aid us in scheduling field work, ye would appreciate your notifying this office vtthL, n 48 hours after the well is spudded. We would also ltke to be notified so that a repre- sentative of the ecm~tsston may be pEesent to vt theSe testing of blowout preventer equipment before surface casing shoe ~s dr~lled. In the event of suspension or abandonment, please gL.ye this off~ae adequate advance not,flea.ton so that we may nave a vitness present. Very truly yours, Harry #. Xuglor Alaska Oil & Gas Conservatio~ Comm:Lssion Bnclosuge cc~ Deparmnt of F:Lsh & Game, Habitat Section w/o encl, ~r~t of h~r~ Sure, asr, ~r ~v C~pl~ce Dtv~81~ v/o encl. SOHIO ALASKA PETROLEUM COMPANY J6ne 16, 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. H. H. Hamilton Gentlemen: Well H-II (22-21-11-13) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Surveyor's plat shc~ing well location, 4. Blowout Prevention Equipment Diagram. Enclosures Yours very truly, SOHIO ALASKAPETROLELI~CCHPANY District Drilling Engineer Form 10-401 REV. ].-1-71 la. TYPE OF WORK b TYPE OF WELL STATE OF ALASKA £ SUBMIT IN TRIP~ E (Othe~ mstruct~o~ on reverse side) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL I~] DEEPEN I-"] WELL WELL OTHER NAME OF OPERATOR Sohio Alaska Petroleum ~y SINGLE ZONE MULTIPLE 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 1873' SNL, 1266' WEL, Sec. 21, TllN, R13E, UPM At proposed prod. zone 1630' SNL: 1830' HgL: Sac. 21: TllN: RI3F.: IR 13 DISTANCE IN MILES AND DIP. EC~ON FROM NEAREST TOWN OR POST OFFICE* 10 miles NW of Deadhorse AP1 # 50-029-20485 6. LEASE DESIGNATION AND SERIAL NO ADL 28284 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9 WELL NO. H-11 (22-21-11-13) 10 FIELD AND IW3OL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pc~ 11 SEC., T , IL, M , (BOTTOM HOLE OBJECTIVE) Sec. 21, TllN, R13E, UPM 14. BOND INFORMATION ~E Blanket Surety and/o, No. Amaerican Insurance Co. 3348616 Amount $500,000,00 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST 18 30 ' east of PROPERTY OR LEASE LINE, FT. (Also to nearest dng, umt, ffany) ADL 28283 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 2388' south of Well H-2 16 No OF ACRES IN LEASE 2560 19 PROmSED DEPTH 9940 'MD 9490 'TVD 21 ELEVATIONS (Show whether DF, RT, CR, etc ) Est. KBE = 75' AMSL 23 PROPOSED CASING AND CEMENTING PROGRAM 17. NO.ACRES ASSIGNED TO THIS WELL 160 20 ROTARY OR CABLE TOOLS 22 APPROX DATE WORK WILL START August 5, 1980 sIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE MD SETTING DEPTHTV~ Quantity of cement 36" 20"x30" Insulated Coz ductor 110' 110 8 cu.yds, concrete 17%" 13 3/8" 72# L-80 2670' 2670 3250 cu. ft. Arctics~t II 12%" 9 5/8" 47% L-80 8960' .856_0 ]230 cu. ft. C] as'sG :130 cu. ft.Arc~_i 8½" 7" 299 L-80 9940' 9490 280 cu. ft. Cla.~.~ G w/1a~ .~al~ ~c~icset I See attached proposed drilling program outline. EFW: j a ~ depths. G_we blowout preventeI program. 24. I hereb~l~~~G~l~~ SIGNED: %o H.,,i~_-]-~_~ -- h DATE _~__~ fl]us ~psce for State office use) . %% C~)NDITIONS OF APPROV/LL, IF ANY- SABLES AND CORE C~S R~QUIR~D I MUD LO~ OTHER REQLURE~NTS [] YES ~O I U ~ES ~O DIR~IONAL SURLY REQUIRED ~P.I ~E~CAL CODE IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal ,s to deepen g~ve data on present producUve zone and proposed new producUve zone. If proposal m to drill or deepen duect~onally, g~ve pertinent data on subsurface locations and measured and true District TITLE Drilling Engineer June 20, 1980 PERMIT NO. (~- ~:)<:~ APPROVAL DATE ~VEDBY / ~ ~, ~ ~ ,~TLE -- - . / ___/ *See Instruction On Reverse Side BY ORD~ OF T~ CO~MISSION DATE 06/20/80 PROPOSED DRILLING & CCMPLETION PROGRkM H-il Dry bucket 36" hole to 80' belc~ ground level and c~nent 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 725 L-80 Buttress casing to surface using 3250 cu. ft. Arcticset II cement. Blcwout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVD. DirectioD~lly drill 12 1/4" hole to 8580' TVD. Run 9 5/8" 475 L-80 Buttress casing to 8560' TVD and cement first stage with 1230 cu. ft. cement. Cement second stage through D.V. packer collar at 2600'_+ With 130 cu. ft. Arcticset I cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9490' TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 280 cu. ft. Class G ce_we_nt with 18% salt. Run 4 1/2" 12.69 tubing with 5 gas lift mandrels and a production oacker assembly at 8070 '-+ TVD. A subsurface safety valve with dual control lines will be placed at 2000'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. GK: ja B.O.P~" STACK CONFIGUF~&TION 15 5/8" TRIPLE RAM STACK - 5000 PSI WP DRILLING ! ANNULAR PREVENTER .( L Z"' KILL LINE · -' HAND HAND CHECK GATE GATE -o J 1 I ], PIPE ~'~, M $ I ! BLIND RAMS ! I SPOOL · . -I I PIPE RAMS I 4' CHOKE LINE HAND GATE HYDR. ASST. GATE ::: il:. 2: O2 03 40 04 15 - ' O2 O3 O4 H-9 LAT 70° 17'40 74'* LONG 148°50'2! 57" X-'~ 643,343 Y: 5~958,695 PAD DETAIL SCALE I"= --INNPORTION T. Ii N.,R.ISE: SCALE I"= I/P-MILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to practice land surveying tn the State of Alaska and that this plat represents (3 location survey of the wellpad shown (]nd the wells thereon. This survey was mode by me or under my supervision and ali dimensions and other details ore correct Bottom hole locations are furnished by others. Date Surveyor - ADDED PROPOSED BHL H-Ia, H-II, H-I2 (680~' SUDSEA) 6- IZ-80 LAB o . - ii ii i i i iii -, _ PAD "' H" EXTENSION Located in NE 1/4 PROTRACTED SEC Zl~ T. II N ~R 13E.UM!AT MER.,ALASKA Surveyed for SOHIO ALASKA PETROLEUM CO. - - Surveyed by E M. LINDSEY I~ ASSOC. LAND ~, HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Alaska Anchorage ~ CHECK LIST FOR NEW WELL PERMITS (tDmpany. Item Approve Date Yes (~ Fee ~K A-/F-Fo 1. Is the permit fee attached .......................................... ~<. No 2. Is well to be located in a defined pool ............................. ~ 3. Is a registered survey plat attached ................................ ~ (2) Loc. _2~f ~-/~/o 4. Is well located proper distance frcm property line .................. ~ 5. Is well located proper distance frcm other wells .................... g~ 6. Is sufficient undedicated acreage available in this pool ............ F~0K 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... (3) ~imin. ~~ ~-/F-.f~ 10. Does operator have a bond in force .................................. ~K .., 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to _%'DOO psig . Approval R~c~ded: Additional Requirements: _Geology: Engineering: JAL rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically .. organize this category of information. ******************************* * AbASKA CO~PU~ING C,EN~ER * ****************************** COMPANY NAME ~ ~P EXPhORATION REFERENCE NO LIS Tape Verification Listing $chlumeerqer AlasKa ComputLng Center SERV/CE NA~£ ~ EDIT DATE { 89/04/ 4 ORIGIN :FLIC CONTINUA?ION # { PREVIOUS REEL : COMMENT I BP EXPLORATION,PRUDHOg BAY,B-!: (22-21.11-13),50.0.29.20485 **** TAPE HEADER SERVICE NAME : EDIT DATE : 89/04/ 4 ORIGIN : TAPE NAME : 73252 CONTINUATION ~ : ! PREVIOUS TAPE : COMMENT : BP EXPDORATION,PRUDHOE ~A¥,H.i! (22-21-11-13),50-029-20485 FILE NAME : EDIT .001 EERVIC~ : FDIC VERSION I 001A02 DATE I 89/04/ 4 MAX EEC SIZE { 1096 DAST FIDE PAGEi COMPANY NAMEI BP EXPLORATION WELL~ H-11 (22-21-11-13} FIELD{ PRUDHOE BAY BOROUGH~ NORTH 8DOPE STATEI ALASKA AP1 NUMBER{ 5002920485 LOCATION{ 1266 WED & 1873 8NL SECTION: 21 TOWNSHIP: PERMANENT DATUM{ HSD LOG MEASURED FROM RKR 76,5 EbEVAT '' ION. ABOVE PERMANENT D~TUM LIS Tape verification Listing Schlumberger AlasKa Computing Center PAGE~ DATE LOGGED~ TD DRILLER: TD LOGGER: CASING 1 CASING 2~ CASING 3~ K8~ 76,5 DF: 75,5 Gbl 47,29999 29-MAR'89 98?3, 9702, 13 3/8" 72 LB g BOTTOM D~PTH OF 2696 AND TOP DEPTH OF 0 9 5/8" 47 bBe BOTTOM DEPTH OF ,8942 AND TOP DEPTH OF 0 7" 29 LB ~ BOTTOM DEPTH OF 9873 AND TOP DEPTH OF 7255 BIT SIZE 2~ 12 1/4" BIT SIZE 3: 8 TTME [JOGGER ON BOTTOM: 12:20 29-MAR-89 MAXIMUM TEMP PECORDED~ 200, bOGGING DISTRICT: LOGGING ENGINEER: WITNESS~ TOOL NUMBERS: ATM-AA 160 CNC-DA 160 CAL-UB 597 4615 J,HUSBAND R,BLACKWOOD NSR b 3!37 ATC-CB 524 FIELD REMARKS: TIED-IN TO SWS ~ 980 ~ELL SHUT-IN 21:0 SHUT-ZN WELLHEAD PRESSURE [400 RUN O. LI.ES?O E STATUS DATE JOB STARTED: 3-APR-89 JOB REFERENCE NO: 73252 LDP/ANAI R, SlNES FILE ' EDIT,O0! BP EXPLORATION PRUDHOE BAY H-Ii (22-21-11-13) 50-029-20485 DATA SAMPLED EVERY -,5000 FEET TOOLS INCLUDED CNT-D (HLAt CNT-D IPS! CN?-D LIS Tape Verification Listing Schlumberger AlasKa Computing Center 4-A~R'~]989 ~2:49 , CNT-D CPS3 CNT'D (PS4 PAGE: 3 TABLE TYPE ~ CONS TUN! VAbU DEF! CN BP EXPbORiRTION Company Name Fle~d Name Well Name FN WN NATI STAT COUN FL sEC? TOWN RANG LRTI bONG ENGI SON ~PIN PRUDHO~ B~Y H-il (22~2i-tt-13) USA AbASKA_ NORT~ ~bO~E 1266 WEb ~ 1873 SNb J.HUSBAND 73252 5002920485 Nation State or Province gunty1eld bocatlon ectlon ow~shtp Range ba"t~tude bongitgde Engfneer's Name $,,e~vice O~der Number AP! Serial Number TABLE TYPE ; CURV DEPT NPH! NPH! NRAT NCNb FCNL RNRA GR TE:N$ NPH! NCNL FCNL RNRA GR NPH! NRAT NCNb DEF! DEPTH CHANNEb NAME NEUTRON POROSITY NEUTRON POROSITY Neutron Ratio (ND/FD) ~ Near CNb Detector Counts Far CNb Detector Counts Raw Neutron Ratio (Near/Far) Gamma Ray Tension POROSITY Neutron Ratio (ND/FD) Near CNL Detector Counts Far CNb Detector Counts Raw Neutron Ratio (Near/Fat) Gamma Ray Tenslon CCh Am NEUTRO~ POROSITY Neutron Rs~io (ND/FD) Hear CNL Detector Counts LIS Tape Verification [,lstlnq Schlumberqer AlasKa Computlnq Center 4-APR-~1959 12:49 DEFI FCNL Far CNL Detector Counts RNRA Raw Neutron Ratio (Near/Far) GR Gamma Ray TENS Tension CCh CCL Amplitude NPH! NEUTRON POROSITY NRAT Neutron Ratio (ND/FD) NCNL Near CNb Detector Counts FCNI, Far CNL Detector Counts RNRA Raw Neutron Ratio CNear/Far) G~ Gamma TENS Tension CCh CCL Amplitude PAGEt DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** mmmmm~mmmmmmmmmmMmmmmNmM~m~mN TYPE R~PR CODE VALUE 1 66 0 2 66 3 73 4 66 1 5 66 6 73 7 65 9 65 I 66 B I~ 68 66 0 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN m, -.. m.. AP1 API AP! FILE~NUMB NUMB SIZE REPR PROCESS E S~ ORDER # LOG TYPE CLASS NOD NUMB~& ELEM CODE (HEX) ...~ .~ p. ~4~,ooooo ooo i ~ i ~ ~ ~'ooooooooo ..~..~,,,,,~, ooooo ooo i ?ii ,'~ ooooo'°°°°°~o° NCNb P$1 CPS 347161 O0 000 O0 0 1 FCNL PS1 CPS 347161 O0 000 O0 0 t i i 44 68 680~000000 00000 LIS Tape verification blsttnq $chiumeerger AlasKa Computing Center 4-APR"ii989 I2:49 PAGEI NAME SERV [INIT SERVICE API AP1 APl API F!b~ NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB~SAMP ELEM CODE O0 000 O0 0 1 ! 1 4 68 0000000000 RNRA P$1 347161 GR P$1 GAP! 347161 O0 TENS PS! LB 347161 O0 CCh PSX 347161 O0 NPH! P82 PU 347161 O0 NRAT PS2 347161 O0 NCNb PS2 CPS 347161 O0 FCNL P$2 CPS 347161 O0 RNRA PS2 347161 00 GR PS2 GAP! 347161 O0 TENS P$2 LB 347161 O0 CCh PS2 347161 O0 NPH! PS3 PU 347161 O0 NRAT PS3 347161 O0 NCN[ P$3 CPS 347161 O0 FCNL PS3 CPS 347161 O0 ~RA PS3 347161 O0 GR PS3 GAP! 347161 O0 T~N8 PS3 LB 347161 O0 CCh P$3 347161 O0 NPH! PS4 PU 347161 O0 NRAT PS4 347161 O0 NCNL PS4 CPS 347161 O0 FCNL PS4 CPS 347161 00 RNR~ P$4 347161 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 1 ! 1 i 1 I 1 ! i 1 ! 1 1 ! I ~ ~ ooooooo ooooo.oo~ ~ ~ ooooo,ooooo 0000000'000 ~ ~ ~o, ooooo 000000 4 ~ 00000000~00 4 0000000000 000 000000 ~ ~ ooogoooooo 0000000 ~.oooooooooo { ~,oooooooooo , ~ oooooooooo , ~,oooooooooo ~ ~ oooo, o~ooo oo000ooo 68 0000000 ~ ~, ooooooo~g~ ~ ~ °°°°°°8~8~ 000000 ~ oooo, oooo oooooooogg 000000001~ cc~ ~2 ~~t oo ~o oo o ~ ~ ~ ~ 4 ~ oooooooooo ** DATA ** DEPT NCNb PS1 TENS P$1 NCNb PS2 TENS P$2 NCNb P$3 TENS P83 NCNL P$4 T~N$ DEPT, NCNb,PS1 TENS PS1 NCNb PS2 TENS PS2 NCNb PS3 TENS PS3 NCNb PS4 ~7 8 25O 9~9 000 '999 250 '999 250 '999 250 '999 250 '999 '999 2 0 '999 250 9700,000 2562,000 ~.ooo 24 ,000 1165~000 2352~000 1185.000 2326,000 NPHI HbA FCNb P$1 PS COb FCNE CCh COb P$3 FCNb P84 CCh PS4 NPHI HbA FCNb PS1 COb P8~ COb PS2 rCNL P$3 CCh PS3 FCNL PS4 23,047 NP,H~,P51 -999'250 '~ RNRA,P$1 :~,~o .p.~..~ ;2"50~ RNRA~p:$2 :999,250 NP,HI,,P~3 999,250 ~: RN'RA;'P83 999;2~0 NPHI,P$4 999,250 > RNRA;P84 999,250 ~ 22,559 NP~Z.P$! 608,500 RNRA,PS~ 57~,999 NPHI.;P~2 ,~UO ~NRA,PS2 55~,00 NPHI,PS3 50~ RNRA;P$3 , PS 0'000 NPHI,ps~ 581,500 RNR~, '99 GR,PS~ ,250 :999,250 NRAT,PS4 999;'{50 G:R.P$4 23.584 NRAT 4,207 OR 23.438 NRAT 4.:332' OR 22,65b NRA~ 4.230 OR 19,482 NRAT 4,00'0 OR ,999,250 :'999.250 °999,250 LIS ?ape verification Llsttnq $chlumberqer AlasKa Computtnq Center TENS.PS4 1155.000 CCL,PS4 DEPT. NCNb,PS1 TENS,PS1 NCNb,PS2 TENS.PS2 NCNL,PS3 TENS.PS3 NCNb,PS4 TENS,PS4 DEPT NCNL TENS NCNb P$2 TENS PS2 NCNb TENS NCNb P$4 TFN$ P$4 DEPT NCNb P$1 TENS PSI NCNB TENS PS NCNB PS3 TEN P 3 NCN~ $ P$4 TENS PS4 DEPT NCNB PSI TENS PS NCNb TEN8 PS NCNb P$3 TENS PS3 NCNb PS4 TENS PS4 DEPT NCNb P$1 TENS PS1 NCNB PS2 TEN8 PS2 NCNb P$3 TENS PS3 NCNB P84 TENS PS4 9600.000 2946,000 1160,000 2916,000 1155,000 3046 000 1180 000 2930 000 1170 000 9500 000 3074 000 1110 000 3042 000 1155 000 3134 000 1145 000 3116 000 1160 000 9400 000 2980 000 1130 000 3038 000 1155 000 3038 000 1130 000 3024 000 !165 000 9300,000 3900,000 1145,000 3566 000 1100 000 3496 000 1150 000 3362 000 1130 000 9200 000 4272 000 1090 000 4200 000 1090 000 4 76 000 1~10 000 4180 000 li35 000 NPHI,HbA CC PSi FCNb,P$2 CCh,PS2 FCNbeP$3 CCLePS3 FCNb. P$4 CCh,PS4 NPHI.HLA FCNh.P$1 CCh,PS1 FCNL,P$ CCb,PS~ FCNh. P$3 CCh,PS3 FCNb.PS4 CCh,PS4 NPHI,HbA FCNL,PSI CCh,PS1 FCNb,PS2 CCh,PS2 FCNh,P$3 CCh,PS3 FCNb,P$4 CCh,PS4 NPHI,HLA FCNb,P$ CCb,PSl FCNbeP$2 CCh,PS2 FCNh,PS3 CCh. PS3 FCNb,P$4 CCL,PS4 NPHI,HbA FCNb,PS1 CCL,PS1 FCNh,P$2 CCh,PS2 FCNb,P$3 CCL,P$3 FCNS,P$4 CC5.P84 4-APR"2989 12:49 0,000 22 168 ~ 656 500 0 000 641 000 0 000 ~ 721 000 0 000 694 000 0 000 NPHI,PSl RNRA,PS NPHi,PS~ RNRAeP$ NPHI,PS~ RNRA,PS3 NPHi,PS4 RNRA,PS4 20 313 NPHI,P$! 720 500 RNRA,PS{ 0 000 ~ NPHI;P$2 768 500 ~ RNRA, P$2 0 000 ~PHI,PS3 RNRA,PS3 NPHI,PS4 RNRA,PS4 767 0 756 0 00 00' 000 000 20 459 NPHI,P$1 5 000 !; RNRAePSI 700 000 NPHZ,P$2 RN:EA,PS2 NPHI,PS3 80O 0 0 O0~ pNRAeP83 RNRA,P$4 22 656 91~ 000 O00 ~ 85~ 000 o00 ~ 75~ 500 000 ~ 000 70~ 000 NPHZ,P$1 RNRA~PSI NPHZ'~P$2 RNRA. PS3 NPHI,P84 RNRA.P$4 22 1037 852 NPHI,P81 000 RNRA, P$ 200 ~. RNRA.~P 000 RNRA,P$4 000 22,217 NEAT,PS! 4,484 GE,pSi 2't;~'875 4,547 OR,PS2 2t,338 NEAT,P83 4,223 GB,PS3 21,875 NRA'T,PS4 4,219 OR,PS4 2t.777 NEAT,PS1 4,266 GR,P.Si 20,166 NRAT.PS2 20,}13 NRAT 2~,086 GE,PS3 ,605 NEAT,PS4 4,121 OR,PS4 21,289 NEAT,PS1 4,227 GE,PSi 18;994 NRA?,PS2 ;654 NRAT,PS 2t,039 GR,P&3 ;045 NRA?,P84 4,000 GE,PS4 22,1t9 NRAT.PSl 2~,273 GR,PS1 ~754 NEAT,PS2 PS' NRA?, ,~ub P84 4,754 OR,PS4 22,5!0 NEAT,PS1 17 NRA?,P$2 PS GE,PS4 PAGEI 4,578 19,422 4,53 18,70i 4,465 15,813 23,406 4,465 17,281 4,172 21,609 4 566 25 422 4 609 19 219 LIS Tape Verification Listing Schlumberger ALasKa Computing Center D~PT NCNb TENS NCNb TENS NCNL TFN$ NCNb T~N8 9100,000 PSi 6132,000 P81 1070,000 PS2 6132,000 PS2 1105,000 PS3 65~.000 PS3 10 .000 PS4 6252,000 P$4 1090,000 NPH! HLA FCNb PSI CCL FCNb PS2 CCh PS2 FCNL PS3 CCh PS3 FCNb P$4 CCL PS4 DEPT. NCNb T~N8 NCNb PS2 TENS PS2 NCNb PS3 NCNb P$4 TENS P84 9000,000 2340,000 1065.000 2514,000 1080,000 2618,000 1070,000 2530,000 1075,000 NPHI.HbA FCNb COb FCNL P$2 CCh PS2 FCNb P$3 CCh PS3 FCNb P$4 CCh PS4 DEPT NCNb T~N$ NCNb TENS NCNb NCNb TENS PS PS2 PS4 8900 000 2200 000 i085 000 2170 000 1095 000 1928 000 1065 000 2020e000 1080.000 NPHI,HbA FCNL,P$1 CCL,P81 FCNb P$2 CCh P$2 Nb F~Cb PS FCN5 CCL ps4 DEPT NCNL TENS NCNb TENS NCNb NCNb TENS PS2 8861 000 -999 250 -999 250 -999 50 -999 ~$0 -999,250 '999.250 2020,000 1060.000 NPHI HLA FCNb CCh PSi FCNb P$2 CCh PS2 FCNb PS3 CCh PS3 FCNb CCh PS4 END OF DATA ,*** FILE TRAILER **** FILE NAME : EDIT ,001 SERVICE I FbIC VERSION I 001A02 DATE 1 89/04/ 4 MAX REC S/ZE ~ 1096 FILE TYPE ~ LO 4-APR-"/989 12149 13,330 O, 00 o O, 2~56,000 0,000 48 584 O0 35~ 0O 368 ~50 0 00 58 O57 375 25~ 000 298 750 0 000 31~,500 ,000 288,500 0,000 -999 250 -999 -999 -999~ ' 256,590 0.000 NPH! NRAPS PH! PS~ RNRA PS2 ~P"I PS3 RNRA,PS3 NPHi'PS4 RNRA,P$4 NPHI,P81 RNRA,PSI NPHI,PS2 RNRA,PS2 NPHi;PS3 RNRA,.P$3 NPHi"P$4 RNRA,P$4 MPH!,PSI RNRA,PSI NPHI,PS2 RNRA,P$2 NPHI,PS3 RNRA,P63 NPHI.P84 RNRA, P$4 NPHI,P$! RNRA,PSI NPHi~P$2 NPHI,PS3 RNRA~P$3 NPHZ~PS4 ..... RNRAePS4 PAGE~ 7 10.596 NRAT.PS{ 2,600 GR,PBi 10;596 NRAT,PS2 2,896 GR,PS2 9~473 ~RiTLPS$ 2,730 GR;PS3 8,984 NRAT;P84 2,652 GR,PS4 3 O37 50,342 NRAT,PSi 068 ~RA~;PS2 293 NRAT;:PS3 4 291 NRAT,PS4 867 GR,P$4 7 59 082 ~RAT,PSl 5~ :750 GR,PS1 6i7 NRAT.PS2 7 262 GRIPS 49 805 NRAT,PS~ 207 GR,PS3 5! 367 NRAT,PS4 000 GR,P$4 8 203 4~;094 ,480 50,175 -999,250 MRA?,P$1 ~999,250 GR,PS~ -999,250 NRAT,P82 ,~8i3 NRAT,P$4 7,875 GR,PS4 -999 -99~ 250 LIS Tape verification Listing Schlumberger AlasKa Computing Center 4-APR-1989 12~49 PAGE~ **~* TAPE TRAILER **~* SERVICE NAMg I EDIT DATE : 89/04/ 4 ?Ap~ NAME : ?3252 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION,PRUDHOE BAY,H-11 (22-21-11-13),50-029-20485 SERVICE NAME : EDIT DATE : 89/04/ 4 ORIGIN I FbIC REEL NAME : 73252 CONTINUATION # : PREVIOUS REEL : COMMENT { BP EXPLORATION,PRUDHOE BA~,H-I~ (22'21-11-13),50-029-204~$ VERIFICATION LISTING LVP 010,hO1 Yk:RIFICATI[J~ LISTING AGE ** REEL HEADER ** SERVICE NAME =SERViC DATE :82/12/17 ORIGIN : REEL hAME :117927 CONTINUATION ~ 101 COMMENTS :LIBRARY TAPE ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/12/17 ORIGIN 16617 TAPE NA~E : CONTINUATION # PREVIOUS TAPE COMMENTS :LIBRARY TAME ** FILE HEADER FILE NAME SERVICE NA~E VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS U~IT Type CATE SIZE CODE CN : SOHIO ALASKA PETROLEUM CO, ~ ~' 000 000 026 w~ = H-l! 000 000 004 FN ~ PRUDHOE BAY ~! 000 000 012 RANG: 13E 000 000 004 TOWNI llN ~ gOO O00 &ECT{ 21 000 000 002 COUNI NORTH SbOP~ ~ OO OO 0,12 A AS A oo§ CTRY U $ OOO 0OO OOb 65 065 SCHLUMBERGER ALASKA COMPUTING bVP OIO,HO! VERIF1CATIOCJ L1STING PAGE COMPANY : SOHIO ALASKA PFTROLEUM COMPANY ~ELL ~ H'I1 FIELD = PRUDHOE BAY COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACCI 6~I72 RUN #1~ DATE LUGGED: 22oNOV-82 CASING = 13 3/8 IN, 269~' TO SURFACE CASING : 7 IN. 8 ! TO 9877' TUBING m 4,5~N 8433' TO SURFACE TYPE FLUID : 8RIN ~ Oib FbUID bEVEb a FUbb ~DP{ R, SINES -==============================================================================-- 6VP OIO.HO1 YE~IFIC~TION LISTING PAGE * SCHLUmbERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: * THERMAL DECAY TIME (TDT-M) , GAMMA RAY LOG CGR) , ** DATA FORMAT RECORO ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 8 4 73 6 9 4 0 I 66 0 DATUM SPECIFICATION RbOCK8 MNEM SERVICE SERVICE UNIT API API AP][ API FISE SIZE PROCESS SAMPLE REP:R' ID ORDER ~ LOG TYPE CLAS~ MOD NO, bEVEL CODE D~PT FT 0 0 0 0 0 4 0 ~ ~8 CU ' 68 $IG~ PSi 0 40 ! 0 FSIG PS1 0 0 0 0 TRAT PS1 0 42 1 0 GR PSI GAPI 0 31 32 0 BACK PS1 CPS O 0 0 0 FBAC PS1 CPS 0 0 0 O NTDT PSI CPS 0 0 0 0 FTDT PS1 CPS 0 0 0 0 $IG~ PS2 C~! 0 40 I 0 F$1G P$2 0 O 0 0 TRAT PS2 0 42 I 0 0 4 68 bVP OiO,HO1 VERIFICATlO~,I LISTING PAGE 4 GR P$2 GAPI BAC~ P$2 CPS FBAC P52 CPS NTDT P$2 CPM FTDT P52 CP6 SIGM PS3 CU FS1G PS3 TRAT P8~ GR PS3 GAPI BACK PS3 CPS FBAC P$3 CPS NTDT PS3 CPS FTDT PS3 CPS SlGM PS4 C~J rSXG PS4 ~RAT PS4 GR PS4 GAP! 8AC~ PS4 CPS FBAC PS4 CPS NTDT P$4 CPS FTD? PS4 CPS SIG~ P$5 CU F$IG P$5 TRAT PS5 GR PS5 GAP! BAC~ P$5 CPS FMAC PS5 CPS NTDT PSb CPS FTDT P$5 CPS 31 0 4O o 42 31 0 o 0 0 40 0 42 0 0 40 ,12 31 0 0 0 32 0 1 0 1 0 0 0 1 0 1 0 0 0 1 1 0 0 DATA DEPT GR FTDT GR FTOT GR FTOT GR FTDT GR FTDT 9839 0000 54 4~88 0 2'120 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999.2500 '999.2500 $IGM BACK MACK SIGM BACK SIGM BACK SIGM BACK 2100,0000 0,0000 =999,2500 "~99,2500 - 99,2500 -99~,~500 '99 .2500 '999,2500 -999.2500 -999.2500 DEPT FTDT GR FTDT GR FTDT FTDT 9800,0000 125,1875 70.b87b 110,4375 71,~OUO 140,1250 SIG~ BaCK SIG~ SIG~ MACK $1GM ~ACK SIG~ 62,6250 ~ 25 61 O, 63 60, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FSIG FSAC FSIG FFFsAC FBAC FSIG FSAC.. FSIC, 0 0 ~ 4 4 4 4 4 . 4 4 4 4 4 4 4 4 83~4,0000 .'9~ '6260 ,2500 -'9:$9,:2500 -999,2500 '999;2500 ~99!9.2500 '999;25'00 -9~9e2500 51,71'88 $2;'2! 87 46:88 4688 TRAT ~f~ T~T T~ T N,TDT TRAT TRAT TRAT 2,4102 ~999, -999,2500 -999.2500 -999,250~ 4,6445 2~0,25~!0 4,7031 04844 20~,0:2:50 .5664 .703i bVP 010,HOI VENIF1CATIOa GR 70,3125 BACK FTDT 137,b2bO DEPT 9700,0000 FTOT 05,0000 FTDT 65,4814 GR 32,b4U4 FTDT 71.7910 GR 35,~750 FTDT 70.'15U0 GR 36,4844 FTDT 70,O469 5IG~ MACK MACK SIGn ~ACK 5IG~ BACK BACK BACK $IG~ OAC~ BACK 8ACK 6IG~ BACK DEPT 9bO0,O000 GR 9,0625 FTDT 71,$7b0 GR 19,b777 FTDT 58,312b GR 2~,~437 FTDT 71.937~ GR 28,0000 FTDT 7b,7051 GR 28,bO94 FTDT 80,4379 DEPT 9500 GR 14 FTDT 85 OR 22 FTDT 72 GR 28 FTDT 84 GR 28 FTDT 80 OR 34 FTDT 87 0000 ~1328 .bb25 ,2607 ,3125 2344 0000 9727 7500 71~8 2500 $tG~ BACK BACK SIG~ BACK SIG~ BACK MACK DgPT 9400 GR 15 FTDT 73 GR 24 FTDT 74 GR 27 FTDT 72 GR 34 FTD2 63 GR 40 FTDT 56 .0000 .0391 .1250 ,OO00 343~ 40~3 b855 4863 4297 ,0420 ,632~ SIG~ BACK BACK BACK SIG~ BACK BACK DEPT 9300 GR 31 FTDT 89 ,0000 .Oj13 .1875 SIGM BACK 85.9375 18,2031 59,8125 18.1631 82 2~5 85,1250 1~.3281 85,~75 17. 58 78,6246 17.0781 71,5000 16.~562 85,9219 16,7o31 85 ~875 16i4727 83 125 16 ~719 83.1875 17,9375 77,1250 18.3623 89,0=625 18.3281 18 84 500 18 359~ 87 2500 17.8281 81,5625 17.3608 85 25 18 19 79,9766 18,1719 :oooo ! 2969 FBAC r$1G FBAC FSIG F~AC FSIG F~AC FSiG FBAC FSiG FSAC F$IG 8,AC FBAC FBAC F$iG FMAC FSIG FBAC FSiG F-BAC FSIG FeAC F$IG F:BAC FBAC FSIG F~AC F$IG FBAC FSlG FBAC ~4,7813 16.1562 i6.0410 .4688 i5'1841 3:9.1211 i4.6484 ~.75oo ;5492 .0391 ~O,5'625 't4'9775 ~7,9:687 ~!i5..5547 ~ 5.~ ~ 7'$0'i07266 ~:~, 0'b25062.5 ,{5 ~ 68 7:'5 ~?.0~56 14.8984 !5;2896 15;3896 {9~6~914 14.4956 I5;163i ~5.6172 ;9062 NTDT TRAT N. TDT TRA T N~DT T~AT TDTRAT NTDT TRAT T~T RAT TDTRAT NTDT TRAT RAT TRAT TDT RAT mTDT TRAT NTD T TRAT TRAT NTDT TRAT PAGE 5 22&.b2~O 2.8730 b~.1875 .8904 ,820! , 2, 09 7:~.~$89 2 6953 8~b25 ,7220 6426 81.7500 2.b387 ;b964 ;640'6 2' .6797 2,5996 ,8i59 7~,1074 .77i5 9375 ? :737 7~,3252' .6677 63,b875 2.5781 84, ~950 2~' . 6406 bvP GR FTDT GR FTDT GR FTVT FTDT DgPT GR FTDT FTDT FTDT FTDT FTDT DEP~ FTDT GR FTDT GR FTDT GR FTDT GR FTDT DLPT FTDT GR FTDT FTDT FTDT FTDT OEP2 GR FTDT FTDT FTDT FTDT OIO,HO1 VER]FICATiUN 42.0313 BACK 87.3125 45 4688 BACK 84~'1500 55.3438 BACK 90,5000 56,4844 BACK 92 1 1 1 1 00 0000 5IGM 19:b563 BACK 0U 0625 SIGM 29:6094 BACK 11,37b0 SIGn 33,9687 BACK 22.4453 $IGM 43.5938 BACK 94 7500 $IG~. 44:7813 BACK 19,12~0 91 1 1 1 1 1 1 1 O0 9~ 00 08 17 11 93 19 04 27 95 .0o00 $IG~ 3750 BACK 3125 SIGn 1250 BACK 9375 $lG~ ~062 BACK 9375 SIG~ 0&25 BACK 7500 SIG~ b250 BACK 09~ 9000 72 90 84 107 87 95 102 118 100 99 ,o000 $IGM .b8'15 BACK ,0625 $IGa ,b875 BACK ,4375 8IG~ 14Ib BACK '73~4 , .I250 BACK .bO00 ,b172 BACK ,~12b 8900 79 4b 98 53 94 71 82 ,0000 ,~gJ~ BAC~ .3125 .9062 BACK .2813 ,9375 BACK .5625 SIG~ 5000 ~ACK '9922 $IGM LISTING 91,6250 17.7500 84,5000 19.0625 89,2500 17,8906 87.0625 21 0938 90 6250 19 8125 85 6250 20 5bi5 899531 ~9.8906 89,8125 17.~594 91 56 17, !0 97,7656 18,1875 95, 90,6563 38.5313 ,7500 38. 101,2';!I9 3~o9912 89,9~75 38o~481 92.2402 38.6563 90,0000 38,5322 38,4063 89,5000 39,0879 88. 02 39.U171 FSIG rBAC rsi~ FBAC F~AC FSIG FB~C F$iG FBA¢ FSiG 8AC FBAC FSIG FBhC FSIG FBAC F$IG FBAC FSiG 8AC FBAC FSiG FFBAC S~(; F$IG F$IG FBAC F~AC FSIG F~A:C FSiG ~0'0625 ' 09 38 ,9297 · 14781'3 i5.000o i8,6875 S5 I3 17: goo :37,:7500 i. 7,8009 ~7,7578 ,~ 2' ¢68.8 18,5i5o ~3,781:3 i4 1797 $2 $625 14 734'4 $2,1562 39. 1250 38,6875 48,3125 37,797! ::I;~.0~:1 ~ · 2148 :;~.4:, 3945 38~7637 ~9,9~61 ~8,1562 40,4238 39~ 7:I 88 3~'77 , O0 TRAT ~AT TD'T ~TDT TRAT NT'DT TRAT TDT RAT TDT ~AT TDT NTDT TRAT RAT TDTRAT NTDT TART 'TVT ~AT NTDT TRAT .TDT ~AT ~:TDT T~A T TRAT ~ ' TRAT TRAT DT T'RA T NTD:T, TRAT PAGE 83,3! 25 2 5430 7'8 5000 2~ 5195 82~5547 7500 S4 3750 3.5098 12~:25002422 6;8 75' 4512 3e, 5000 1 9590 729 :b875 0410 ~ 0000 i 9365 74 10t'6:' ~ O170 ~ 5000 1290 8~, 3750 5,6211 .t 7 4, b2 bO 5,4102 , ~750 5825 5~5994 187,562:b 5,9453 15~,00~i0 '5352 i445 18~,0000 '0018 16~,843'7 ;1606 L~"~ I"I I l I l i iiI;..] 1! [ :-.] i bVP OIO.H01 VERIFICATION LISTING GR FTDT 70.3750 BACK 99.0547 93.b094 FBAC DEPT GR FTDT GR FTDT FTDT FTDT FTDT 8893.0000 36.8750 BACK 94.3'150 SIGM -999,2500 BACK -999.2b00 5IGM '999.2500 BACK -999.2500 SIGn -999,2500 BACK -999.2500 SIGM '999,2500 BACK '999,2500 38,0313 FSIG 85,5000 FBAC -999,2500 ¥SIG '999,2500 FBAC -999.2500 FSIG -999,2500 FBAC -999,2500 FSIG '999.2500 FBAC "999.2500 FSIG '999.2500 FBAC ** FILE TRAILER ** FILE NAME ISERVIC.O01 SERVICE NAME 5 VERSION # : DATE 5 MAXIMUM LENGTH = 1024 FILE TYPE 5 NEXT FILE NAME = EOF I§,0654 NTDT ~9. 1875 TRAT 999.25 TRAT .-999,2500 NTDT -999'2500 TRAT "9~9,2~'00 ~TVT -999.2500 T~AT -9:~9,2500 -999.2500 ?RAT -9~9,2500 NTDT PAGE 165,5981 6.0469 17b,0000 -999.2500 ~999,2500 -999.~500 -999~2500 -999,2500 ** TAPE TRAILER SERVICE NAM~ =SERVIC DATE 582/12/17 ORIGIN :6b17 TAPE NAME I CONTINUATION # NEXT TAPE NAME COMMENTS :LIBRARY TAPE ** REEL TRAILER SERVICE NAME 5$ERVlC DATE 182/12/17 ORIGIN : REEL NAME 1117927 CONTINUATION # 501 NEXT REEL NAME COMMENTS :LIBRAR~ TAPE L~ I~ 111iJl iI:4i[! [:4 ~ 11 000000 1 i 000000 1111 O0 O0 t I I 1 O0 O0 11 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 1l O0 O0 11 O0 O0 I I 111 I 000000 111111 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0o00 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777771777 7777177171 77 77 77 77 71 17 77 77 77 77 77 77 H-II (o,o . bbbbbb 11 bb6bo6 I1 66 1111 6~ 1111 be 11 b6 11 6666666b 11 ob bO 11 6b Ob 11 bO bb 11 ObOb66 1111 b6Obb6 1111 11 11 000000 000000 OO OO O0 OO O0 0000 O0 0000 O0 00 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 11 1l 1111 1111 11 11 11 11 11 11 11 11 111111 111111 44 44 44 44 44 44 44 44 q4 44 44 44 44~44~4444 44444~4444 44 44 44 44 44 44 M~ MM M M M M H M M d J JJJ d AAA PPPP RRRR d A A P P R R d A A P P R ~ d A A ..... PPPP RRRS J AAAAA P R R J A A P R R A A P E R U O DDDD U [} D D U U D D U U D D U O D D U U D D UUUO£{ DDDD H H DO0 ~LELE H H U 0 L H H O 0 E H~RHH O 0 LLEE H H 0 0 L u H u 0 L M H oD0 ~EEEE *START* MONITOR *STAIR'I'* MiJN i TfIR USER PCAL [10707,b1014J JOB SWS ~LIOL40 SEP--80. *START* USER PCAL [10107,b1014{ 5wS KLIOE40 SEP-80. *START* SHiP SEO. ~122 DATE SfllP SRO. {122 DATE 2I-uCT-80 21-0CT-80 12:0b:17 12:0b:17 SS HH HH $SS$SS HHHHHHHHHH $SSS$S HHHHHHHHHh SS HB HH SSSSSSSS HH HH SSSSSSSS HH HH lllI llll 1I 11 I1 II 1i 11 11 ii Illl Iii1 Ll II 1[ PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTT1 UOt)UOO TTTTTTTT'I i I'T U[J OO T T (j {J O tJ IT LiD {JO 'rT O0 UU TT flu U(J T I' ()tJ OL) T ~ {j [j (J U rr OO OO ~l ~ UO oD TT tit) T'r O(JUUUU PT ,START* USER PCAL [10707,01014] dUB SHIP SEO. 3122 MONITOR SWS ~hlO~40 SEP-8O. ,START* ~lb~: DS~:SHiP.'£u<2~5>t~O707.blO14J CREATED: 21-OCT-80 PRINTED: 21 OCT 80 12:06:39 OU~,U~, SWlICHkS: /~ILk:FORT /CUPIES:I DATE 21-OCT-80 12:06:17 11:30:13 SHiP T~ PCCC 6HIPPING INSTRUCFIUN6 t~bOkD 21-UCT-80 11:29 CALIF OBN IA MJA PCCC VV V'¥ VV VV VV VV VV V¥ Vv VV VV VV VV VV vV VV E~ HR RR VV EL R~ R~ VV ~E ~H ~ VV EEEEEEhL RRRRRRR~ VV EE HH RR VV E~ HH RR IIiiii 1iiiii II ii I1 I1 I1 II I1 11 1i i1 1iiiii 1i1III F~ YY YY YY ~Y Y~ 000000 000000 44 44 000000 000000 44 44 O0 O0 O0 O0 44 44 O0 O0 O0 O0 44 44 O0 OOOO O0 0000 44 44 O0 0000 O0 0000 44 44 O0 O0 O0 O0 O0 O0 4444444444 O0 O0 O0 O0 O0 O0 4444444444 0000 O0 0000 O0 44 0000 O0 0000 O0 44 O0 O0 O0 O0 44 O0 O0 O0 O0 44 000000 000000 44 000000 000000 44 ,STAR1'* USER PCAL [10707,o1014J jOl~ SHIP SE(J, MONITOR Sw6 KLIOE40 SEP-BO. ,START* fll,k: DSKM:VERif~.004<057>[I0707 61014] CREATED: PRINTED: 21-OCT-80 12:0~:52 OUI.,.UE SWITCHES: /f'ILE:fURT /COP1ES:I /SPACING:I /LIMIT:130 /f'URMS:NORMAi, 4122 DATE 21-UCT-80 21-OCT-80 12:02:33 12:0b:17 l, IS VERSIO~ 15.H01 7910112(:, SCHLUMBERGER COMPUTING C~NTkR 10707,61014 PEEl, I, ENGTH: 1 ]2 REF, I, NAME: P.C.A.6. SFRV1CE NAME: ~DIT R~,EL C[~NTiNUArIUN NUMBER: PRkVIULJS R~,EL NANE: COMMENTS: 616 FORMAT COSTUMER TAPE DATE: 80/10121 TAPF, HEADER L~,NGIH: 192 BYTES TAPE NAME: blO14 DATE: 80110/21 SF, RViCk NAME: EDIT TAPE CONTINUATION NUMBER: 0! PREVIOUS TAPE NAME: CtJMMENT$: UNIQUE ~kbb IDENTIFICATION NUMBER IS 50-029-20485 ~APE CDMM~,NTS RUN ONE DATA 9-10-80 CSG 1]-5/8" ~ 2696' / BI°I 12-~/4" / ~bU1D LOW SOLID / DENS 9.~ VI~C ~8 / PM 9. / R~ 2.9~ 0 62 DF / RMF 2.~ ~ 62 DF / ~M 1.32 ~ 1~ 1~8 D~ BHT RUN 1'WU DAT~ CSG 13o~7 m 8942' / ~iT 8.5 / PLOID XC POL2H~R / DENS ~o6 / ViSC 41.00 / PH 10.0 / ~M ~o5 ~ 70 D~ / RHF 2.28 ~ bO D~ ~HT 192 BHt FILL HEADER LENGTH: b2 BYTE6 ~II, E NAME: EDIT .001 MAXIMUM PHYSICA~ RECORD LENGTH: PRF, VIUU~ FILE NAME: CUMPAN~ : SUHI[) ALASKA PETRO. wELl, : H- 11 f 1ELI) : PRUDHUIc, BAY HANGE : lie ]]OWNSH i F : 1 1 N SECTIfJN : 21 COUNTY : N. SLOPE STAlk : ALASKA DENSITY : 800. 1024 BYTES [~ATA ~UI~NAT SPI~CI~ICATION LENGI~t: 650 l~ ~ TiiS TYPE 0 S1Z~, R~P CUDk ENTRY 1 66 0 DATUM ,SPLCIF ICAT/ON ~bEICK6: NAML 'luUb UNiT API API AP1 AP1 FILE SIZE SAM ALP PRUCESS INDICATUR$ PT 0 0 0 0 0 4 M V 1 1 0 0 0 4 UHMM ? I 2 46 0 0 4 OH~ ? 12 44 0 0 4 [JHMN 7 22 8 0 0 4 GAPI 7 31 32 0 0 4 GAPt 60 31 32 0 0 4 US/~ 60 52 32 0 0 4 GAP[ ~2 31 J2 0 0 4 IN 42 28 I 0 0 4 G/t'3 42 44 0 0 0 4 PU ~2 68 2 0 0 4 G/C3 42 35 I 0 0 4 C/C q2 42 I 0 0 4 CPS 42 34 92 0 0 4 CPb 42 3~ 93 0 0 4 1 08 1 08 1 68 1 68 1 68 1 68 I 68 1 68 I 68 1 6~ 1 68 1 68 I ~8 1 68 U,SLP DEPINLD UtI~PU't AREAi OUTPIIF SB Al 2 OUTPUT 1LO AT 3 OtJTPtJT ILM A'[ q OUT['IIT I,LSU A'[ 5 OUTPUT GH AT 6 OUTFUT GR Al~ 7 []UTPUT D'I Al 8 OUTPUT G~ AT 9 OUTFdP CALl Aq 10 OUTF'UT DRHU AT 11 OUTPUT NPHi Al 12 OUT~UT RHUB A% 13 OUTPUT NFAT AT 14 OUT[~UT NCNL A'I~ 15 OIJTPIIT PCNL A'[ 16 DLPTH 9890.000 9BO0.O00 qTO0.O00 9600.000 9500.000 qqO0.O00 9300.000 9200.000 9100.000 9000.000 R900.000 MNLMUNIC SP GP CALl NHAT SP GR CAI,I NRAT SP GR CALl NHAI SP GR CALl N~AT SP GR CALl NRAT SP GR CALl NRAT SP GR CAb1 NPAT CALl NRAT SF GR CALl NRAT GR CALl NlRA 1' SP CALl NRAT VALUE -15.750 9;.125 8.500 2.551 -16.992 83.734 9.365 2.898 -83.010 30.957 8.832 2.330 -83.313 16.855 8.844 2.217 -81.938 25.988 8.900 2.172 -80.000 21.47] 8.871 2.184 -82.813 19.55q 8.912 2.332 -66.938 30.250 ~.895 2.367 -50.000 134.156 9.398 1.294 -25.063 112.250 10.584 3.502 -59.914 49.992 9.510 3.961 MN LMUN lC ILD GR DRHU NCNb ILD GR DRHD NCNb ILD GR DRHU NCNL lbD GR DRHU NCNL lbo G~ DRHU NCNb IbD GR DHHU NCNb ILD GR DRHO NCNb ILD GR OHHO NCNb ILD GH DRHO NCNb ILD GR DRHU NCNb ILD GR DRHO NCNb VALUE 2.926 97.]25 0.130 2730.000 4.985 95.250 0.095 3138.000 2.890 34.156 0.044 3830.000 4.468 16.813 0.018 3878.000 2.883 25.656 0.O42 3932.000 3.933 21.500 0.012 3760.000 18.305 20.188 0.002 3268.000 20.621 29.813 0.056 3342.000 92.406 140.625 0.017 5984.O00 1.740 113.563 0.052 2029.000 1502.201 56.719 -0.O05 1569.000 MN EMUNIC DT NPH1 ~CN~ IbM DT NPHI IbM DT NPHI ~CNL 1bM i) T ~CNL ibm DT NPHI FCNb ILM DT NPHI ~CNb IbM DT NPH1 fCNL ibm DT NPHI ~CND ILM DT NPHI iLM U~ NPHI ~CNb UT NPHI VALUh 2.994 100.750 25.537 908.000 5.035 75.734 24.072 1033.000 3.221 84.563 19.128 1540.000 4.547 89.484 17.761 1558.000 3.184 83.578 16.650 1625.000 4.354 82.510 17.480 1506.000 13.889 96.328 19.U36 124o.000 18.395 U7.109 19.592 1313.000 94.406 00.195 2.722 4064.000 1.617 107.156 35.168 496.750 2000.000 63.773 41.492 324.000 MNLMONIC bbSU GR RMUB bbSU GR bbSU GR RHOB bbSO Gk RHUB bbSU GR bhSO GR RHUB 5580 GR RHUB LbSU GR RHUB bbSb GR bbSU GR RHUB bbSO GR VAbUL 3.719 I I I. 938 2.209 5.981 110.672 2.786 8.134 32.719 2.385 12.549 11.836 2.313 10.484 d3.852 2.394 11.521 24.695 2.292 19.520 21.785 2.298 24.094 21.074 2.438 190U.250 143.391 2.063 3.009 123.125 2.507 0.578 54.789 2.591 DkPTH 8800. 000 ~700.000 8eoo.ooo 8500.000 ~400.000 8]00,000 8200,000 ~ 1 O0. OOO 8000,000 7900°000 7~00.000 MNkMUNIC SP GR CALl NRAT GH CALl NRA'[' ~P GR CALl NRA£ SP GR CALl NRAT SP GR CALl NRA[' SP GR CALl NRAT SP GR CALl NRAT SP GR CALl SP (JR CALl NttAT 8P CALl N~AT SP G~ CALl N IR A 'r VAL UE -68.250 114.40o -999.250 -999.250 -14· 108. -999. -999. -16. 70. -999.-999. -21. 80. -999.-999. -17· 87. -999.-999. -17. 94. -999.-999. -17. qo. -999.-999. -20. 68. -999.-999. -20. 95. -999.-999. -21. Bb. -999.-999. -23. 89. -999.-999. 750 200 25(; 250 5O0 200 250 25O 000 800 250 25O 50O 80O 250 250 250 100 250 250 000 lO0 25O 250 750 700 250 250 250 000 25O 25O 000 500 250 250 000 000 250 25O MNkMONIC ILO GR DRHU NCNb GR NCNb tbD GR DRHU NCNL ILD t)RHO NCNb iLD GR DRHU NCNb GR ORH[] NCNb ILO GR DRHO NCNb ILD GR DRItO NCNb iLO GR DRHU NCNL GR DRHU NCNb GR DRHO NCNb VALU . -999. -999. -999. . -999. -999. -999. · -999. -999. -999. . -999. -999. -999. I · -999. -999. -999. I · -999. -999. -999· I · -999. -999. -999. 0 -999. -999. -999. I . -999. -999. -999. I · -999. -999. -999. · -999. -999. -999. 107 250 250 250 271 250 250 250 704 25O 250 250 270 250 250 250 282 250 250 250 ]55 250 25O 250 419 250 250 250 78O 25O 250 25O 038 250 250 250 107 250 250 250 247 250 250 250 MNkMUNIC ibm NPHI ~CNL ibm NPfll ~CND ibm Dr NPHI ~ CNL, DI NPHI fCNL IbM O[ NPHI PCNL UT mPdl IbM DT NPH£ ~CNL ibm DT NPHI ~CNL ibm OI NPHI [CNL IbM DT NPHi fCNb iLM DT NPHI PCNL VALU . -999. -999, -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. · -999. -999. -999. . -999. -999. -999. . -999· -999, -999· . -999. -999, -999. · -999. -999. -999. · -999. -999. -999. 250 250 250 318 250 250 250 25O 2bO 25O 462 250 25O 25O 3O5 25O 25O 25O 369 250 250 250 436 250 25O 250 998 250 25O 250 077 25O 250 25O O88 250 250 250 221 250 250 250 MNEMLJN IC LLSU RHOB bb~O RHOB bL8U G~ RHOB LL8U GR bbSU GR RHOB bLSO GR RHUB LL8U GR RHUB LbSU GR RHUB bbSU GR RHOB bbSO GR RHUB bbSU GR RHOB VAbUk 2,159 -9N9.250 -999.250 2.270 -999.250 -999.250 3.57] -999.250 -999.250 ].898 -999.250 -999.250 2.214 -999.250 -999.250 2.328 -999.250 -999.250 1.844 -999.250 -999.250 4.108 -999,250 -999.250 1.Sb0 -999.250 -999.250 1.714 -999.250 -999·250 1.938 -999.250 -999·250 DkP'IH 7700,000 7600.000 7500,000 7400.000 7i00.000 7200.000 7 1 o0. 000 7000.000 6900.000 6800. 000 ~700.000 MN EMUN IC SF GR CALl NRAT SP GR CAL.{ NRAT SP CALl NRAT SP G[~ CALl NRAT Gl-{ CALl NRAT SP GR CALl NRAT SP GR CALl NRAT 8P GH CALl NRAT 8P GR CALl NRAT SP GR CALl NRAT $P G~ CALl NRAT VALUE -26.500 9~.8OO -9q9.250-999.250 -JO.O00 105.30u -999.250 -999.250 -27.75O 211.200 -999.250 -999.250 -33.500 164.400 -999.250 -999.250 -25.500 123,700 -999.250 -999.250 -17.750 12b.300 -999.250 -999.250 -22.000 173.200 -999.250 -999.250 -22.500 198.200 -999.25¢) -999.250 -30.250 85.4OO -999.250-999.250 -29.250 82.300 -999.250-999.250 -20.500 9].900 -999.250-999.250 MN EMONIC IL0 GP DRHU NCNb ILD DRH{~ NCNb GR ORliO NCNL GR DRHO NCNL ILD GR DRHO NCNL 1 bD GR DRHO NCNb iLO GR DRHO NCNL ILD GR DRHO NCNb ILD GR NCNL ILD DRHO NCNb ILD GR DRHO NCNL VALIIE 1.472 -999.250 -999.250 -999.250 1.738 -999.250 -999.250 -999.250 2.208 -999.250 -999.250 -999.250 2.270 -999.250 -999.250 -999.250 2.512 -999.250 -999.250 -999.250 1.754 -999,250 -999.250 -999.250 1.117 -999.250 -999.250 -999.250 1.854 -999.250 -999.250 -999.250 1.472 -999.250 -999.250 -999.250 1.556 -999.250 -999.250 -999.250 2.070 -999.250 -999.250 -999.250 MNi~MtlN lC IbM NPHI laCmL ILM DT NPhl fCN6 ibm UT NPHI fCNL ibm NPH1 fCN6 ILM DT NPHI FCNL ILM DT NPHI IbM DT NPHI fCN6 ibm O~ NPHI ~CNL IbM NPHI fCNb 1bM DT NPH1 ~CNb AbM Ol NPHI ~CNL VAL, UE 1,492 ,,999.250 -999.250 -999.250 1.136 -999.250 -999.250 -999.250 2.158 -999.250 -999.250 -999.250 2.199 -999.250 -999.250 -999.250 2.580 -999.250 -999.250 -999.250 1.187 -999.250 -999.250 -999.250 1.1~1 -999.250 -999.250 -999.250 1.964 -999.250 -999.250 -999.250 1.464 -999.250 -999.250 -999.250 1.579 -999.250 -999.250 -999.250 2.078 -999.250 -999.250 -999.250 MNEMUNIC 668U RHO8 LbSW GR 668U GR R, HUB 6680 GR 668U GR RHOB 6680 GR RMO~ L68U GR RHOB 668U GR RHOB LbSU GR LbSb GR 6680 GR RHOB VALU{~ -999.250 -999,250 2.410 -999.250 -999.250 3.270 -999.250 -999.250 3.392 -999.2b0 -999.250 5.352 -999.250 -999.250 2.830 -999.250 -999.250 2.141 -999.250 -999.250 ~.481 -999.250 -999.250 2.251 -999.250 -999.250 2.328 -999.250 -999.250 2.904 -999.250 -999.250 DEPTH 6600.000 6500. 000 64,00.000 6300.000 6200.000 6100.000 6000. 000 5900.OO0 5800.O00 5700.000 5600.000 CALl NRAI' .P G~ CAI.,i NHAr 8P GR CALl NRAI .P GR CALl NMAT SP GR CALl NEAT SP GR CALI NHAT SP CALl NRA3 SP NHAT SP GH CALl N~AT SP GH CAI, I NHAT SP CALl NEAT VAL -28 85 -999-999 -]4. 82. -999.-999. -55. ~2. -999.-9gq. -37. 10~. -999. -999. -3]. 88. -999.-999. -]?. 83. -999.-999. -]7. 85. -999.-999. 57. -999. -999. -69. 60. -999.-999. -58. 76. -999.-999. -57. 62. -999.-999. UE .000 .000 .250 .250 75O 600 250 250 000 9O0 250 250 750 5O0 25O 250 25O 50O 25O 25O 75O 000 25O 250 5O0 000 250 25O 500 300 250 250 750 500 250 250 250 300 250 250 000 200 25O 250 MNLMONiC iLD GR DRHU NCNb ILD GH DHHU NCNb ILD GR DRHU NCNb ILD GR DHHU NCNb ILD DHHU NCNb iLD DP, HO NCNb ILD GE DRHO NC NL IbD GR DRHU NCNb ILD GE DHHLJ NCNb II,D DRHO NCNb ILD GH DRHU NCNb VALU · -999. -999. -999. · -999. -999. -999. 12. -999. -999. -999. 0 -999. -999. -999. · -999. -999. -999. . -9q9. -999. -999. . -999. -999. -999. I -999· -999 o -999. · -999. -999. -999. -999. -999. -999. . -999. -999. -999. 489 25O 25O 250 152 250 250 250 942 250 250 250 018 250 250 250 018 25O 250 25O O55 250 250 250 O76 25O 25O 250 ~199 25O 25O 250 250 25O 250 O76 25O 250 250 467 25O 25O 25O MNLMONIC ILM DI NPHI ~CNL ILM D~ NPHI ~CNL DT NPHi FCN6 ILM DT NPHI fCNb ILM NPHI fCN6 1LM DT NPMI ~CNb DI~ NPHI f CNb DT NPHI fCNL ibm DT NPHI ~CNL iLM DT NPHI fCN6 DT NPH1 ~CN6 VA6U 0 -999. -999· -999. . -999, -999. -999. 13. -999. -999. -999. . -999. -999. -999. . -999. -999· -999. . -999. -999. -999. . -999. -999. -999. . -999. -999. -999. -999· -999. -999. . -999· -999. -999. · -999. -999· -999. 5O9 250 250 250 OO8 250 25O 250 255 250 250 250 858 250 250 250 931 250 250 250 895 250 250 250 942 250 25O 250 485 250 250 25O ~82 25O 250 250 942 250 250 250 292 25O 25O 250 MNLMUNIC 6680 G~ RHOB 6680 GR RHUB 6680 GR RHOB 6680 GR 6680 GR RHOB 6680 GR HH08 6680 RHUB 668U GR 6680 GR RHOB 6680 GR RHOB 6680 GR RHUB VALUE 3.362 -999.250 -999.250 5.849 -999.250 -999.250 19./88 -999.250 -999.250 4.485 -999.250 -999.250 4.485 -999.250 -999.250 -999.250 -999.250 3.604 -999.250 -999.250 4.108 -999.250 -999.250 5.400 -999.250 -999.250 3.511 -999.250 -999.250 3.732 -999.250 -999.250 DEPTH 5500.000 5400.000 5300.000 5200.000 5100.000 5000,000 4900.000 ~800,000 4700.000 4600.000 4500.000 NNEMUNIC SP CALl NRAT SP GR CALl NRAT 6P GR CALk NRAT GR CALl NRAT SP GR CALl NRAT SP GR CALl NRAf SP OR CALl NRAT SP GR CALl N~AT SP CALl NRAT SP GR CALl NRAT SP GR CALl NRAT VALUE -95.750 46.000 -999.250-999.250 -92.000 59.200 -999.250-999.250 -116.000 4J.700 -999.250-999.250 -{0b.250 )5.800 -999.250-999.250 -52.500 40.800 -999.250-999.250 -60.500 40.200 -999.250-999.250 -25.000 06.700 -999.250-999.250 -45.250 56.000 -999.250-999.250 -/.OuO 75.900 -999.~50 -999.250 -12.500 79.200 -999.250-999.250 -11.250 q2.100 -999.250-999.250 MN EMI)NIC 1 LD GR DRHO NCNb 1Lb DRHU NCNb lbD GR DRHU NCNb iI,O GR DkHO NCNb ILD GR DRHU NCNL ILD GR ORHO NCNb GR DRHU NCNL, 1LO GR DRHU NCNb ILD GR DRH[J NCNb 1LO GR DRHO NCNb ILD GR DRHU NCNL VALUE 2.312 -999.250 -999.250 -999.250 1.803 -999.250 -999.250 -999.250 1.213 -999.250 -999.250 -999.250 1.330 -999.250 -999.250 -999.250 1.820 -999.250 -999.250 -999.250 1.500 -999.250 -999.250 -999.250 2.228 -999.250 -999.250 -999.250 2.466 -999.250 -999.250 -999.250 4.325 -999.250 -999.250 -999.250 3.908 -999.250 -999.250 -999.250 3.981 -999.250 -999.250 -999.250 MN ~MONIC ibm NPHI kCNb DT NPHI ~CNL IbM DT NPHI fCNb ILM DT NPHI PCN6 IbM DT NPHI PCNb DT NPHI PCNL IbM OT NPHi PCNL DT NPHI PCNb kLM DT NPHI ~CNU ILM DT NPH1 fCNL ILM DT NPH! kCNb VALUE 2.416 -999.250 -999.250 -999.250 2.020 -999.250 -999.250 -999.250 1.422 -999.250 -999.250 -999.250 1.492 -999.250 -999.250 -999.250 2.001 -999.250 -999.250 -999.250 1.594 -999.250 -999.250 -999.250 2.349 -999.250 -999.250 -999.250 2.485 -999.250 -999.250 -999.25O 4.043 -999.250 -999.250 -999.250 3.752 -999.250 -999.250 -999.250 3.752 -999.250 -999.250 -999.250 MNEMUNIC bbSU GR RHC)[5 LLSU GR bbSu GR RHOB LbSU GR LLSU RHUB LUSU GR bbSU GR bbSU RHOB bbSO GR bbSU GR RHOB bbSO GR RHOB VAbU~ 5.031 -999.250 -999.2b0 5.95~ -999.250 -999.250 b.0bl -999.250 -999.250 3.967 -999.250 -999.250 4.85~ -999.250 -999.250 3.898 -999.250 -999.250 3.932 -999.250 -999.250 a.b06 -999.250 -999.250 4.330 -999.250 -999.250 4.b0b -999.250 -999.250 4.606 -999.250 -999.250 D[sP'tH 4400.000 4 ~OU, O00 4200,000 4100,000 4000.000 {qo0. 000 3800.000 3700,000 ~bO0.O00 ~500.000 ~400.000 MNEMON lC SP CALl NRAr SP GR CALl SI-' GR CALl NRAr SP GR CALl NRAT SP GR CAI,i N~AI' 8P CALl NRAT SP GR CALl NRAI SP GR CALl NRAT SP GR CALl NRAI SP GR CALl NRAT SP GA CALl NRAT VAL -3O -999 -999 -65 ~3 -999-999 -67 29 -999-999 -19 -999 -999 -17 71 -999-99q -43 44 -999-999 -22 76 -q99-999 -6O -999 -999 -22 70 -999-999 58 -999 -q99 -47 56 -999-999 UE .250 .800 .250 .250 · 250 .200 .250 .250 .500 .SOO .250 .250 .000 .100 .250 .250 .250 · 6O0 .250 .25O .250 · 100 .250 .250 .000 .600 .250 · 25O .250 .700 .250 .250 .000 .lO0 .250 .250 .250 .200 .250 · 250 .500 .300 .250 .250 MN LMONIC ILD GR DRHO NCNb iL[3 GR NCNb iLD GR DRHO NCNb II, D (.,R DRHU NCNL ILO GR DRHO NCNb GR DRHO NCNb GR DRHL! NCNL ILD GR DRHO NCNL ILD GR ORHU NCNL ILD GR DRHU NCNL GR DRHO NCNb VAL 4 -999 -999 -999 2 -999 -999 -999 -999 -999 -999 6 -999 -999 -999 5 -999 -999 -999 4 -999 -999 -999 . -999. -999. -999. -999. -999. -999. . -999. -999. -999. -999 -999 -999 . -999. -999. -999. UL .J25 .250 .250 .25O . ~55 .250 .250 .250 .532 .250 .250 .250 .138 .250 .250 .250 .970 .250 .250 .250 .656 .250 .250 .250 855 250 250 250 966 250 25O 250 982 25O 250 25O O81 250 250 250 248 25O 250 25O MNLM{JN lC iLM i~PHI ~CNL ILM NPHI ~CNL NPHI fCNL DT NPHI bCNh DT NPMI FCNL ILM Ot bCN6 IbM UT NPHI ~CNL DT NPHI PCN6 DT NPH1 ~CNL IbM Ol NPHi D~ NPHI fCN6 VAb -999 -999 -999 2 -999 -999 -999 3 -999 -999 -999 5 -999 -999 -999 5 -999 -999 -999 4 -999 -999 -999 6 -999 -999 -999 5 -999 -999 -999 -999 -999 -999 -999 -999 -999 5 -999 -999 -999 U~ .~79 .250 .250 .250 .250 .250 .250 .787 .250 .250 .250 .806 .250 .250 .250 .496 .250 .Z50 ·250 .049 .250 .250 .250 .496 .250 .250 .250 .247 .250 .250 .250 .250 .250 .250 .260 .250 .250 .250 .345 .250 .250 .250 MNEMUN[C 6680 GR RHOB 6680 GR RHOS bhSO GR RHOB LhSU GR RHOB 6680 G~ RHUB L680 GR RHOB 658u GR WHUB 668u GR 6680 GR RHO~ 6b8U GR RHOB 6680 GR VAbdk 5.095 -999.250 -999.250 ~.791 -999.250 -999.250 1.247 -999.250 -999.250 7.378 -9~9.250 -999.~50 b.b27 -999.250 -999.250 b.226 -999.250 -999.250 1.318 -999.250 -999.250 1.927 -999.250 -999.250 7.378 -999.250 -999.250 8.441 -999.250 -99~.250 1.511 -999.250 -999.250 D k. P t300,000 3200.000 3100.000 )000.000 2900.000 2800,000 2700.000 2600,000 2580.000 MIImMUNIC SP CAI, 1 NPArl' SP GR CAhI SP CALl NRAT SP CAI, I NRA I' SP GR CALl NPAT GR CALl NRAT SP CALl NRAT GR CALl NRAT SP GR CAbi NRAT VALUE -40.000 66.400 -999,250-999.250 -28.000 75.100 -999,250-999.250 -2~.500 79.500 -999.250-999.250 -30.750 62.400 -999,250-999.250 -25,500 68,800 -999.250-999.250 -5].500 57,8OO -999.250-999.250 -49.500 50.400 -999.250-999.250 -999.250 -999.250 -999.250 -999.250 -q99.250 -999.250 -999.250 -999.250 MN triON lC 1LD DRHU .NCnb II, D GR DRHU NCNb ILD GR DRHU NCNB ILD DRHU NCNb G~ NCNb ILO GR DRHO NCNb GR DRHO NCNb IbP GR DRHO NCNb DRHU NCNL VAL 6 -999 -999 -999 5 -999 -999 -999 5 -999 -999 -999 . -999, -999, -999. . -999. -999. -999. . -999. -999. -999. 162754. -999, -999. -999, -999, -999. -9q9. -999. -999, -999. -999. -999, UE .668 .250 .25O .250 .808 ,250 .250 .250 .395 ,250 .250 .250 532 250 250 250 873 250 250 250 168 250 250 250 780 25O 25O 25O 250 250 250 250 250 250 250 250 MNLMONiC ibm DT NPHi fCNL ibm DT NPHi ~CNL IbM UT ~CNL IbM D'r NPH1 ?CNG DT NPHI fCN6 ILM NPHI rCNb Dr NPHi fCNb IbM DT NPHI ~CNL ibm NPHI fCNb VAbU -999, -999. -999. . -999, -999. -999. . -999. -999, -999, -999. -999. -999. -999. -999, -999. . -999, -999. -999, 14, -999, -999, -999. -999. -999. -999, -999. -999. -999. -999. -999, bi8 ~50 25O ~50 496 250 250 250 825 25O 250 250 417 25O 250 250 682 25O 25O 250 158 25O 250 25O 80~ 250 250 25O 25O 25O 250 25O 250 Z50 25O 250 MNkMUNIC bhBU RHUB bbSO GR RMOB bbSU GR RHOB hbSb GR bbSO GR hhSO GR RHUB bbSU GR RHOB LLSU GR RHO0 bbSO GR RHU~ VAbUL 8.~bb -999.25U -999.250 6,627 -999.250 -999.250 b.22b -999,250 -999.250 4,~87 -999.250 -999.250 5.075 -999,250 -999.250 -999.250 -999.250 4.108 -999.250 -999.250 -999,25O -999.250 -999,250 -999,250 -999.250 -999,250 NUHBLI~ U~ F!LCLJRD~; 975 I,[<NG'I.'h (.J~; RECLjRD~$J ghb I,F, NGIH O~ LAS~ R_F. CURD: 110 ILK 'I'RA I LF. R IJ~,NGTH: 62 BYTES FiLE NAME: EDIT .001 MAKIMUN PH¥SiCAL HLC[IRD LENGTH: NEXT ~IL~ NAME: 1024 TAPE 1~AILE~ LENGIH: 132 BYTES TAPL NAME: b1014 DATE: 80110/21 SERVICE NAMEr EDI~ I'APE CONTINUArI[JN NUM~E= O] NEXT TAPE NAME: C()MM~N~S: [INI~UE WEBL IDENTIFICATION NUM~E~ IS 50-029-20485
