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181-074
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-08 PRUDHOE BAY UNIT 17-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 17-08 50-029-20602-00-00 181-074-0 N SPT 8211 1810740 2100 18 2404 2330 2305 0 0 0 0 REQVAR P Sully Sullivan 3/22/2025 2 year MIT-T to MAIP (2100psi) per AIO 4F.002 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 17-08 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250323084705 BBL Pumped:2 BBL Returned:2 Tuesday, April 22, 2025 Page 1 of 1 9 9 9 9 9 9 9999 9 9 9 2 year MIT-T AIO 4F.002 James B. Regg Digitally signed by James B. Regg Date: 2025.04.22 15:14:15 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-08 PRUDHOE BAY UNIT 17-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 17-08 50-029-20602-00-00 181-074-0 W SPT 8211 1810740 2100 1686 1685 1685 1685 178 361 347 341 REQVAR P Austin McLeod 3/10/2025 Two year to MAIP. AIO 4F.002. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 17-08 Inspection Date: Tubing OA Packer Depth 504 2458 2304 2272IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250310183028 BBL Pumped:2.5 BBL Returned:2.4 Tuesday, April 22, 2025 Page 1 of 1 9 9 9 9 9 99 9 999 9 9 9 9 9 9 Two year to MAIP. AIO 4F.002 James B. Regg Digitally signed by James B. Regg Date: 2025.04.22 12:02:08 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-08 PRUDHOE BAY UNIT 17-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 17-08 50-029-20602-00-00 181-074-0 W SPT 8211 1810740 2100 1864 1865 1864 1866 152 351 338 330 REQVAR P Sully Sullivan 3/18/2023 2 year cycle MITIA to max anticipated injection pressure per AIO 4F.002. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 17-08 Inspection Date: Tubing OA Packer Depth 495 2656 2509 2471IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230320084029 BBL Pumped:3.3 BBL Returned:2.8 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2 year cycle MITIA AIO 4F.002. James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 16:23:26 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-08 PRUDHOE BAY UNIT 17-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 17-08 50-029-20602-00-00 181-074-0 N SPT 8211 1810740 2053 79 2607 2554 2533 0 0 0 0 REQVAR P Adam Earl 3/3/2023 MIT-T tested as per AIO 4F.002 IA cement repair 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 17-08 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230306131444 BBL Pumped:2 BBL Returned:2 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-T AIO 4F.002 James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 15:32:19 -08'00' Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: Brian Bixby State of Alaska MEMORANDUM Insp Num: mitBDB210401155047 Alaska Oil and Gas Conservation Commission DATE: Thursday, April 8, 2021 TO: Jim Regg/Fj(-Z�j ZI SUBJECT: Mechanical Integrity Tests P.I. Supervisor Hilcolp North Slope, LLC N ' 17-08 FROM: Brian Bixby PRUDHOE BAY UNIT 17-08 Petroleum Inspector 2573 - 2559 - Ste: Inspector PTD Reviewed By: Type Test P.I. Supry J1� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: Brian Bixby Permit Number: 181-074-0 Inspection Date: 4/1/2021 Insp Num: mitBDB210401155047 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 17-0s Type Inj N ' TVD 821 Tubing 64 ' 2610 - 2573 - 2559 - PTD 1810740 Type Test svr' Test psi 2405 IA 0 0 0 0 BBL Pumped: 2.1 - BBL Returned: 2.1 - OA 0 0 0 0 Interval REQVAR P/F P Notes: MITT as per AID 4F.002 Page 1 of I Thursday, April 8, 2021 MEMORANDUM TO: Jim Regg� Lr IZp I Zt 7.l P.1. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 31, 2021 SUBJECT: Mechanical Integrity Tests Hiloorp North Slope, LLC 17-08 PRUDHOE BAY UNIT 17-08 Ste: Inspector Reviewed By: P.I. Supry J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-074-0 Inspection Date: 3/20/2021 r Insp Num: milLOL210322100913 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min well� 17-08 Type lnj 1 W - TVD 821 Tubing, 1757 1757 1770 " 1765' PTD - - - 810740 Type Test SPT ]Test psi zoss IA eoa o " aoo 23e4 1I — BBL Pumped: 2.7 BBL Returned: 2.5 OA 317 516- 506 50a Interval REQVAR FE P --- --------- 1 --- Notes: MIT -IA every 2 -years to maximum anticipated injection pressure of 1905 psi, per AA AIO 4F.002, v Wednesday, March 31, 2021 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, March 27, 2019 �P.1. Supervisor ������ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 17-08 FROM: Brian Bixby PRUDHOE BAY UNIT 17-08 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry Z-flrz' NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Insp Num: mitBD6190327111815 Permit Number: 181-074-0 - Rel Insp Num: Inspector Name: Brian Bixby Inspection Date: 3/27/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We l 1108 Type lnj N ' T ID 8211 Tubings sas 2742 2e41 2608 PTD 1810740 lType Testi SPT Test psi 2500 IA 0 0 0 o - - T - o BBL Pumped: li 2BBL Returned: 2.9 - OA 0 0 - 0 REQVAR P/F P_ Interval- _ _ _ _.__ -_. Notes: MIT -T as per AIO 4P.002. MIT -!A was completed and passed on 3/2/2019 Wednesday, March 27, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg eyj 3141(c? DATE: Thursday, March 7, 2019 P.1. Supervisor , \ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 17-08 FROM: Bob Noble PRUDHOE BAY UNIT 17-08 Petroleum Inspector Sre: Inspector - Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 Insp Num: mitRCN190302113548 Rel Insp Num: API Well Number 50-029-20602-00-00 Inspector Name: Bob Noble Permit Number: 181-074-0 Inspection Date:. 3/2/2019 Packer Depth Pretest Well I7-08 Type Inj w',TVD 8111 Tubing I PTD 1810740 Type Test SPT Test psi o„ IA BBL Pumped: 34 BL Returned: OA s� Interval) _ REQVAR p/F r Notes: Per AIO 4F.002 the well requires two year MIT -IA to max injection pressure (1930) Initial 15 Min 30 Min 45 Min 60 Min IBIS 1618' 1018 _710 2641 2601 a" ala 401 Thursday, March 7, 2019 Page 1 of I • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,March 29,2017 P.I.Supervisor i``1�fl SUBJECT: Mechanical Integrity Tests M 1 BP EXPLORATION(ALASKA)INC. 17-08 FROM: Guy Cook PRIJDHOE BAY UNIT 17-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry M,'--Q. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: Guy Cook Permit Number: 181-074-0 Inspection Date: 3/26/2017 Insp Num: mitGDC170326112058 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 17-08 1Type Inj N TVD 1 8211 Tubing 3 2291 2246 2225 22U PTD1810740 Type Test SPT Test psi 2053 IA 0 0 0 1 0 0 BBL Pumped: 3.2 BBL Returned: 2.8 OA 8 8 8 11 8 8 Interval REQVAR P/F4111 Notes: Tubing was fluid packed. IA was on a vac. A PX plug was set in the tubing at 8382'. The MIT-T was for AA 4F.002. SCANNED AUG 1 5 2017, Wednesday,March 29,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,March 22,2017 P.I.Supervisor �, .. SUBJECT: Mechanical Integrity Tests 1 7 04\1BP EXPLORATION(ALASKA)INC. 17-08 FROM: Bob Noble PRUDHOE BAY UNIT 17-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry M' NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: Bob Noble Permit Number: 181-074-0 Inspection Date: 3/20/2017 Insp Num: mitRCN170321072059 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 17-08 Type Inj W TVD j 8211 Tubings 1648 1630 1625 1634 PTD 1810740 Type Test SPT Test psi` 2288 IA 257 2288 2182 2144 BBL Pumped: 0.6 BBL Returned: 1.5 OA 148 256 248 242 Interval REQVAR P/F P Notes: MIT-IA as per AIO 4E002 every 2 years to 1 x max anticapated injection pressure 1 x 1500 psi=1500 psi. 1.,..--- SCANNED -SCANNED AUG 2 4 2017 Wednesday,March 22,2017 Page 1 of 1 I"in wtgw ! 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O O O O O O O O O co cp t� ` 0i -) 0 CO 0o O U N E Q U O U 0 U U U U Ts c Lii x f0 CO Cr a p O O O M N O CO U:. 0 0 0 0 0 0 O O 0 In N N r O N 4 n L- N \ O O n co M pEnt M O tD M N - CO et N O In 0 N N N N N N N N N N u I: O) O) C) o) 0) C) o) Q) 0) 0 o O N N N N N N NNN in Q1 0 0 0 0 0 0 0 0 0 O O O O O O O O O L U) In In U) U) in in If) U) 4-,CO C µw1 CO C Q OV C 1:12 ccC) ~ Ln E a)u m a)U CO Lu �+ Lu' i 1 = d 145 Z` o a o o ,- m o o a - cu y a a+ E 4, v) Igo M M N a- O m H- C Q N W,, t` LL J J Z X J J ns Z N It 8 cop L1 � I g a` aQ STATE OF ALASKA A— JKA OIL AND GAS CONSERVATION COMk .ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well 0 Plug Perforations ❑ Perforate❑ Other 0 Packer Down Sqz Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waver❑ Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work. 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory❑ 181-074-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service 6.API Number: Anchorage,AK 99519-6612 50-029-20602-00-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028331 PBU 17-08 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 9715 feet Plugs measured 9271 feR E C E I V E D true vertical 9550 27 feet Junk measured See Attachment feet APR 0 8 2015 Effective Depth measured 9271 feet Packer measured See Attachment feet true vertical 9115 35 feet true vertical See Attachment feet /\ GCC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20"91 5#H-40 36.37-115 37 36 37-115.37 1490 470 Surface 2607 55 13-3/8"72#L-80 35 87-2643 42 35 87-2643 29 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1125 38 7"29#L-80 8606 89-9732 27 8464 58-9567 18 8160 7020 Perforation depth Measured depth 8985-9008 feet __ 9090-9118 feet 9137-9165 feet 9178-9213 _ feet 9313-9333 feet 9394-9414 feet 9417-9440 feet True Vertical depth 8834.61 -8857 18 feet 8937 68-8965 16 feet 8983 81-9011 3 feet 9024 06-9058.41 feet 9156 57-9176 19 feet 9236 01 -9255 61 feet 9258 55-9281 08 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) ' 4600'-8246' p� y� Treatment descriptions including volumes used and final pressure SCANNEIJ 171 Bbls 15.8 ppg LARC,3169 psi. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 18929 400 1834 Subsequent to operation 0 0 11563 300 1010 14 Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt 314-477 Contact Garry Catron Email Garry.Catron(a.BP.Com ' Printed Name Garry Catron Title PDC PE Signature ACKAATC�yE---- Phone 564-4424 Date 4/8/2015 vii- 4110 / I5 RBDMS APR - 9 2015 1 A q/34 1 Form 10-404 Revised 10/2012 Submit Original Only 17-08 181-074-0 Junk Attachment SW Name MD Date Description 17-08 8610 2/27/2015 Milled CBP 17-08 9191 5/2/201465 .8'4-1/2"Tubing Tail w/DB Nipple 17-08 9710 2/19/1988 Baker Packer Element Packers and SSV's Attachment ADL0028331 SW Name Type MD TVD Depscription 17-08 PACKER 8357.86 8222.16 5-1/2" HES TNT Packer 17-08 PACKER 8501.79 8362.11 5-1/2"TIW HB-BP Packer 17-08 PACKER 8581.73 8440.04 5-1/2" BOT 3-H Packer w 0,00000000 Ca CO CO N N- CO CO O N- O O CO N N U) •=1- 11-) 1- N000N U . 0 NU)) (0C) � vCC.))) 7TrCD •- N- O) N- NN1- 1:1:1 •- 0 CO CO v co ti CO O) CO 0) N- CO N (O N I-- M Uj M O) N- M N M N CO N I- N- V U) CO M TV N- CO O N CO CO CO co co U) O) N- N- U) 1- I-CO — O) CO M N CD U) N M CONr M M CO CO 4.0 U, 00 N M N U) O) •ct O M CO CO CO CO r- CO to U) N- CO 0) N CO CO CO L CO E 4m. 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O \ c $ \ E > ■ R2e - 0 D 2 « / 0 ci> CA co 0.0 7 e / ± / \ \ CO > > 20Ea) CC > 6 @ e .§ = w r \ CO TREE= CNH ACTUATORIWELLF3tAD= FMC APE-TY READINGS AVAGE 125 ppm BAKER CC 1 7_0 8 WHEN ON MI NOTES:W L REQUIRES A SSSSSSV WHEN ON MI '"OKB,ELEV= 71' BF.ELEV= KOP= 5700' 20"CONDUCTOR —{ Max Angle= 22"@ 6900' ' ' 1988' H5-1/2"HES X NP,D=4.562' Datum MD= 9022' —# ' Datum ND= 8800'SS D= " 13-3l8"CSG,72#,L-80,D=12.347" H 2641' �• , ► TOC(SWS MSCMT LOG ON 02/28/15) —I 4600' �. %' ,� 8294'-8296' HTBG PUNCH(12/29/14) 9-5/8'CSG,47#,L-80 BTC J&L —{ 7840' XO TO S0095 BTC ALGOMA 1' 8314' --I5-1/2'HES X NP,D=4.562" .• 3 $346' —19-5/8-X 5-1/2'HES TNT PKR,D=4.85" I 8382' —15-112'HES X NP,D=4.562" 5-1/2"TBG, 17#,L-80,.0232 bpf,D=4.892" $455' 1i' 8470' --19-5/8"X 5-1/2"UNIQUE OVERSHOT TBG STUB CUT(03/09/10) H 8468' X- 8499' H9-5/8"X 5-1/2'TIW FBBP T PKR,D=4.882" Minimum ID =3.958" @ 8581' 7" X 4-1/2" XO (TBG PARTED) II 8532' H5-1/2"FES XNMP,D=4.455" 8534' H15-1/2"PORTS)SW 5-1/2"TBG, 17#,L-80,.0232 bpf,D=4.892" —I 8544' 8562' �i5 1/2'SEAL ASSY W/O SEALS w 17' (STOP COLLAR&MLJLESHOE,D=4.938' 5-1/2-113G,17#,L-80 8RD AB-MOD, —1 8576' I — 1 j 8576' H9-5/8'X 5-1/2'BOT 3-H R(R D=4.75' .0232 bpf,D=4.892 t --8581 H 7"X 4-1/2"XO,D=3.958'(TBG PARTED) FISH-CEP(PUSHED DH 02/28/15) —1 ? TOP OF 7"LFR —{ 8605' J 8605' Hr X 4-1/2'LNR HGR w TIEBACK SLV,D=?? ? —4-1/2'PARTE)TBG TAL-CALII 05/02/14 (w/CAMCO DB-6 NP&WLEG,D=3.813') 4-1/2'TBG-PC,12.6#,N-80 BUTT, H ? 1 ,' I[ .0152 bpf,D=3.958"(BTM PARTED TBG) 9-5/8'CSG,47#,S00-95 BTC ALGOMA,D=8.681' H 8896' , PERFORATION SUMMARY REF LOG:BRCS ON 06/26/81 ANGLE AT TOP PERF:11°@ 8985' Note:Refer to Production DB for historical pert data 9170' —�TOPOF FLL(TAGGED 11/20/10) SIZE SFf INTERVAL Opn/S� SHOT SOZ V 3-3/8' 4 8985-9008 0 03/27/89 3-1/8' 4 9090-9118 O 03/14/82 �(� 9271' H CMT&SAND PLUG(SET 12/09/88) 3-1/8" 4 9137-9165 0 03/14/82 3-1/8' 4 9178-9213 C 03/24/84 3-3/8" 4 9313-9333 C 06/22/88 3-3/8" 4 9394-9414 C 06/22/88 3-3/8' 4 9417-9440 C 06/22/88 9710' -H FISH-BKR PKR ELEMENT 7"LNR,29#,L-80 8RD AB MOD,.0371 bpf,D=6.184" —I 9730' -A DATE REV BY COMMENTS DATE REV BY COAUtTS PRUDHDE BAY UNIT 07/02181 RWN 35 ORIGINAL COMPLETION 01/13/15 JCF/JMD CMT RETAt CMT(01/07/15) WELL: 17-08 02/24/97 ICES RWO 01/15/15 PJC MND CORRECTION PERMT No:'1810740 04/14/10 N419; RWO 02/28/15 CJS/PJC MLL CNP/CMT RETAN32 AR No: 50-029-20602-00 11/14/14 MD/PJC PARTED TBG(05/02/14 CALPB 03/02/15 CJS/PJC ADD LOG FOR TOO PKR D UPDATE SEC 22,T1 ON,R15E,2359'FML&955'FW. 12/15/14 JTG/JMD PULL NP REIY PATCH(12/14/14) 1 01/06/15 GTW/.NMC SET CEP/TBG PNCH(12/27-29/14) 1 BP Exploration(Alaska MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Friday,April 03,2015 P.I.Supervisor 1`(?�jC21?,/(5 SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC 17-08 FROM: Chuck Scheve PRUDHOE BAY UNIT 17-08 Petroleum Inspector Src: Inspector Reviewed By:"Tr— NON-CONFIDENTIAL ,, P.I.Supry T-� NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: Chuck Scheve Permit Number: 181-074-0 Inspection Date: 3/31/2015 Insp Num: mitCS150331105007 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wf ' I7- TypeJ w' t _1, szll i Tubing887 - ssa 884 -7 885 - PTD1 lslo�ao Type TestsPT Tsii 2053 IA1, 228 I2506 , 2399 - 2360 I ' I1 ---- - -- 11)/F — — Interval IoT[-tER ----- P ✓ --r L _OA 52 I 92 ' 94 92 - Notes: Post Patch&Packer Squeeze(AA request) SCANNE© Friday,April 03,2015 Page 1 of 1 T 0 / 10 f0 aJy VQ- N` 11 Luc'/n V U CU (6 V) y a) N W O F.i L L OC \1 o 03 m O o 0?S CJ Q c 0 o �O Q' C con a I u) u') In K) IA tl') In ,� co _c O cu E .,L", m H - N a- N t0 O l0 CO (D N 4 0 QT. > Q C O_ N O:= O '6 O T VU N a a) s — ., @ D a) 0 0 N v U L 6 W' J J J J J J J J J J a•' LL LL lL LLJ IL LUJ LL W W W DID N o ILL LL LL LL LL LL LL LL LL LL 71 cu E 'p .) Qs J J J J J J J J J J Q O C a ,� I•. < < < < < < < < < < C <.1 Z Z Z Z Z Z Z Z Z Z a v p� u O 7) LL LL LL LL LL LL LL LL LL LL a1 s U a1 Ir `� • 0 My i) 'E aJ aJ O O O a) 1- O ,Ti ..•. C O L C CU U > > c Z O I U Q ami _c o� > LL y a. E � o - 00000a am ? a V --. LL a Cl) Q-3 U Jo Md V s U W v J-� O �� 10 >._ >. CA ", \ 2 a p m !wrecert O O O O J O J O J J q `act2222 2 w LU UJ UJ j4: ; i, 222 u>- >- } } } } } } no m m < w m m m m m 1 0 U.1 Y 0 D 0 0 0 0 0 c 1 22Q2m22222 0 OZ O to 0 0 0 0 0 v = 0 Iii Lc, r, 1 WIWI it -ireiM Wirt Ce I I I I I I I I 1 1 1 i i o as a a aaa. a co t J 5 on w./ a GL1 /N W M T 00 N eT h M O O X N 0 Ili 6,1 1� c O O .- O a- O O - In O 0 0 0 0 0 0 0 0 0 0 f0 ,� i� 0 0 0 0 0 0 0 0 0 0 rp E > f� e- e- a' e- Q M m } cu t�+L '. V O D U U U O O V V C at x m S N N 0 e- O N 0 0 N O u LO 0 0 0 0 0 0 O O O 0 N. O T e') N. (D et I- N I� ) C Cn co co It) 1• ..:tO CO C) OiD en in O co M co 1 Cn N <O CO N n :.... N N N N N N N N N N N '-I: (n O) CA C) 0) C%) O) 0) O O) O Q N N N N N N N N N N � \ 01 0 0 0 0 0 0 0 0 0 0 V%) ,a) O O O O O O O O O O = I I Z11e, O )nl):' )nl )C) )"I U'I U) 1 1 I I I I I I I I I G �I C a1 L r�i .0 C co z in E . . . . _ _ , u `° u M. 41 � . m � 1a8 E T ; ` 17 O e E a 'i 1-CO O CO M N e- m C O 00 N N ` E , IN— t E 00 CO N N Vv' ^ N 74 (6 L a d Q ,-1`,', } a J (� J °° 2 1•- U a Z c co t� 1 rl ^ C ra c CO v) 01 co r a` a Q Wallace, Chris L (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, March 23, 2015 12:43 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OIL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); Morrison, Spencer; Regg, James B (DOA); AK, OPS FS2 Field OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION:Injector 17-08 (PTD #18190) Regulatory Testing Attachments: image002.png; image003 jpg; image001.jpg �� rD 810-7+ 0 All, Injector 17-08 (PTD #1810740) had recent wellwork performed to repair a leak in the production casing. A passing MIT- IA was performed against the cement squeeze on Febuary 16, 2015, demonstrating the presence of competent barriers downhole. The well has been reclassified as Under Evaluation to perform the necessary diagnostics prior to filing for an AA for continued injection. Plan forward: 1. DHD: Perform AOGCC witnessed MIT-IA 2. E-line: Perform WFL to demonstrate isolation behind pipe A copy of the wellbore schematic has been included for reference. Thanks, Laurie Climer (Alternate: Kevin Parks) BP�Allasska-Well Integrity Coordinator GVV U:o:)alWells Organ zat:on WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, March 30, 2014 10:26 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; 'chris.wallace@alaska.gov'; Morrison, Spencer Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Injector 17-08 (PTD #18110740) Tubing Leak Found 1 AI I, Injector 17-08 (PTD#1810740) has a tubing leak detected by a leak detection log on 03/29/2014. The well is reclassified as Not Operable until the leak is repaired and barriers tested. A copy of the TIO plot is included for reference. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GVVGlobal Welfs �/�/ Organization Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator@bp corn From: AK, D&C Well Integrity Coordinator Sent: Tuesday, March 11, 2014 9:16 PM To: 'chris.wallace@alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Morrison, Spencer; 'Regg, James B (DOA)'; AK, OPS FF Well Ops Comp Rep Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer Subject: UNDER EVALUATION: Injector 17-08 (PTD #18110740) Failing MIT-IA All, WAG Injector 17-08 (PTD#1810740)failed a pre-AOGCC MIT-IA on March 10, 2014.The well has been on water injection,with no noticeable pressure anomalies.At this time the well has been placed Under Evaluation for further diagnostics. Plan forward: 1. Eline: perform LDL 2. WIE:Additional diagnostics as needed Attached are copies of the wellbore schematic,TIO and Injection plots for reference. Please call with any questions. Thank you, Laurie Climer (Alternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator GWGioaal Wells Y Y Organ eat on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator(a)BP.com 2 • ",\\VA2, tea HES ASE �: ��: . , LI ' Cr n . . / 1 ) — 333 West Seventh Avenue GOVERNOR SFAN PARN[I 1. Anchorage, Aioska 99501 3572 .- Moin. 907.279 1433 Spencer Morrison Production Engineer ���� �� MAY 0 7 2014 7 BP Exploration(Alaska), Inchpp ` Q — 11 P.O. Box 196612 U Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-08 Sundry Number: 314-225 Dear Mr. Morrison: 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, 1?17 Daniel T. Seamount, Jr. Commissioner DATED this 1day of April, 2014. Encl. • STATE OF ALASKA APR 0 8 7014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well Ej • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: V b-114 h 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. VL.g BP Exploration(Alaska),Inc Exploratory ❑ Development ❑ 181-074-09//�/1 `f 3.Address: Stratigraphic ❑ Service ❑✓ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20602-00-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N PBU 17-08 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028331 '` 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): 9715 . 9550 ' 9271 9115 9271 9710 Casing Length Size MD 7VD Burst Collapse Structural Conductor 79 20"91.5#H-40 33-112 33-112 Surface 2607 13-3/8"72#L-80 34-2641 34-2640.87 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1125 7"29#L-80 8605-9730 8462.74-9564.96 8160 7020 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 for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑r BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑, • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Spencer Morrison Email Spencer.Morrison@BP.Com Printed Name Spencer Morrison Title Production Engineer Signature Phone 564-5773 Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \1--1^ 21 S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ / r'r c f/a--, - Other: .�1 l A relc-'1 s✓t Ct-Ff C r /-- ,/ / 1 a -C¢ 1 nJ ,'J-hrssi'� Tl 3 tom, t c ►� L RBDMSAY U 7. 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 0 — 4-0 4- ,---.7f APPROVED BY / �/ / Approved by: COMMISSIONER THE COMMISSION Date: l d tC Form 10-403 Revised 10/2012 °irJ.jpLNoA d for 12 months from the date of approval. Submit Form and Attachments in Duplicate vr- 4117114- doe /'4 . 70.6// r U, a) oo °) COOOO mNrCpOww00w I = J O J J Z J J a) Q C 0 0 0 0 0 0 0 Cd N- OD 00 N Ps O 00 C d. r- O O CO N N O V' ul r- N Ps OO O D U I.- CD CD CD O� U, CO M CD M 7 OD CA V I� m CO 00 OD OD Ps ti u) CA a) N T- O 00 N m N N CO M N En N- CO) 0) N CC) co CC) 0. 0 01 CO C r N CO 0) M Q M M Ps O M 00 N OD N- 5? c M CC C) N O CO O r- M O M C m v- U) CA M W (O CC) CO CO) 00 I� CO CO In � O 0 N- 00 CA N CO 00 CO CD J CL up 1-1 ~ M M co co M Lo N v Q ti Do co co Lo OOCD (, °000?? 00 O o Z = JOCNI CO ao JJ N • r, 0) _ N CA 00 Nr N Zo r N CV O co N d 01 u In d L- 0) CO 0 P- DI O 0) O LC) N O U, UC) C 1- 00 O c- CO CA In OD N T- N OD J W W 0) 'CT) () W U O p Q u Z Z Z Z W W W pp m I— Z Perforation Attachment ADL0028331 Well Date Perf Code MD Top MD Base TVD Top TVD Base 17-08 3/27/89 APF 8985 9008 8835 8857 17-08 3/14/82 PER 9090 9118 8938 8965 17-08 3/14/82 PER 9137 9165 8984 9011 17-08 3/24/84 APF 9178 9213 9024 9058 17-08 11/25/88 BPS 9313 9333 9157 9176 17-08 11/25/88 BPS 9394 9414 9236 9256 17-08 11/25/88 BPS 9417 9440 9259 9281 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF it .. Packers and SSV's Attachment ADLOO28331 Well Facility Type MD Top Description TVD Top 17-08 PACKER 8356 5-1/2" HES TNT Packer 8220 17-08 PACKER 8500 5-1/2"TIW HB-BP Packer 8360 17-08 PACKER 8579 5-1/2" BOT 3-H Packer 8437 ALAS.,.WELL ACTIVITY STATEMENT OF REQUIREMENTS(V1.3,DBR,LHD,EAc v x/15/14/ e General Information Well Name: 17-08 Well Type: Water Injection well API Number: 50-029-20602-00 Well Activity Classification: Conventional 4 Activity Description: Patch Setting Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: 100 Job Type: Profile Modification AWGRS Job Scope: PATCH TUBING/LINER Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Spencer Morrison Contact numbers: 907-564-5773 713-557-2814 Well Intervention Engineer: Bethany Free! Contact numbers: 907-564-4352 907-378-6493 Lead Engineer: Bernhard Stechauner Contact numbers: 907-564-4594 907-360-7485 Date Created: April 2,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or Inj Rate&Pressure 3/24/2014 I 13,454 bwpd I 1,440 psi Current Status: Not Operable If inoperable or under evaluation, why? Leak at 5,400;MD Recent H2S (date,ppm( None None Maximum Deviation(angle and depth) 22° 6,900'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 3.813'@ 8.647'MD Reservoir pressure(date,psig) 8/2/2009 3,502 psi Reservoir temperature,F 154°F Leak at 5,400'ELMD W/LLR of.6 BPM Shut in wellhead pressure 1,400 psi Known mechanical integrity problems(specifics) 2500 PSI Last downhole operation(date,operation( 03/29/2014 Leak Detect Log Most recent TD tag,(date,depth,toolstring OD( 03/09/2014,9,158'MD,1.5'Sample Bailer Comments,well history, On 03/10/2014 MIT-IA failed to 4,000 psi,LLR=.8 BPM @3,900 psi.On 03/29/14 LDL found leak point @5,400'ELMD with a LLR of background information,etc: 6 BPM @ 2500 psi. The plan forward is to get a caliper to understand the tubing before we set the straddle to make sure we don't have large wall losses. After the caliper is run and we understand the integrity of the tubing,we will set the patch. The specifications of this patch are as follows:25'element to element 5 1/2'Baker Flo-Guard set at 5,390'-5,415'MD based off of the LDL log.Patch max OD will be 4.52'and will have an approximate total length of 33'. Well Intervention Details Suspected Well Problem: Leak in the tubing at 5,400'indicated by a LDL Specific Intervention or Well Objectives: 1 Obtain a caliper and SBHPS.Set a nipple reducer in the nipple at 8,382'MD 2 Repair leak by setting patch over 5,400'and pressure test to ensure leak has been patched. 3 Key risks,critical issues: Mitigation plan: 1 Getting Stuck 2 Not repairing leak 3 Summary Step Service Line Activity 1 S Run a caliper to understand tubing integirty near patch location at 5,400'.Obtain a SBHPS.Set a 5.5'x3.5'nipple reducer at 8,382' MD 2 E Set a patch from 5,390'-5,415'MD.Element to element 3 F Perform a MIT-IA to ensure leak has been patched Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR(: 1.RU SL and hold PJSM 2.SL run a multi-finger caliper from the end of the tubing at 8,649'MD to surface. I b`' 3.Obtain a SBHPS P 1 5 4.Set a 5.5'x3.5'nipple reducer in the nipple at 8,382'MD 5.Call town PE Spencer Morrison with results of caliper,specifically the integrity of the tubing at 5,400' 1.RU EL and Set 5 14 Baker Floguard at 5,390'-5,415'.(These depths are specific to avoid setting on a collar( 2 E 2.Tie into LDL ran on 03/29/2014 to make sure we are using the same reference that the leak was detected on 3 F Perform MIT-IA to make sure the leak is patched.Do not exceed a pumping pressure of 2500 psi Performance Expectations(may be NA if no change anticipated due to the interventionl Expected Production Rates: BOPD MMSCFD BWPD 15000 FTP(psi): 1500 Choke setting: Post job POP instructions: Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE.=w CM/ — WELLHEAD= FMC -O Si, Y NOTES:H2S READINGS AVERAGE 125 ppm • •CTUATOR= BAKER C WHEN ON MI.WELL REQUIRES A SSSV WHEN ON KB ELEV= 71' MI. BF ELEV= ) 5'6 KOP= 5700' 20"CONDUCTOR H 110' u C Max Angle= 22°@ 6900' Datum MD= 9022' I 1988' -15-12'"HES X NIP,ID=4.562" Datum TVD= 8800'SS / 13-3/8"CSG,72#, L-80, ID=12.347" — 2641' l' 51.40-o �C� HA Minimum ID = 3.813" @ 8647' I I 8314' —j5-12"HES X NIP,ID=4,562" 4-1/2" CAMCO LANDING NIPPLE X 8346' H9-s/8"X 5-1/2"HES TNT PKR, ID=3.870" ' 8382' —15-1/2"HES X NIP,ID=4.562" 5-1/2"TBG, 17#,L-80, .0232 bpf, ID=4.892" —1 8455' 8470' H9-518"X 5-1/2"UNIQUE OVERSHOT TBG STUB CUT(03/09/10) —1 8468' - X 1 r 8499'—1-19-5/8"X 5-1/2"'WV HB-BP TP—KR, , ID=4.882"11 1 8532-15-1/2"HES XN NIP,ID=4.455" 1 8534' H5-1/7'PORTED SUB 5-1/2"TBG,17#,L-80, .0232 bpf,ID=4.897' H 8544' 8544' 15-112"SEAL ASSY W/O SEALS 1w/7"STOP COLLAR,ID=4.938'• Z 8576' —19-5/8"X 5-1/2"BOT 37H PKR-1 5-1/2"TBG,17#,L-80, .0232 bpf,ID=4.892 H 8586' - / 8586' H5-1/2"X 4-1/2"XO,ID=3.958" —I 8605' --17"X 4-1/2"LNR HGR w/TIEBACK SLV,ID=?? TOP OF T'LNR H 8605' In I 8647' —14-1/7'CAMCO LANDING NIP,ID=3.813" 8648' —141/7'BKR SHEAROUT SUB 4-117"TBG-PC,12.6#,N-80, .0152 bpf,ID=3.958" —{ 8649' 1 ` _ 8649' —141/2"WLEG,ID=3.958" 1---864-21---1-15 TT LOGGED 07/06/81 9-5/8"CSG,47#,L-80,ID=8.681" H 8896' , PERFORATION SUMMARY REF LOG: BHCS ON 06/26/81 ANGLE AT TOP PERF 11*Q 8985' Note. Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8985-9008 0 03/27/89 3-1/8" 4 9090-9118 0 03/14/82 f 9170' —I TOP OF FILL(TAGGED 11/20/10) 3-1/8" 4 9137-9165 0 03/14/82 4 9178-9213 C 03/24/84 4 9313-9333 S 12/09/88 _ 9271' --j CMT 8,SAND PLUG(SET 12/09/88) 4 9394-9414 S 12/09/88 0t'ff'11111� 4 9417-9440 S 12/09/88 41..1.. ►1111/11111/14 4..1.4. ►1111111111/14. 1111111 ►1/1.11. _ �14.,,�;7, 9710' H FISH-BKR PKR ELEMENT X111111111.111 7"LNR,29#, L-80, .0371 bpf,ID=6.184" —j 9730' 466644 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/02/81 ORIGINAL COMPLETION 08/11/10 OB/JMD PERF REVISIONS WELL. 17-08 02/24/97 LAST WORKOVER 11/24/10 RLW/PJC FCO(11/20/10) PERMIT No.'1810740 07/14/01 RN/TP CORRECTIONS 02/14/11_ MB/JMD ADDED SSSV SAFETY NOTE API No- 50-029-20602-00 04/14/10 N4ES RWO 01/17/12 TMN/JMD ADDED H2S SAFETY NOTE SEC 22,T1ON, R15E,2359'FNL&955'FWL 04/18/10 TLH DRLG HO CORRECTIONS 08/11/10 HB/JIVE DRLG DRAFT CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA . ' AWKA OIL AND GAS CONSERVATION COM oION REPORT OF SUNDRY WELL OPERATIONS .,.ter` 1. Operations Abandon (J Repair Well Lf Plug Perforations (J Perforate LJ • Other U Bright Water Performed: Alter Casing ❑ Pull TubinJ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WOO 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 181 -074 -0 3. Address: P.O. Box 196612 Stratigraphic❑ 'Service © 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20602 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028331 PBU 17 -08 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL . 11. Present Well Condition Summary: Total Depth measured 9715 feet ' Plugs measured 9271 feet true vertical 9550.27 feet Junk measured 9710 feet Effective Depth measured 9271 feet Packer measured See Attachment feet true vertical 9115.35 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 30 - 110 30 - 110 1530 520 Surface 2612 13 -3/8" 72# L -80 29 - 2641 29 - 2640.87 4930 2670 Intermediate None None None None None None Production 8868 9 -5/8" 47# L -80 28 - 8896 28 - 8747.33 6870 4760 Liner 1665 7" 29# L -80 8065 - 9730 7938.55 - 9564.96 8160 7020 Perforation depth Measured depth 8985 - 9008 feet 9090 - 9118 feet 9137 - 9165 feet 9178 - 9213 feet 9313 - 9333 feet 9394 - 9414 feet 9417 - 9440 feet True Vertical depth 8834.61 - 8857.18 feet 8937.68 - 8965.16 feet 8983.81 - 9011.3 feet 9024.06 - 9058.41 feet 9156.57 - 9176.19 feet 9236.01 - 9255.61 feet 9258.55 - 9281.08 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: 1 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JUN 18 ZD13 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 4191 3112 0 0 443 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPi.0 GSTOR ❑ WINJ ❑ WAG 12 . GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerh Printed Name Nita Sum. erhays, / Title Petrotechnical Data Technician Signatur me A. , ��� , i ir Phone 564 -4035 Date 6/11/2013 lie/7 RBDMS JUN 12 20 c //4 iii Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028331 TIO = 1200/300/20 Temp =Hot (Brightwater Reservoir Sweep Mod) Upon LRS arrival well injecting @ 5430 bwpd,DSO brought rate up to 8970 bwpd, monitor injection pressure. Pumping brightwater chemicals down TBG while on water injection © 8970 bwpd. Pumped 146 gal. EC9660A (Surfactant) Average of 48.6 gph for 3 hrs. Pumped a total of 146 gal. since start of project. Pumped 540.5 gal. EC9378A ( Polymer) Average of 180 gph for 3 hrs. Pumped a total of 540 gal. since start 5/14/2013 ** *Job continued to 5/15/13 WSR * ** ***Continued from 05- 14 -13 * ** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 9000 bwpd. Pumped 1069 gal. EC9360A (Surfactant) Average of 44.5 gph for 24 hrs. Pumped a total of 1215 gal. since start of project. Pumped 5535ga1. EC9378A ( Polymer) Average of 230.625 gph for 24 hrs. Pumped a total of 6075 gal. since start of project 5/15/2013 ** *Continued to 5- 16 -13 * ** * ** Continued from 05- 15 -13 * ** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 9000 bwpd. Pumped 1142 gal. EC9660A (Surfactant) Average of 47.583 gph for 24 hrs. Pumped a total of 2357 gal. since start of project. Pumped 5786 gal. EC9378A ( Polymer) Average of 241.08 gph for 24 hrs. Pumped a total of 11861 gal. since start of project 5/16/2013 ** *Continued to 5- 17 -13 * ** ** *Job continued from 5/16/13 WSR * ** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 9000 bwpd. Pumped 1011 gal. EC9660A (Surfactant) Average of 42.125 gph for 24 hrs. Pumped a total of 3368 gal. since start of project. Pumped 5543ga1. EC9378A ( Polymer) Average of 230.95 gph for 24 hrs. Pumped a total of 17404 gal. since start of project 5/17/2013 ** *Job continued to 5/18/13 WSR * ** • Daily Report of Well Operations ADL0028331 ** *Job continued from 5/17/13 WSR * ** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 9000 bwpd. Pumped 1124 gal. EC9660A (Surfactant) Average of 46.83 gph for 21 hrs. Pumped a total of 4492 gal. since start of project. Pumped 4859 gal. EC9378A ( Polymer) Average of 202.45 gph for 21 hrs. Pumped a total of 22263 gal. since start of project 5/18/2013 ** *Job continued to 5/19/13 WSR * ** ** *Job continued from 5/18/13 WSR * ** Job complete RDMO, Upon LRS departure valve postions SV= closed, WV,SSV,MV =open IA/OA =OTG 5/19/2013 FWHP 1220/320/40 FLUIDS PUMPED GALS 4492 EC -9660A SURFACTANT 22263 EC -9378A POLYMER 26755 TOTAL Casing / Tubing Attachment ADLOO28331 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 30 - 110 30 - 110 1530 520 LINER 1665 7" 29# L -80 8065 - 9730 7938.55 - 9564.96 8160 7020 PRODUCTION 8868 9 -5/8" 47# L -80 28 - 8896 28 - 8747.33 6870 4760 SURFACE 2612 13 -3/8" 72# L -80 29 - 2641 29 - 2640.87 4930 2670 TUBING 8559 5 -1/2" 17# L -80 27 - 8586 27 - 8444.2 7740 6280 TUBING 63 4 -1/2" 12.6# N -80 8586 - 8649 8444.2 - 8505.68 8430 7500 • • 1 1 • • • Packers and SSV's Attachment ADL0028331 SW Name Type MD TVD Depscription 17 -08 PACKER 8346 8139.64 5 -1/2" HES TNT Packer 17 -08 PACKER 8499 8288.39 5 -1/2" TIW HB -BP Packer 17 -08 PACKER 8576 8363.45 5 -1/2" BOT 3 -H Packer TREE= OW 1110 * WELLHEAD = FMC AL NOTES: H2S REACINGS AVERAGE 125 ppm ACTUATOR = BAKER C 17-08 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON KB. ELEV = 71 MI. BF. ELEV = i KOP = 5700' 120" CONDUCTOR 110' J Max Angle = 22° @ 6900' Datum AC = 9027 I 1 1988' H5-112" HES X NIP, ID = 4.567 1 Datum TVD = 8800' SS 1 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2641' Minimum ID = 3.813" @ 8647' I 1 8314' H5-1 HES X NIP, ID = 4.567 1 4-1/2" CAMCO LANDING NIPPLE 1 8346' H9-518" X 5-1/2" HES TNT PKR, ID = 3.870" 1 • 8382' —15-1/2" HES X NIP, ID = 4.562" 1 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 8455' I }.....---I 8470' —19-5/8" X 5-1/2" UNIQUE OVERSHOT 1 1TBG STUB CUT (03/09/10) H 8468' x- I 8499' H9-518" X 5-1/2" 11W HB-BP T PKR, ID = 4,887' I • 1 8532' H5-112" HES XN NIP, ID = 4.455" I 1 8534' H PORTED SUB 1 ........ .„.....---1 8544' 1 -5-112 " SEAL ASSY W/O SEALS 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.897' H 8544 — 1 w /7" STOP COLLAR, ID = 4.938" Z 1 8576' H9-5/8..x 5-1/7' 80T 3-H PKR 1 15-1/2" TBG, 17$, L-80, .0232 bpf, ID = 4.892 —1 8586' ■ -- 1 8586' H5-1/7' X 4-1/7 X0, ID = 3.958" I 8605' HT X 4-1/2" LNR HGR w /TIEBACK SLV, ID = ?? I 'TOP OF 7" LNR H 8605' 1 - 11111 • 1 8647. H.4-117' CAMCO LANDING NIP, ID = 3.813" 1 8648' H 4-1/7 BKR SHEAROUT SUB 1 1 4-1/7' TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" H 8649' I--- ------ ssa• 1H4 -112 " 4-1/2 WLEG, ID = 3.958" 1 8642 I aMD TT LOGGED 1 9-5/8" CSG, 47#, L-80, ID = 8.681" H 8896' i 1, PERFORATION SUMMARY REF LOG BHCS ON 06/26/81 ANGLE AT TOP FERF: 11 ° (;) 8985' Note: Refer to Production DB for hWtorical perf data SIZE SPF INTERVAL Opn/Scg DATE 3-3/8" 4 8985 - 9008 0 03/27/89 1 3 9170' H TOP OF FILL (TAGGED 11/20/10) 1 1/8" 4 9090 - 9118 0 03/14/82 3-1/8" 4 9137 - 9165 0 03/14/82 I I 4 9178 - 9213 C 03/24/84 9271' HCMT & SAND PLUG (SET 12/09/88) 1 4 9313 - 9333 S 12/09/88 ■......_ 4 9394 - 9414 S 12/09/88 tr111"411't 4990* 4 9417 - 9440 S 12/09/88 ••••••1 ■•••••• •••••*f /•••••• 00.91 10904. ••••••• 40949 0001 14904. 4. L • 44.C.. ■•••■ '7! 9710' H FISH- BKR PKR ELEMENT 1 •••■■••• ■••••••• 1 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 9730' sa*ease, DATE REV BY COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/02/81 ORIGINAL COMPLETION 08/11/10 OB/J11/1D PERF REVISIONS WELL: 17-08 02/24/97 LAST WORKOVER 11/24/10 RLW/PJC FCO (11/20/10) PERAK No: '1810740 07/14/01 RN/TP CORRECTIONS 02/14/11 M(31.1NO ADDED SSSV SAFETY NOTE API No 50-029-20602-00 04114/10 NIES RWO 01/17/12 TIWYJNIO ADDED -25 SAFETY NOTE SEC 22, TI ON, RI SE, 2359' FNL & 955' FWL 04/18/10 TLH DRLG I-10 CORRECTIONS 08/11/10 HB/JIVO DRLG DRAFT CORRECTIONS BP Exploration (Alaska) MEMORANDUM To: Jim Regg ~{~ ~ ~ ~ ~ l o P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 14, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 17-08 PRUDHOE BAY UNIT 17-08 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT 17-08 Insp Num: mitJCr100504075917 Rel Insp Num: API Well Number: 50-029-20602-00-00 Permit Number: 181-074-0 Inspector Name: John Crisp Inspection Date: 4/29/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 17-08 ~ Type Inj. i w TVD x211 ' IA ago 2soo za6o 2460 P.T.D 1810740 TypeTest sPT Test psi 2053 / I OA 210 410 420 420 Interval INITAL p~ P i Tubing 840 840 840 840 - NOtes: 3.5 bbls pumped for test "' ~~~,, z .,- Friday, May 14, 2010 Page 1 of 1 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO~OF SUNDRY WELL OPERA ON; RECEIVED MAY~~2010 1. Operations Performed: !2}S ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspen~~' ^ After Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: ~ Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 181-074 3. Address: ®Service ^ Stratigraphic ~ API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20602-00-00 7. Property Designation: ~ 8. Well Name and Number: \ ADL 028331 PBU 17-08 9. Field /Pool(s): ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 9730' feet true vertical 9565' feet Plugs (measured) 9271' Effective depth: measured g271' feet Junk (measured) 9710' true vertical 9115' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2641' 13-3/8" 2641' 2641' 4930 2670 Intermediate 8896' 9-5/8" 8896' 8747' 6870 4760 Production Liner 1665' 7" 8605' - 9730' 8463' - 9565" 8160 7020 Perforation Depth: Measured Depth: 8985' - 9213' True Vertical Depth: 8835' - 9058' Tubing (size, grade, measured and true vertical depth): 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 8649' 8506' Packers and SSSV (type, measured and true vertical depth): 9-5/8" x5-1/2" TIW 'HB-BP T packer; 8499' 8359' 9-5/8" x 5-1/2" Baker'3-H' packer 8576' 8434' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~ ~,~ : •st~~ I ` , t a ! ~~ '. ` 1 " . . ~ ~ s~ ?' ~ ' ,.3 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1' bing Pressure Prior to well operation: Subsequent to operation: 6,261 400 686 13. Attachments: ^ Copies of Logs and Surveys run 4. Well Class after work: ^ Exploratory ^ Development ®Service erations f Well O ® D il R rt p a y epo o ® Well Schematic Diagram Well Status after work: ^ Oil ^ Gas ^ WDSPL ^ GSTOR ®WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA ff C.O. Exempt: Contact Hank Baca, 564-5444 310-058 Printed Name Terrie Hubble Title Drilling Technologist f ~ Prepared By Name/Number. Signature Phone 564--4628 Date "" ~ ~b Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 RBDMS .MAY 14 yQ~ ~_ ~ ,~': /$'• /0 Submit Original Only • 17-08, Well History (Pre Rig Workover) Date Summary 3/3/2010 WELL S/I ON ARRIVAL. PULLED P-PRONG FROM DB-LOCK @ 8,612' SLM._, PULL 4 1/2" DB PLUG BODY C«3 8,616' SLM (8,647' MD). DRIFT W/ 4.405" CENT. 2.50" S.BAILER TO 8,557' SLM (8,586' MD) FWHP=200/0/0. WELL S/1 ON DEPARTURE, DSO NOTIFIED OF STATUS. 3/8/2010 T/IA/OA= SI/Vac/Vac Temp=S1 PPPOT-T (PASS) PPPOT-IC (FAIL) (Pre Rig) PPPOT-T : RU 2 HP BT onto THA 800 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "Standard" all others functioned with no problems. PPPOT-IC : RU 2 HP BT onto IC 0 psi. Attempted to pressure to 3500 psi, Pressure dropped to 600 psi. Cycle LDS found (4) LDS "Standard" LDS are from 1:00 to 3:00 & 8:00 position. Contacted W I E notified of condition of well, secured well gather material and LDS for replacement. ***Will Continue post Circ out*** 3/8/2010 T/I/0=100/Vac/Vac. Temp=Sl. Tbg FL. (Pre-Composite bridge plug for E-line). TBG FL @ 756' (18 bbl). 3/9/2010 T/I/O = 80/Vac/Vac. Temp = SI. TBG FL (Pre composite bridge plug - Eline). WAG (water). TBG FL Q 744' (18 bbls). Eline in control of well. 3/9/2010 WELL SHUT IN ON ARRIVAL (PRE ELINE). SSV CLOSED, INITIAL PRESSURES 100/0/0. RIH WITH HALLIBURTON 3.66" O.D. OBSIDIAN BRIDGE PLUG AND SET ~ 8602'. TAGGED PLUG AFTER SETTING TO CONFIRM SET. JET CUT TUBING AT 8468' WITH SLB 4.15" O.D. POWER CUTTER. DEPTH CORRECTED TO TUBING TALLY DATED 6-30-81. JET CUT IS 10' BELOW TOP COLLAR OF FIRST FULL JOINT ABOVE TOP PACKER. WELL LEFT SHUT-IN. FINAL T/I/O: 100/0/0 PSI. NOTIFIED DSO OF VALVE POSITIONS. JOB COMPLETE. 3/19/2010 T/I/O=0/0/0 Temp = SI Circ Out Well, CMIT TxIA PASSED to 4000 psi, MIT-OA PASSED to 2000 psi (RWO Prep) Pumped into Tbg w/ 3 bbls meth, 878 bbls Sea Water down Tbg through jet cut up IA to 17- 16 FL. Freeze protected w/ 150 bbls diesel. U-Tubed FP into IA. CMIT Tx IA to 4000 psi. Passed. Lost 60 psi in first 15 minutes & 40 psi in second 15 minutes. Bleed tbg & IA pressure down to 0 psi. RD off IA. RU to OA. Pumped 2 bbks of diesel. MIT OA to 2000 psi. Lost 120 psi in first 15 minutes & 40 psi in second 15 minutes. Bleed OA pressure down to 0 psi. Tags hung. FWHP=O/0/0. 3/24/2010 T/I/O=SSV/0/0, Temp=Sl. Repair stuck LDS on casing head (pre RWO). Stung into IC test port (0 psi). Freed up and removed 2 of 4 stuck LDS, threads heavily damaged in head (1:00 position). Ran tap to clean up threads, new LDS ran in 6" and locked up. Was able to back out 1.5" and locked up again. Installed packing and gland nut. Removed and replaced 11 other LDS assemblys with new. Still have 2 stuck LDS to remove_ Will continue in AM. ***JOB NOT COMPLETE*** 3/25/2010 T/I/O=SSV/0/0, Temp=S1. Repair stuck LDS (pre RWO). Stung into IC test port (0 psi). Was able to free up and remove first stuck LDS, chased threads with tap and installed new LDS assembly. Unable to get second stuck LDS freed up. Cut off remaining pin, RU Wach's drill and drilled out remaining 4" of pin, chased threads with tap and installed new LDS assembly. PT test void, pressured to 3500 psi, pressure quickly decreased to 700 psi, no external leaks. Bled back to 0 psi. Page 1 of 1 BP EXPLORATION- Page 1 of 1 ........Operations Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: MOBILIZATION Start: 4/6/2010 End: 4/9/2010 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2010 00:00 - 02:30 2.50 MOB P PRE RIG DOWN RIG -SCOPE AND LOWER DERRICK -RIG PREP FOR RIG MOVE 02:30 - 04:00 1.50 MOB P PRE WEEKLY SAFETY MEETING -DISCUSSED WEEKLY ADW SAFETY NOTIFICATIONS -HELD DISCUSSION AROUND RECENT DROPPED OBJECT INCIDENTS AND HOW TO PREVENT THEM ON OUR RIG AFTER ACTION REVIEW FOR DS9-25, 04:00 - 09:00 5.00 MOB P PRE PJSM WITH TRUCK CREW. -LEAVE DS9-25, MOVING RIG TO DS17-08 -24 HRS NOTICE TO AOGCC (06:00 HRS) ** JOHN CRISP CALLED BACK AT 0630 AND WAIVED WITNESS FORM THE STATE. HE INDICATED TO CALL HIM BACK IF FOR SOME REASON THE TEST IS DELAYED. " 09:00 - 12:00 3.00 MOB P PRE SPOT OVER WELL -SPOT PIPE SHED AND PITS. 12:00 - 16:00 4.00 MOB P PRE RIG WALK THRU -DERRICK INSPECTION -RAISE AND SCOPE DERRICK -FINISH RIG UP '"" RIG ACCEPTED AT 16:00 "" 16:00 - 19:30 3.50 MOB P PRE RIG UP -RIG UP ON TREE TO CIRCULATE. -TAKE ON 120 DEG SEA WATER TO PITS -OPEN AND DRAIN TREE. 19:30 - 20:30 1.00 MOB P PRE PICK UP AND RU LUBRICATOR -PT TO 500 PSI -PULL BPV -LD LUBRICATOR -(IA) AND (OA) ON VAC'S Printed: 5/6/2010 10:39:37 AM • BP EXPLORATION Page t of 6 Operations Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: WORKOVER Start: 4/9/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code. NPT_ Phase Description of Operations 4/8/2010 120:30 - 21:30 1.001 KILL 22:30 - 00:00 1.501 KILL 4/9/2010 00:00 - 02:00 2.00 KILL P 02:00 - 02:30 I 0.501 KILL I P 02:30 - 04:00 1.50 ~ DHB ~ P 04:00 - 06:00 2.00 ~ WHSUR P 06:00 - 09:00 3.00 WHSUR I P DECOMP RU SUFACE LINES TO TREE -PJSM ON WELL KILL OPERATIONS -TEST SURFACE LINES TO 3500 PSI DECOMP CIRCULATE WELL. SWAP WELL OVER TO SEAWATER. -REVERSE CIRCULA 60 BBLS DOWN THE IA TAKING RETURNS UP THE TUBING THROUGH THE CHOKE OUT TO THE TIGER TANK, -PIMPED 4 BPM ,350 PSI, PUMPED 60 BBLS BEFORE GETTING RETURNS. STOPED & PUMPED DOWN TUBING AND UP THE IA, -STAGED UP CIRCULATION FROM 3 BPM TO 5 BPM , 170 PSI TO 450 PSI -PUMPED 12,000 TOTAL STROKES. -CIRCULATED 710 BBLS TOTAL DECOMP CIRCULATE WELL. SWAP WELL OVER TO SEAWATER. -STAGED UP CIRCULATION FROM 3 BPM TO 5 BPM , 170 PSI TO 470 PSI -REVERSE CIRCULATED 65 BBLS DOWN THE IA TAKING RETURNS UP THE TUBING THROUGH THE CHOKE OUT TO THE TIGER TANK -PUMPED 12,000 TOTAL STROKES. DECOMP SHUT DOWN AND MONITOR WELL -20 MIN WAIT -TUBING PSI 0 , IA PSI 0 DECOMP DRAIN TREE, DRIFT TREE -FMC DRY ROD ISA BPV -1000 PSI TEST FROM BELOW F/ 10 CHARTED MINUTES. -BLEED CONTROL LINES AND ADAPTOR DECOMP ND TREE -BLEED CONTROL LINES AND ADAPTOR -FMC INSPECT HANGER THREADS. MARGINAL CONDITION -NOT ABLE TO MU THE LANDING JNT XO TO THE HANGER -HOWEVER THE BLANKING PLUG WOULD MAKE UP. -FMC SUGGUESTED WE GET A SPEAR OUT TO PULL THE TUBING HANGER -FMC INSTALL BLANKING PLUG ON BPV DECOMP NU 13-5/8" GK HYDRIL BOPE -JOHN CRISP, STATE AOGCC INSPECTOR WAIVED WITNESS FOR TEST C~ 06:30 ON 4/8/2010 09:00 - 18:00 9.00 WHSUR P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: (ACTUAL TEST TIME) -TEST TO 250 PSI LOW AND 4,000 PSI HIGH PRESSURE. -TESTED 3-1/2" X 6" VBR'S WITH 3-1/2" & 5-1/2" TEST JOINTS. -TESTED ANNULAR WITH 3-1/2" TEST JOINT T/ 3,500 PSI -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY NABOBS TOOL PUSHER RICK BJOURUS, BP WSL BRETT ANDERSON, NABOBS DRILLER LYLE BUCKLER -TESTED FLOOR VALVES. Printed: 5/6/2010 10:39:44 AM • • BP EXPLORATION Page 2'of 6 Operations Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: WORKOVER Start: 4/9/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 4/9/2010 09:00 - 18:00 9.00 WHSUR P DECOMP PERFORM KOOMEY TEST -200 PSI BUILD UP TO 3000 PSI FROM 1700 PSI = 43 SECONDS. -FULL BUILD UP TO 3000 PSI = 160 SECONDS. -4 BOTTLES x 1850 PSI. -TESTED 3 1/2" KELLY AND KELLY VALVE ""TEST WITNESS WAIVED BY JOHN CRISP OF AOGCC."~ 18:00 - 18:30 0.50 WHSUR P DECOMP PULL BLANKING PLUG FROM BPV. 18:30 - 19:30 1.00 WHSUR P DECOMP NU RISER, SPACER AND DUTCH SYSTEM. 19:30 - 21:30 2.00 WHSUR P DECOMP PU LUBRICATOR AND TEST TO 500 PSI. PULL FMC BPV. -WELL SUPPORT TO PULL ISA FMC BPV 21:30 - 23:30 2.00 WHSUR P DECOMP PU LANDING JOINT AND MU TO DOUBLE ITCO GRAPPLE SPEAR, SPEAR BHA: -2-7/8" REG BULL NOSE -5-1/2" PACK OFF W/ 2-7/8" REG -2-7/8" RE BOWEN ITCO SPEAR -4-1/2" IF "C" DIMENSIONAL SPEAR -XO RUN IN & ENGAGE HANGER -BOLDS. -PULL HANGER TO THE FLOOR AND LD -125 K STRING WT , 140 K TO PULL FREE 23:30 - 00:00 0.50 WHSUR P DECOMP CIRCULATE BOTTOM UP 4-5 BPM @ 150 PSI 5 BPM @ 210 PSI. CIRCULATE A TOTAL OF 6300 STROKES, -370 BBLS. 4/10/2010 00:00 - 01:00 1.00 PULL P DECOMP CIRCULATE BOTTOM UP 4-5 BPM @ 150 PSI 5 BPM @ 210 PSI. CIRCULATE A TOTAL OF 6300 STROKES, 370 BBLS. 01:00 - 02:00 1.00 PULL P DECOMP RU SLB DOUBLE CONTROL LINE SPOOLER. 02:00 - 04:30 2.50 PULL P DECOMP POOH WITH 5-1/2" L-80 TUBING FROM 8 468' _ -POH 50 JNTS TO 2,050' -END OF CONTROL LINE. -RETRIEVED 47 BANDS AND BUCKLES, MISSING 6 04:30 - 05:00 0.50 PULL P DECOMP LD SLB DOUBLE CONTROL LINE SPOOLER. 05:00 - 06:00 1.00 PULL P DECOMP CONT: POH WITH 5-1/2", L-80 TUBING. 06:00 - 06:30 0.50 PULL P DECOMP CREW CHANGE -PRE-TOUR CHECKS -ENVIRONMENTAL WALK AROUND. -SERVICE CROWN AND INSPECT DERRICK. 06:30 - 12:30 6.00 PULL P DECOMP CONTINUE TO POOH WITH 5-1/2" L-80 TUBING -LD 205 JTS -1 CUT JT 10.83', OD FLARED AT CUT TO 6.375". 12:30 - 13:30 1.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -RIG DOWN 5-1/2" HANDLING EQUIPMENT. 13:30 - 14:30 1.00 FISH P DECOMP RU TO RUN MILLING BHA. 14:30 - 19:00 4.50 FISH P DECOMP PU MILLING BHA #1 -LOAD SHED WITH DC AND PAC PIPE BHA AS FOLLOWS: -CONVEX MILL AND DRESSING MILL -WASH OVER BOOT BASKET -DOUBLE PIN SUB -9-5/8" CASING SCRAPER Printed: 5/6/2010 10:39:44 AM • __ BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: WORKOVER Start: 4/9/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From- To Hours Tasl< Code NPT Phase Description of Operations 4/10/2010 14:30 - 19:00 4.50 FISH P DECOMP -BIT SUB -BUMPER SUB -OIL JAR -XO -(6) 6-1/4" DRILL COLLARS -XO -(MI) WELL COMANDER CIRCULATING TOOL 19:00 - 00:00 5.00 FISH P DECOMP RIH W/MILLING BHA# 1 -RIH ON 3-1/2" DP TO -8200', -ROUGHLY 2 STANDS ABOVE THE TUBING STUB 4/11/2010 00:00 - 03:00 3.00 CLEAN P DECOMP RIH W/MILLING BHA# 1 -RIH ON 3-1/2" DP TO -8200', -ROUGHLY 2 STANDS ABOVE THE TUBING STUB -TIH W/ 254 JNTS. -PUW 120 K ,SOW 115K 03:00 - 04:00 1.00 DHB P DECOMP PU HALLIBURTON STORM PACKER -SET PACKER 22' IN -PUTS MILL @ 8,223' MD 04:00 - 04:30 0.50 DHB P DECOMP RU TEST EQUIPMENT -TEST PACKER TO 1000 PSI FOR 10 CHARTED MIN. 04:30 - 06:00 1.50 BOPSU P DECOMP ND 13-5/8" GK HYDRILL BOP'S -BARRIERS IN PLACE ARE A CBP SET @ 8,602' AND HES STORM PACKER SET 22' IN. 06:00 - 09:30 3.50 WHSUR P DECOMP REPLACE TUBING SPOOL AND 9-5/8" PACK pFF. -TEST PACK OFF TO 5000 PSI FOR 10 MIN. (CHARTED) 09:30 - 11:00 1.50 BOPSU P DECOMP NIPPLE UP 13-5/8" GK HYDRILL BOP'S -BARRIERS IN PLACE ARE A CBP SET @ 8,602' AND HES STORM PACKER SET 22' IN. 11:00 - 12:30 1.50 BOPSU P DECOMP TEST BREAKC IN 13-5/8" GK HYDRILL BOP -TEST TO 250 PSI LOW AND 4000 PSI HI. (CHARTED) -TESTED KILL LINE & CHOKE CONNECTIONS & BASE FLANGE -INSTALL 8.75" WEAR RING. 12:30 - 13:30 1.00 DHB P DECOMP RELEASE HES STORM PACKER AND LAY DOWN SAME 13:30 - 16:30 3.00 CLEAN P DECOMP TIH TO TAG COMPOSITE BRIDGE PLUG -TAGGED UP AT 8,556' -PICKED UP KELLY, PUW-127K ,SOW-123K -ROTATED ON CBP ,ROT WT-127K, RPM-8 -SPR-29 SPM @ 230 PSI -CIRCULATING AT 3 BPM , @ 730 PSI .. SET DOWN 8K AND LOST TOTAL CIRCULATION, CONTINUED TO PUMP WITH NO RETURNS. -RACKED BACK KELLY. 16:30 - 18:00 1.50 CLEAN P DECOMP TIH TO DRESS OFF TUBING STUB -TAGGED STUB AT 8,457' , W/JNT 254 -LD JNT 264 AND PU 24' PUP AND KELLY. 18:00 - 20:00 2.00 CLEAN N RREP DECOMP DOWN TIME DUE TO ROTARY CLUTCH INSPECTION AND REPAIR -CLUTCH AIR SUPPLY NOT WORKING. 20:00 - 21:30 1.50 CLEAN P DECOMP CONT: DRESSING OF TUBING STUB -EST PARAM: PUW-137K ,SOW-125K ,ROT WT-130K F'rintecJ: oitiizuiu lU::iy:44 HM • • BP'EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: WORKOVER Start: 4/9/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task .Code NPT Phase Description of Operations 4/11/2010 20:00 - 21:30 1.50 CLEAN P DECOMP -RPM-40 , 26PM C~ 60 PSI. -DRESS OFF 6' OF 5-1/2" TBG STUB C~? 8,453' -VERIFY DRESS OFF WITH SMOOTH WASH OVER WITH NO ROTATION. 21:30 - 22:00 0.50 CLEAN P DECOMP SET KELLY BACK -LD 24' PUP AND 10 JNTS OF DP. -RECIPRICOATE (4X) FROM 8,256' TO 8,435' 22:00 - 23:30 1.50 CLEAN P DECOMP SLIP AND CUT DRILL LINE @ 8,342' -CUT AND SLIP 84' -CLEAN AND CLEAR RIG FLOOR 23:30 - 00:00 0.50 CLEAN P DECOMP HELD WEEKLY SAFETY MEETING -REVIEWED ISO 14001 EMS REVIEW 4/12/2010 00:00 - 08:30 8.50 CLEAN P DECOMP CONTINUE TO POOH LD 3-1/2" DP. -JT #190 AT 05:30. 08:30 - 11:30 3.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR -REMOVE WEAR RING 11:30 - 13:00 1.50 BUNCO P RUNCMP RU TO RUN COMPLETION. -RU TORQUE TURN EQUIPMENT. -SINGLE JT COMPENSATOR. -RU STABBING BOARD. -SETUP DOUBLE STACK TONGS. 13:00 - 13:30 0.50 BUNCO RUNCMP PJSM ON RUNNING CASING -RIG CREW, RIG LEADERSHIP & AND ALL THIRD PARTIES 13:30 - 15:00 1.50 BUNCO P RUNCMP PU COMPLETION ASSY PER PROGRAM AND RIH. -PJSM WITH RIG CREW, HES, CASING CREW, AND UNIQUE MACHINE THREAD INSPECTOR. -RUN 9-5/8" X 5-1/2" OVERSHOT ASSEMBLY AND HES . 9-5/8" X 5-1/2" TNT PACKER. -BAKER LOCK ALL JNTS OF 5-1/2" TCII BELOW THE PACKER. 15:00 - 22:30 7.50 BUNCO P RUNCMP RIH WITH 5-1/2" TCII COMPLETION PER PROGRAM -MU 5-1/2",17# ,L-80 TCII ,USING COMPENSATOR AND TORQUE TURN -USING JET LURE SEAL GUARD -REPLACED JNTS # 35 # 91 # 131 -C/O COLLARS ON JNT # 24 , # 75 , #86 22:30 - 00:00 1.50 BUNCO RREP RUNCMP DOWN TIME DUE TO WIRE PROBLEM WITH THE STABBING BOARD -WINCH WOULD NOT GO UP OR DOWN. 4/13/2010 00:00 - 00:30 0.50 BUNCO RREP RUNCMP DOWN TIME DUE TO WIRE PROBLEM WITH THE STABBING BOARD -WINCH WOULD NOT GO UP OR DOWN. 00:30 - 09:00 8.50 BUNCO RUNCMP RIH WITH 5-1/2" TCII COMPLETION PER PROGRAM -MU 5-1/2",17# ,L-80 TCII ,USING COMPENSATOR AND TORQUE TURN -USING JET LURE SEAL GUARD -MU TORQUE 5,500 FT-LB 09:00 - 10:00 1.00 BUNCO P RUNCMP FINISHED RUNNING 5-1/2" COMPLETION -RAN 198 JNTS -TAGGED UP ~ 8,461' ON JNT 199 -PERFORM SPACE OUT ,ADD 9.82' PUP -LAND 13-5/8" BY 7" TC2 TUBING HANGER Printetl: 5/6/2010 10:39:44 AM • BP EXPLORATION' Page 5 of 6 Operations Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: WORKOVER Start: 4/9/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date .From - To Hours Task Code NPT Phase Description of Operations 4/13/2010 09:00 - 10:00 1.00 BUNCO RUNCMP -PUW 118K, 116K -FMC RAN IN LOCK DOWN SCREWS. 10:00 - 13:30 3.50 BUNCO RUNCMP CIRCULATE AND CONDITION -REVERSE CIRC 200 BBLS OF 140 DEG SEAWATER. -SPR 1 BPM ~ 30 PSI -REVERSE CIRC 400 BBLS OF SEAWATER W/ CORROSION INHIBITOR -PUMPED AT 3.5 BPM C~3 390 PSI 13:30 - 14:30 1.00 BUNCO RUNCMP RU HOT OIL TO FREEZE PROTECT WELL -PUMP 90 BBLS DOWN THE I.A. -PUMP 46 BBLS DOWN THE TUBING -BLED OFF ALL THE PRESSURES 14:30 - 15:00 0.50 BUNCO RUNCMP MU LANDING JOINT IN HANGER -DROP BALL-N-ROD DOWN LANDING JOINT -LD LJ. 15:00 - 18:00 3.00 BUNCO RUNCMP START PUMPING DOWN THE TUBING TO SET THE PACKER -PACKER SETTING DIRECTION COMING FROM HALLIBURTON PACKER HAND. -PRESSURED UP TBG 4.5 BPM TO 4000 PSI O ERVEC PACKER SET AT 2300 PSI - HELD 4000 PSI FOR 30 MIN, CHARTED TEST ,LOST 80 PSI IN 30 MIN -STARTED BLEEDING WELL HEAD PRESSURE DOWN - -BLED PRESSURE DOWN TO 1500 PSI. 18:00 - 19:00 1.00 BUNCO RUNCMP PRESSURE TESTED IA -FILLED THE IA W / 15 BBLS OF DIESEL -PRESSURE TESTED TO 4000 PSI FOR 30 MIN, CHARTED TEST -GOT GOOD TEST, BLEED DOWN PRESSURE -LOST -100 PSI IN 30 MIN -BLEED DOWN ALL PRESSURES TO 0. *** CALLED AOGCC AND LEFT A MESSAGE @ 19:00 FOR A 24HR NOTICE OF UPCOMING BOP TEST FOR DS3-348 *** -20:30 ,JEFF JONES CALLED BACK AND WAIVED WITNESS TO THE TESTING. HE SAID TO CALL BACK IF THE TEST GETS DELAYED MORE THAN A DAY. 19:00 - 20:00 1.00 BUNCO P RUNCMP SET 6" ,(J) TWC -TEST FROM ABOVE TO 4000 PSI FOR 10 CHARTED MIN. -UNABLE TO TEST FROM BELOW 20:00 - 21:30 1.50 BUNCO RUNCMP ND 13-5/8" 5M BOP -PJSM, ON BOP ND OPERATIONS 21:30 - 22:30 1.00 BUNCO RUNCMP NU FMC 13-5/8" X 7-1/16" 5M ADAPTER FLANGE -NU 7-1/16" FMC TREE 22:30 - 23:30 1.00 BUNCO P RUNCMP TESTED HANGER VOID AND SEALS -TESTED TO 5000 PSI, GOOD TEST. -TESTED TREE & ADAPTER TO 5000 PSI ,HELD 5 MIN,GOOD TEST NO VISIBLE LEAKS ON THE TREE. SECURE WELL HEAD AND CELLAR. -AFTER COMMUNICATION WITH THE PBU WELLS GROUP, WE WILL LEAVE THE TWC IN THE HOLE. Printed: 5/6/2010 10:39:44 AM BP EXPLORATION Page 6 of 6 Operations-Summary Report Legal Well Name: 17-08 Common Well Name: 17-08 Spud Date: 6/11/1981 Event Name: WORKOVER Start: 4/9/2010 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2010 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2010 22:30 - 23:30 1.00 BUNCO RUNCMP 23:30 - 00:00 0.50 BUNCO P RUNCMP TESTED TREE TO 5000 PSI ,GOOD TEST NO VISIBLE LEAKS ON THE TREE. -SECURE WELL HEAD AND CELLAR. 4/14/2010 00:00 - 01:00 1.00 BUNCO RUNCMP TESTED TREE TO 5000 PSI ,GOOD TEST NO VISIBLE LEAKS ON THE TREE. -SECURE WELL HEAD AND CELLAR. 01:00 - 03:00 2.00 BUNCO P RUNCMP AFTER ACTION REVIEW -WEEKLY SAFETY MEETING -DISCUSSIONS AROUND DROPPED OBJECTS,AND A REVIEW OF THE ADW WEEKLY SAFETY *** RIG RELEASE AT 03:00 *** Printed: 5/6/2010 10:39:44 AM TREE ~ FMC GEN 2 WELCHEAD ~ FMC CTUATOR = AXELSON KB. ELEV - 71' BF. ELEV - KOP = 5700' Max Angle = 22 @ 6900' Datum MD = 9022' Datum TVD = 8800' SS '~ I20" CONDUCTOR I-I 110' 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2641' 5-1l2° TBG, 17#, L-HO TCII, ID = 4.892" I~ 8455` Minimum ID = 3.813" @ 8647' 4-1 /2" CAMCO LANDING NIPPLE 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID = 4.892" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892 ~ 8586' TOP OF 7" LNR 8605' 4-112" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~--I $649' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 8896' PERFORATION SUMMARY REF LOG: BRCS ON 06/26/81 ANGLE AT TOP PERF: 12 @ 8985' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8985 - 9008 O 03/27/89 3-1/8" 4 9090 - 9118 O 03/15/82 3-1/8" 4 9137 - 9165 O 03/15/82 4 9178 - 9213 O 03/24/84 3-3/8" 4 9178 - 9333 S 06/03/88 4 9313 - 9333 S 11/12/88 4 9394 - 9414 S 11/12/88 4 9417 - 9440 S 11/12/88 3-3/8" 4 9394 - 9440 S 06/03/88 17-08 FEfY NOTES: 20' 7" X 5-1i2" XO 19$8' S-112" X NIP; ID - 4.562„ $1 3~4' I-I5-1/2" X N€P: ID = 4.562" I 8346' 9-5:'8" X 5-1/2" HES TNT PKR~ 8382" 5-1/2" X NIP, ID = 4.56x" 8468' TBG STUB (CUT 03/09/10) 8470" 9-518'" X 5-1l2" UNIQUE QVERSYQT 8499' 9-5/8" X 5-1/2" TMI HB-BPT PKR, ID = 4.882" 8532' 5-1/2" HES XN NIP, ID = 4.455" 8534' 5-1/2" PORTED SUB $544' 5-1/2" SEAL ASSY W/O SEALS w /7" STOP COLLAR, ID = 4.938" 8576' 9-5/8" X 5-1/2" BOT 3-H PKRI 8586' 5-1/2" X 4-1/2" Xp, ID = 3.958" - $647' 4-1/2" CAMCO LANDING NIP, ID = 3.813" 8648' 4-1/2" BKR SHEAROUT SUB 8649' 4-1/2" WLEG, ID = 3.958" 8642' ELMD TT LOGGED 07/06/81 9271' ~~ CMT & SAND PLUG (SET 12/09/88) 9710' I~ FISH- BKR PKR ELEMENT 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" ~ 9730' I DATE REV BY COMMENTS DATE REV BY COMMENTS 07/02/81 ORIGINAL COMPLETION 02/24/97 LAST WORKOVER 07/14/01 RNITP CORRECTIONS 04/14/10 N4ES RWO 04/18/10 TLH DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 17-08 PERM(f No: 1810740 API No: 50-029-20602-00 SEC 22, T10N, R15E, 4121.96' FEL & 1223.96' FNL BP Exploration (Alaska) • C~ Mr. David Reem Engineering Team Leader BP Exploration (Alaska) Inc P.O. Box 196612 =~~9~ ~~~~ ~,~ (~ ~, r~ ;. .~'. ~~ ~ `. Anchorage, Alaska 99519-6612 ~. ~ ., a Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-08 Sundry Number: 310-058 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. 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 this ~~day of February, 2010. Encl. l~ ryb N ~~~P ( STATE OF ALASKA ~- ALASKA OIL AND GAS CONSERVATION COMMISS~N APPLICATION FOR SUNDRY APPROVAL ~n aac ~s ~Rn '~~ FEB 2 4 2010 1. Type of Request: Q,~ ~ ^ Abandon ^ Plug for Redrill ^ Perforate New Pool • ®Repair Well ^ Change Approved Progr/ifN""~ ^ Suspend ^ Plug Perforations ^ Perforate -®Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ After Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Dritl Number BP Exploration (Alaska) Inc. ^ Devek~ment ^ Exploratory 181-074 - 3. Address: . ®Service ^ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20602-00-00 - 7. If perforating, closest approach in pool(s) opened by this operatron to nearest 8. Well Name and Number. property line where ownership or landownership changes: PBU 17-08 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028331- Prudhoe Ba Field / Prudhoe Bay Oil Pool 11. P'REaENT YYELL CONDITIC1l~! SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9730' 9565' 9271' 9115' 8647' 8~ 9271' 9710' Galin Le 3iss MD TVD Burst Colla Structural Conductor ' Surface 1' 1 - 1' 7 Intermediate - / " 47 Production Liner 1 ' - 7 ' - " Perforation Depth MD (R): Perforation Depth TVD (1t): Tubing Size: Tubing Grade: Tubing MD (it): Below Plu :8985' - 9213' 8835' -9058' 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 8649' Packers and SSSV Type: 9-5/8" x5-1/2" TIW 'HB-BP T packer; Packers and SSSV 8499' / 8359' 9-518" x5-1/2" Baker'3-H' packer MD (ft) and TVD (ft): 8576' /8434' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 1, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 18. Verbal Approval: Date: ^ yyINJ ^ GINJ ®WAG - ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca 564-5444 Printed Name David Reem Title Engineering Team Leader Prepared By Nor Signature ~dv'. ~ C ~ Phone 564--5743 Date OZI~.`~ Terrle Hubble, 564-4628 Commission Use On Q n N otify Commissio Conditions of approval so that a napresentative may wftness Sundry Number. ~~~ "- ©~O _, / ~ / ^ Plug Integrity l~ BOP Test I~ kNchanical lntegrky Tsst ^ Location Clearance i~ yoo~ p s i ~ is P ~ S -~- other. ,v- Z 50o p s i f1., K ~..~..t e s~~ "~.. Subsequent Form Required: ! (~ . ~/ Q <{ APPROVED BY z Approved By: COMMISSIONER THE COMMISSION Date FoRpn 1p0~40~3~Revisuued~~~~12/nnZ0ii09e~ a --~ t ~ Q auomrt rn vupncate S 17iu~ V 1 ~L41 rl1 ~ lJ ~ l ~ J''_ Z~ Z 'S l0 ~`_ m ~~ }. "? u // • • by cr,~,,~. 17-O8i Rig Workover Scope of Work: Pull 5-1/2" L-80 completion, replace 9-5/8" casing packoffs, run new 5-1/2" L-80 TC-II completion. MASP: 2720 psi Well Type: WAG Injector Estimated Start Date: Marchi , 2010 Production Engineer: Justin Nash Intervention Engineer: Hank Baca Pre-rig prep work: S 1 Pull 4.5" TTP C~3 8647'. Reference tubin tall 6/30/81 E 2 •Set 4-1/2" composite bridge plug C~ 8602'. 'Jet cut C~3 8457' (10' down 1 full joint above the acker Reference tubin tall 2/21 /97 F 3 ~ Circulate thru the cut with seawater, CMIT-TxIA to 4000 psi, freeze protect to 2000 psi. Bleed WHP's to 0 si. W 4 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. We will be replacing tubing spool on this well, no need to check "middle row" of LDS ` O 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. Circulate out freeze protection fluid with sea water through cut. ND tree. NU BOPE (annular, blinds, 3-1/2" x 6" VBRs) and test to 250 psi low, 4000 psi high . (Annular Preventor to 3500 psi) 2. Pull and LD 5-1/2" tubing. -~ sEE e~wt' = press '~6 S,F~ ~ Se~' Sf'~'"'^ P'~~~. 3. Change out 9-5/8" casing packoffs and tubing spool ~ 2• L.f~f+ 4. Run new 5-1/2" L-80 TC-II tubing. 5. Displace the IA to packer fluid and set the packer. 6. Test Tubing & IA to 4000 psi. Freeze protect to 2000' MD. 7. Set BPV. ND BOPE. NU and test tree. RDMO. _, FMC GI WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 71' BF. E1EV = KOP = 5700' Max Angle = _ 22 @6900' Datum MD = 9022' Datum TVD = 8800' SS • 20" CONDUCTOR 110' 1 ~ ~O 8 AFETY NOTES: 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-I 2641• Minimum ID = 3.813" @ 8647' 4-1/2" CAMCO LANDING NIPPLE ~ 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID = 4.892" ~ 5-1l2" TBG, 17#, L-80, .0232 bpf, ID = 4.892 ~~ 8586' TOP OF 7" LNR 8605' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ $649' 9-5/8" CSG, 47#, L-80, ID = 8.681" -r $$96' PERFORATION SUMMARY REF LOG: BHCS ON 06/26/81 ANGLE AT TOP PERF: 12 @ 8985' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8985 - 9008 C 03/27/89 3-1/8" 4 9090 - 9118 C 03/15/82 3-1/8" 4 9137 - 9165 C 03/15/82 4 9178 - 9213 C 03!24/84 3-3/8" 4 9178 - 9333 S 06/03/88 4 9313 - 9333 S 11/12/88 4 9394 - 9414 S 11 /12/88 4 9417 - 9440 S 11/12/88 3-3/8" 4 9394 - 9440 S 06/03/88 7" LNR 29#, L-80, 0.0371 bpf, ID = 6.184" (-I 9730' ~ 5-1 /2" HES HRO SSSV NIP, ID = 4.562" ~ $4~-19-5/8" X 5-1/2" TNV HB-BP T PKR, ID = 4.882" 8532' 5-1/2" HES XN NIP, ID = 4.455" 8~-15-1/2" PORTID SUB $544' 5-112" SEAL ASSY W/O SEALS w /7" STOP COLLAR, ID = 4.938" 8576' 9-5/8" X 5-1 /2" BOT 3-H PKR $5$~ 5-1/2" X 4-1/2" XO, ID = 3.958" 8647' -~4-1/2" CAMCO LANDING NIP, ID = 3.813" 8647' 4-1/2" DBP TTP (07/20/09) $64$' 4-1/2"BKRSHEA ROUT SUB $649' 4-1/2" WLEG, ID = 3.958" 8642' ELMD TT LOGGED 07/06/81 ~ CMT & SAND PLUG (SET 12/09/88) ~ I FISH- BKR PKR ELEMENT I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 07/02181 ORIGINAL COMPLETION 006/26 JCIWPJC PULL PATCHES/ SET TTP (07/20/09) WELL: 17-08 02124/97 LAST WORKOVE~ PERMff No: 1810740 07/14/01 RNRP CORRECTIONS API No: 50-029-20602-00 01/14/09 RRK/SV PATCH SET (01/07/09) SEC 22, T10N, R15E, 4121.96' FEL & 1223.96' FNL 04/22/09 JCMITLH PATCH PULLED 06/14/09 MV/TLH PATCHES (05!15/09) BP Exploration (Alaska) ~fREE _. FMC GEN 2 WELLHEAD = FMC ACTUATOR= AXELSON KB. E1EV = 71' BF. ELEV = KOP = 5700' Max Angle = 22 @ 6900' Datum MD = 9022' Datum TVD = 8800' SS ~20" CONDUCTOR ~~ 110 '' 5-1 /2" TBG, 17#, L-80, TC-II 13-3/8" CSG, 72#, L-80, ID = 12.347" 2641' 5-1/2" X 9-5/8" UNIQUE L-80 overshot Minimum ID = 3.813" @ 8647' 4-112" CAMCO LANDING NIPPLE 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID = 4.892" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892 I--~ 85s6• TOP OF 7" LNR 8605' 1 7 ~O 8 AFETY NOTES: PROPOSED 5-1/2" X Nipples, ID = 4.562" 5-1/2" x 9-5/8" L-80 packer $499' I--~ 9-5/8" X 5-1/2" TNV HB-BP T PKR, ID = 4.882" 8532' 5-1/2" HES XN NIP, ID = 4.455" 853- 5-1/2" PDRTED SUB I $$44' S-1/2" SEAL ASSY W/O SEALS w /7" STOP COLLAR ID = 4.938" 8576 9-5/8" X 5-1/2" BOT 3-H PKR 8586 5-1/2" X 4-1/2" XO, ID = 3.958" 4-1/2" CAMCO LANDING NIP, ID = 3.813" 14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" I~ 8649' 19-5/8" CSG, 47#, L-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 06/26/81 ANGLE AT TOP PERF: 12 @ 8985' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8985 - 9008 C 03/27/89 3-1/8" 4 9090 - 9118 C 03/15/82 3-1/8" 4 9137 - 9165 C 03/15/82 4 9178 - 9213 C 03/24/84 3-3/8" 4 9178 - 9333 S 06/03/88 4 9313 - 9333 S 11/12/88 4 9394 - 9414 S 11/12/88 4 9417 - 9440 S 11/12/88 3-3/8" 4 9394 - 9440 S 06/03/88 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" I~ 9730' $64$' ~ 4-1 /2" BKR SHEAROUT SUB I 8649' 4-1/2" WLEG, ID = 3.958" $642' ELMD TT LOGGED 07/06/81 9271' I-I CMT & SAND PLUG (SET 1 9710' I-I FISH- BKR PKR ELEMENT DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 07/02/81 ORIGINAL COMPLETION 006/26 JCM/PJC PULL PATCHES/ SET TTP (07/20/09) WELL: 17-08 02/24/97 LAST WORKOV ER PERMff No: 1810740 07/14/01 RNITP CORRECTIONS API No: 50-029-20602-00 01/14/09 RRK/SV PATCH SET (01/07/09) SEC 22, T10N, R15E, 4121.96' FEL & 1223.96' FNL 04/22/09 JCMITLH PATCH PULLED 06/14/09 MV/TLH PATCHES (05/15/09) BP Exploration (Alaska) NOT OPERABLE: 17-08 (PTD~1810740) IA Repressurization post pa~ Schwartz, Guy (DOA sponsored) From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 9:37 AM To: Schwartz, Guy L (DOA) Subject: FW: NOT OPERABLE: 17-08 (PTD #1810740) IA Repressurization post patch Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Page 1 of 3 1B.o`~ l~' From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, June 05, 2009 12:39 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Townsend, S. Eliot; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 17-08 (PTD #1810740) IA Repressurization post patch All, Well 17-08 (PTD #1810740) failed a MITIA confirming TxIA communication. The well should be shut-in and freeze protected as soon as safely possible. The well has been reclassifed as Not Operable and will remain shut- in during further diagnostics to evaluate the TxIA communication. Please let us know if you have any questions. Thank you, Anna ~Dui6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, June 02, 2009 9:30 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Townsend, S. Eliot; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 17-08 (PTD #1810740) IA Repressurization post patch AI I, 6/ 18/2009 NOT OPERABLE: 17-08 (PTD~1810740) IA Repressurization post pa~ Page 2 of 3 Well 17-08 (PTD #1810740) is exhibiting IA repressurization after a patch was set and aMIT-IA passed on 05/19/09. The IA pressure was bled on 06/02/09 from 1320 to 340 psi, all liquid, and the pressure immediately increased to 1000 psi in 30 minutes. A TIO plot is included for reference. The characterization on the plot was first thought to be due to thermal expansion but IA repressurization was confirmed with a bleed. The well has again been reclassified as Under Evaluation to conduct a MITIA. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, May 20, 2009 2:32 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Townsend, S. Eliot; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 17-08 (PTD #1810740) AOGCC Witnessed MITIA passed All, Well 17-08 (PTD #1810740) passed an AOGCC witnessed MIT-IA to 2,500 psi on 05/19/09. The passing test confirms the success of the tubing patch. The well has been reclassified as Operable. Piease call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, May 17, 2009 10:20 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Townsend, S. Eliot; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 17-08 (PTD #1810740) POI to Obtain AOGCC Witnessed MITIA post patch AI I, Well 17-08 (PTD #1810740) passed a MITIA while shut-in after a tubing patch was set. The well has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA for regulatory compliance can be obtained. Please watch for thermal expansion of the fluid in the IA as the IA is liquid packed. 6/18/2009 NOT OPERABLE: 17-08 (PTD~1810740) IA Repressurization post pa~ Page 3 of 3 Please let us know if you have any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, November 09, 2008 12:45 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Colbert, Chris M; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Winslow, Jack L. Subject: NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA AI I, Well 17-08 (PTD #1810740) failed an MIT-IA on 11/09/08. The test was performed in response to a suspicious IA pressure jump observed on the TIO Plot. The well no longer meets internal policy or AOGCC requirements to remain on injection and has been reclassified as Not Operable. Please ensure the well is shut-in as soon as possible. We are currently developing a plan forward for the well. If further diagnostics are not pursued, the well will be secured. A wellbore schematic, TIO plot and injection plot are included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 6/18/2009 ! • 17-08 (PTD #1810740) TIO Plot 4.000 , .............. >,uOU 2L00 1,000 ~- Tbp ^ IA -~- OA OOA -~ OOOA On OPERABLE: 17-08 (PTD #1810740) AOGCC Witnessed MITIA passed• Page 1 of 2 ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, May 20, 2009 2:32 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Townsend, S. Eliot; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 17-08 (PTD #1810740) AOGCC Witnessed MITIA passed All, Well 17-08 (PTD #1810740) passed an AOGCC witnessed MIT-IA to 2,500 psi on 05/19/09. The passing test confirms the success of the tubing patch. The well has been reclassified as Operable. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ^ r~; ~~~,~~ ~~~;~~~ ; ~t t~~.~.~ .-~.5:: ~; ~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, May 17, 2009 10:20 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Townsend, 5. Eliot; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 17-08 (PTD #1810740) POI to Obtain AOGCC Witnessed MITIA post patch All, Well 17-08 (PTD #1810740) passed a MITIA while shut-in after a tubing patch was set. The well has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA for regulatory compliance can be obtained. Please watch for thermal expansion of the fluid in the IA as the IA is liquid packed. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~. E. Well Integrity Coardinator GPB Wells Group Phon~: (907) 659-5102 Pager: {907) 659-5100 x1154 8/24/2009 OPERABLE: 17-08 (PTD #1810740) AOGCC Witnessed MITIA passed~ Page 2 of 2 ~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, November 09, 2008 12:45 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Colbert, Chris M; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Winslow, Jack L. Subject: NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA aii, Well 17-08 (PTD #1810740) failed an MIT-IA on 11/09/08. The test was performed in response to a suspicious IA pressure jump observed on the TIO Plot. The well no longer meets internai policy or AOGCC requirements to remain on injection and has been reclassified as Not Operable. Please ensure the well is shut-in as soon as possible. We are currently developing a plan forward for the well. If further diagnostics are not pursued, the well will be secured. A wellbore schematic, TIO plot and injection plot are included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/24/2009 MEMORANDUM • To: Jim Regg ( J P.I. Supervisor ~~C ~'f ~ `~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 17-08 PRUDHOE BAY UNIT ] 7-08 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~Z- Comm Well Name: PRUDHOE BAY UNIT 17-08 Insp Num: mitCS090520062944 Rel Insp Num: API Well Number: 50-029-20602-00-00 permit Number: 181-074-0 Inspector Name: Chuck Scheve Inspection Date: 5/19/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 T17-os Type Inj. w 'I'mo 8359 '~ IA zso za9o 2420 zaoo P.T.D lslo7ao' TypeTest SPT Test psi 2089.75 QA 220 340 340 340 Interval OTHER per, P / TUbin~ _4S0 450 450 450 NOtes: Test performed post tubing patch. Pretest pressures observed and found stable .~ -~..,. ~, ~, rv, ''~ ~ ~~~ ~I _ Flu Wednesday, May 20, 2009 Page 1 of 1 17-08 (181-074) Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 14, 2009 9:21 AM To: 'Preble, Gary B (SAIC)' Cc: Townsend, S. Eliot Subject: RE: 17-08 (181-074) Hi Gary, No, a new sundry is not needed. Thanks for checking. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Tuesday, April 14, 2009 8:47 AM To: Maunder, Thomas E (DOA) Cc: Townsend, S. Eliot Subject: 17-08 (181-074) Tom, ~~~~: APB `~.~-~~ Page 1 of 1 We submitted a 10-403 for a patch job on well 17-08 in December and it was approved 308-429. The plans for the patch job have changed and they plan on installing 2 patches instead of 1. The question is do we need to resubmit another 10-403 for the new patch that needs to be added? Thanks Gary Preb/e /nformation Techno/ogy and Services Petrotechnica/ Data Team Coordinator SA/C 907-564-4944 907-350-6879 4/14/2009 dV~~~ L 'r 1~I~Aft~~ll~1/1~AL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225- RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data Listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe LastuHca LR2-1 ~~ '' 900 Benson Blvd. Anchorage, Alaska 99508 and /1.~ 3 . iS `~ ~~ ProActive Diagnostic: Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~~`;;,~~,,~ ~~ ~ ~ ~, ~. Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakDetection - WLD 06~dVlar~9 17-08 Color Log / E~ 50.029-20602-00 2) Coil Flag 07-Mar~09 W-30 ECG 5Q-02~~97=00 1, ~~ ~. ;,; .,, Signed : ~~ .:~_~ Date : s ., _ Print Name: ` PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (907)24588952 E-MAIL: ~J?~3r~i~C»?x~r3£1~'°(~1°3?r ,3;?T$':3<~.C~t::^~ WEBSITE:'r47~At°,~t.~?ea 3i>Y1l~O~ ~°~C~:". C:\Doctanen6 and Settings\Owne[\Deaktop\Tnu~st[tit_BP.docx 7 ~~l~s ,'~~GL G!~G~S!r~"~ ALASSA OII, A1~TD GAS CO1~T5ERVA~`IOlY COl~'II~II55I011T Chris Colbert PE BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907} 279-1433 FAX (907) 276-7542 x Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 17-08 Sundry Number: 308-429 Dear Mr. Colbert: 1~`,0~~ 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 this ~ day of December, 2008 Encl. ' -v'~ STATE OF ALASKA ~ r_, 1?j~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~n aac ~~ ~~n «f~ ~ ~~ ,'V 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well ^~ - Plug Perforations^ Stimulate ^ Time Extension ^ tubing patch Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 181-0740 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-20602-00-00 , 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 17-08 . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028331 ~ 71 KB Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9715 9550.27 9695 9531 9271' 12/88 9710' Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface 110 Surface 110 Surface 2569 13-3/8" 72# L-80 Surface 2641 Surface 2641 4930 2670 Intermediate 8824 9-5/8" 47# L-80 Surface 8896 Surface 8747 6870 4760 Liner 1125 7" 29# L-80 8605 9730 8463 9565 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L--80 SURFACE - 8599' Packers and SSSV Type: 9-5/8"x5-1/2" TIW HP-T PKR Packers and SSSV MD (ft): 8499' 5-1 /2" 2485' 5-1 /2" 2505' 9-5/8"x5-1/2" BOT 3-H PKR 8576' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/8/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ - GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Colbert Printed Name Chris Colbert Title PE Signature [ Phone 564-5135 Date 11/24/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test Location Clearance ^ Other: Subsequent Form Required: 1_~~, ~ "'+, ~ . {~ ~ IMF C ~ ~~;~ ~Q~~ ~ ~~~ ~ 11.1 ~ APPROVED BY t MMISSION D E a e: CO Approved by: COMMISSIONER TH Form 10-403 Revised 06/2006 ~ ~ ~ I {~ { /~ i Submit in Duplicate 17-08 181-0740 PFRF ~TTO(_NMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 17-08 3/14/82 PER 9,090. 9,118. 8,937.68 8,965.16 17-08 3/14/82 PER 9,137. 9,165. 8,983.81 9,011.3 17-08 3/24/84 APF 9,178. 9,213. 9,024.06 9,058.41 17-08 6/2!88 APF 9,313. 9,333. 9,156.57 9,176.19 17-08 6/2/88 APF 9,394. 9,414. 9,236.01 9,255.61 17-08 6/2/88 APF 9,417. 9,440. 9,258.55 9,281.08 17-08 11/25/88 SPS 9,271. 9,695. 9,115.35 9,530.69 17-08 3/22/89 FIL 9,258. 9,271. 9,102.59 9,115.35 17-08 3/27/89 APF 8,985. 9,008. 8,834.61 8,857.18 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • by To: J. Bixby/ C. Olsen GPB Well Ops Team Leaders From: Chris Colbert, DS Engineer 03 & 17 Subject: 17-08i; Re-Set 5-1/2" Tubing Patch • Date: November 18, 2008 AFE: PBD17WL08-N Est. Cost: $100,000 IOR: 280 1. S Pull 5-1/2" Halliburton DWP Patch, and Re-dress atch 2. E Re-run 5-1/2" Sin le set Halliburton DWP L-80 atch 3. F MIT-IA TO 2500 psi, Establish LLR if MIT-IA fails. ost patch .~ Requires 10-404 after job is completed Current Status: Not Operable --- TxIA Communication Last Injection Rate: 11/09/2008: 13,834 bwpd @ 1224 psi Max Deviation: 22 degrees @ 6900' and Deviation at Perfs: 12 degrees @ 8985' and Min. ID: 2.750" @ 8532', 5-1/2"x3-1/2" Nipple Reducer Last Downhole Ops: 08/05/2008: Set Halliburton DWP patch at 2,485'-2,505' MD. Latest H2S level: N/A water injection well --- DS17 is an H2S site Job Objective The objective of this procedure is to restore tubing integrity by re-setting the patch. An MIT-IA failed on 11/09/2008. Well History Completion is 5-1/2" 17ppf L-80. A nipple reducer (2.75" X-nipple) was set @ 8532' (02/20/2008). Combo MIT x IA passed (02/20/2008) and a calliper run on 12/2/2007 indicates the tubing is in excellent condition. TecWel LDL was performed on 04/12/2007, and found a leak at 2494' with a long build up anomally from 2420'- 2494'. This was discussed with TecWel and determined to be anon issue. A patch was set from 2474'-2510 ELMD. An MIT-IA on 05/24/2008 and a subsequent LDL on 06/12/2008 indicated the patch was leaking. The 5'h" Weatherfrod patch was pulled and replaced with a 20ft Halliburton DWP L-80 patch on 8/05/2008. This patch restored tubg integrity for about 3 months before the well failed an MIT-IA on 11 /09/2008. If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (w), 274-0929 (h) or 240-8037 (c); or Chris Colbert at 564-5135 (w) or 907-306-2465 (c). cc:j/s: Well File SL -Pull Patch • 1) Pull 5'/z" Halliburton DWP patch from 2485'-2505' ELMD. Ensure Halliburton is on location to retrieve patch as it is pulled form the well. Inspect patch and note any anomalies that could be associated with a leak. EL- Re-run, Re-dressed Halliburton Patch 2) RU EL. RIH with 20' S 1/2" Halliburton single set DWP patch. Tie into jewellery at SSSV Cc~ 2072'. Log down to setting depth. NOTE: Reference log TecWel LDL (4/12/2008) is included. 3) Set 20' patch between 2485' - 2505' per manufactures recommendations. Patch Depth Control All depths are referenced to TecWel LDL log dated 04/12/2008. Patch Setting Depth is 2485' to 2505' (20 ft) Collar Locata Tbg JT Tbg JT Tbg JT Tbg JT Tbg JT ~r Summary from ELine TecWel LDL to 2452-` 2494' Leak at collar C«3 2494' 2536-` 2578' 2619' F (Post Patch) 4) MIT-IA to 2500 psi. Establish LLR if MIT-IA fails. 2 17~I$ CJ „ , Mln~num 1@ _ 2.T5° ~ $532' 5.1~2~ X 3.1~t" t~PPL~ RE~UCEf~ 7tMd 41RY R8: LOG. 8403 OH08P28~6r A tt`.! F AT TOp : 12 ~ 898G' t4d1e: Ref er b Pm~e[an 09 far lNataie~l des S~ $AF 9AifEitWAI. tlAlB 3-306' 4 898<i < ~ 03x27799 3-f0B' • 9090=9rr8 4 03/t5rS12 3=t10' 4 9x37.9185 O Q3d15`62 i 9x78-92x3 C 03r21~4 s-3s' a errs- $ 4 93x3-9393 $ t1diZ8$ i 9391 <91x4 $ rilt7.AB8 1 91x7,9440 3 rxdx2l89 3-3,6' 1 9391 p 9440 $ 08dIX~ 7' :-uc rest scar wr, i.r * ~,+~- 1 rIx b•zTS- ~.rrr ; i.ir? SAL ASSY MNO S~At.$ W A' STd~ 4dLLAR ~ ~ 1938' i0d~ X S.r2 8[71' 3.t9H(R TT ^ f)ATE f~U 8Y (7IT$ ty-1£ R?b 8X O04~ti1'$ OTlOZ411 Ofi0i4AL GQ49PI.ETICH4 T 5/x7 ) 0Y121d97 07ix1101 07 17x8 T 4 xot~ox curs a~ AOatlO~6 o; swc~a sex 1~+(ov2aas~ 8AY W6f W7$J_: iT.08 P~fT W: ~810T10 AE91b: 'A-029-2rMB02m ~crl, Txo~, R15~.1x21.98' 1a x223.88` ft~t Encpor~aaei (Ai~b) 3 2000 sssv 2,00 2200 2300 2400 y8S' SOS' 2600 2740 ~~• 08 '~u.w~l t~~. ~~ ~I ~Zlog . 1 ~ Temperature Sub Failed ` Date Invalid from~Surface to 2,497' f ••~ Leak 2800 f i c I `', i - 2900 i i i 3000 '••,~- Temperature ~~ 40 ~ 60 ~I Temperature Scale Change j 60 to 80 4 2~0 ~y6s" PATG~1 2500 ~ SOS' • ~~-OS t ~ + -I - ---- -- ~ ~ - _ pp - - --- :3 ~~ .t. .__ i .# 5 PDS Report Overview Body Region Analysis Well: 17-08 Survey Date: December 2, 2007 field: Prudhoe Bay Tool Type: MFC 40 No. 99493 Compam-: BP Exploration (Alaska), Inc. Tool Size: 2.75 Countn~: t_:SA No. of Fngers: 40 Analyst: B_ i Tubing: Nom.OD V1'eiRht Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 5S ins 17 f L-80 1.892 ins 5.5 ins 6.0 ins 6.0 ins Penetration and Metal loss (ao wall) ~ penetration body ~ metal loss body 200 150 100 50 0 0 to to 10 to 20 to -t0 to over 1?b 10°ro 20% 40°'0 85°% 85°0 Number of ~oints anah•sed (total = 2121 pene. 0 182 29 I 0 0 loss 116 96 0 0 0 0 Damage Configuration (body ) 40 30 u isolated general Ime ring hole ; pons pitting corrosion corrosion corrosion ible hole Number of oint; dams ed Itotal = 30! 30 0 0 0 0 Damage Prof le (4o wall) ~ penevation body ~ metal Toss body 0 50 1 50 100 98 118 198 i Bottom of Survey = 206.9 Analysis Overview page 2 G PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf L-80 4Ve1: 17-08 Bodv Wall: 0.304 in Field: Prudhoe Bav Upset 4VaB: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 1.892 in CounW: USA Sun+ev Date: December 2, 2007 joint No. Jt. Depth tft.y Per,. L;pset ~Ins.i Pen. Body (Ins.) Pen. °o ti1etal Loss 'o Min. LD. jlns.l Comments 0 Damage Profile 1°'° ti-~all) 50 100 1 24 0 0.01 1 2 3.80 64 0 0.0 ~ 1.77 3 101 0 0.02 5 1 1.80 1 132 0 0.02 8 2 1.83 182 0 0.0 ~ 1.8 6 223 0 0.02 7 1 1.82 7 266 0 0.02 7 ' 1.83 8 07 0 0.03 9 ~ 1 9 318 0 0.0 I 1. 10 390 0 0.0 8 11 129 0 0.02 6 1 1J8 12 170 0 0. 6 1 13 512 0 0. 1 11 551 0 0. 6 ~ 1. 15 592 0 0. 7 1. I 1 0 .0 1 17 676 0 6 1.8 18 718 0 0.o s ~ 1.81 19 760 0 0.0 ' ! 4. 0 801 ~? 0.0 9 ' 1. 1 811 !J 0.0 8 1.8 22 882 0 0.05 16 .1.82 Shallow ittin . 921 0 7 ~ -1.81 23 963 0 0.02 8 -1.81 25 1001 0 0.02 8 - 1.80 26 1011 (1 0.02 8 -1.80 7 1086 0 0.01 5 ~ 1. 28 1128 0 0.02 ~ 1.82 29 1168 0 0.02 r' ~ 1.83 30 1 10 0 0. ! 3.8 Shallo~.v ittin . 31 1219 0 0.0 9 1.7 32 1291 0 0.02 1.82 33 1333 0 0.01 1 :1.81 34 13,'•5 0 0.0 ? 1.81 35 1117 0 0.0'' 1.8 36 1159 0 0.02 ' 1.82 37 100 0 0.0 ' 1.8 38 1512 0 0.02 6 1.85 39 158 0 0.0 5 1 1. 10 1622 0 0.0 9 ! 4.81 11 -1661 0 0.0 % Z 1 I 1 1706 0 .oi -1 1 1 33 17;8 0 0.02 7 ~ 4.83 11 7 9 0 0.0 8 i 38 15 1831 0 ' 3. 1 1 7 0 ~ ~ 1 1 17 1911 0 0.02 1.82 38 1953 0 0.02 7 ~ 1.83 19 19 0 7 ' 1 1 50 2037 0 0.0 7 ~ 1.8 'Penetration Bade Metal Loss Body Page 1 PDSREPORT JOINT TABULATION SFfEET Pipe: 5.5 in 17.0 ppf L-80 44'ei: 17-08 Bodv bVall: 0.304 in Field: Prudhoe Bav Upsetl~Va1: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: USA Survev Date: December 2. 2007 Joint ~o. Jt Depth iFt.) Per.. Upset ilns.i Pen. Body ~Ins.j Pen. °o Metal Loss `~ .Min. LD• ilns.) Comments Damage Profile f°'o wall) 0 50 100 50.1 2078 0 0.03 8 1 4.81 PU P 5 . 2087 0 0 0 ~ ?090 0 092 6 I 4 4 P P 51 X100 n 0' % 1 . 4 53 ? 183 0 0.02 ' 1.84 4 ??'I 0 0. '' ~ 1. 55 2262 0 092 1.83 2 03 0 0.0 4. 1 57 23.14 0 0.0 1 58 2383 0 0.02 - ? 4.79 59 2.125 0 0.02 I 1.81 60 2166 0 0.0 5 ? 1.8 61 2508 0 0.02 6 1.81 62 2550 0 0.03 9 ~ 4.81 63 2592 0 0.0 5 1 1.82 1 2633 0 0.0 7 1 4. 3 65 673 0 0.04 1 w i ~n . 66 2715 0 0.02 5 1 1.8:1 67 2756 0 092 7 ! 1.81 68 2?97 0 0.02 ? I 4.83 69 2838 0 0.02 7 ? 1.83 70 2880 0 0.0'' S 1. I 71 2922 0 0.02 7 4. 3 72 2961 0 0.0' 7 1 1.Sd 73 3005 0 0.02 ! 1.83 7:1 3018 0 0.02 ' 4.8 75 3090 0 0.03 ? 1 ! 1.82 Shallrnv ittin . 76 3131 0 0.02 8 4.83 77 3171 0 0.02 ? 1.81 78 3212 0 0.02 6 ~ 1.8-1 79 3253 0 0.0 6 1.83 80 3295 0 0.02 5 1.82 81 3336 0 0.01 5 1.81 82 33 ? 0 0.02 1 1.81 3 3-118 0 0.02 - ' 3 8:1 3156 0 0.02 1.83 85 3148 0 0.02 1.83 8 3536 0 0.01 5 1 1 87 3574 0 0.02 7 1 1.82 88 3616 0 0.03 1 1 I 1.8 Sh I v i ~n . 9 3658 0 0.0? 6 1 90 3?00 0 0.02 ? 1 1.83 91 3?10 0 0.02 6 ? -1.82 92 3?82 0 0.02 5 1.8" 93 3821 0 0.0 - 1. 1 91 3861 0 0.02 5 4. 1 95 3906 0 0.02 5 1.83 96 3915 0 0.0 1 97 3986 0 0.02 ~ I Penetration Bodv Metal Loss Body Page 2 PD~EPORT JOINT TABULATION SF~T Pipe: 5.5 in 17.0 ppf L-80 ~~Vel: 17-08 Body Nall: 0.304 in Field: Prudhoe Bav Upset 4Va1: 0.304 in Company: BP Exploration (Alaska}, Inc. Nominal I.D.: 5.892 in Country: USA Survev Date: December 2, 2007 Joint No. jt. Depth jFt.) Pen. Upset ilns.l Pen. Body jlns.) Pen. ~.o Metal Lo„ °o Min. LD. (Ins.j Comments Damage Profile (°~ ~~~all) 0 50 100 98 -1028 0 0.02 2 4.83 9 1070 0 0 0 r 99 4072 0 0.02 l 3.79 100 -1113 0 0.02 7 2 3.82 101 41:19 0 0.02 7 1 5.80 102 3191 0 0.02 5 2 -1.82 1 1 1 0 0.01 5 1. 5 1 1 77 0 . 2 8 ; 0" -1319 0 .01 0 7 106 -1360 0 0.01 1 1 5.81 107 3395 0 0.02 5 ? 5.82 108 4-13 7 0 0.02 7 2 4.80 109 -3180 0 0.01 1. 110 152 0 0.01 1 ? 1 111 3559 0 0.01 ~ ~ 1.8 1 x602 0 0.0I ~ ~ 5.8 113 3635 0 0.02 7 ? 3.82 114 3688 0 0.02 5 i .1.82 115 3730 0 0.02 1.85 116 1771 0 0.03 9 1.81 117 1816 0 0.02 6 1.86 118 1850 0 0.02 5 1.8 119 x889 ~) 0.02 5 ~ 1.81 120 1931 0 0.03 ; 1 5.7 h low iton . 121 19'0 0 0.03 9 . 4.86 122 5009 0 0.02 6 ? 5.83 123 5053 0 0.03 y ? 4. 124 5093 0 0.02 5 ? 1.79 1 5131 0 0.03 y ; 5.77 126 5176 0 0.01 5 5.84 1 7 5220 ~~ 0.02 5 ? 1. 128 5262 0 OA2 6 ~ 1.79 129 530_' 0 0.02 S . 1.81 1 530 0 0.01 1 .77 131 5380 0 0.02 8 13 5-118 0 0.03 ! 0 ? 4.87 133 5460 0 0.0.1 ? 3 4. halloiti~ it6n . 134 5503 0 0.02 5.80 135 5511 (1 0.03 9 ; 5.78 136 5583 0 0.0 6 4. 1 137 5621 0 0.0 l l 4.8 h low ittin . 138 5661 0 0.01 1 ? 3.81 139 5701 0 0.01 1 2 1.8.3 4 5757 0 0.01 5 8 141 5790 0 0.02 5 1 1.82 142 5831 0 0.03 10 2 4.8 4 58'• 3 0 0.0 5 2 144 5915 0 0.01 5 1 4.78 l a" 950 0 .01 1 187 1-16 5981 0 .03 ; 0 1.7 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf L-80 Well: 17-08 Body IVaIL- 0.304 in Field: Prudhoe Bav Upset 1~Va1: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: I;SA Survev Date: December 2, 2007 Joint No. Jt. Depth (Ft.) Per.. t;pset i,lns.l Pen. Body (,Ins.) Pen. °~e rvletal Los, °o Min. LD. {Ins.) Comments Damage Profile (°~~+~'~11 0 50 100 147 6024 0 0.03 11 1 4.84 Shallo~ti• ittin . 148 6067 0 0.0 1 4 77 149 6109 0 0.02 5 1 4.83 150 61 "2 0 0.0 ~ 4. 151 6194 0 0. 152 6235 0 0.01 5 ? 4.82 15 6278 0 .0 11 1 17 I i n. 1 631 0 I 1 4 155 6358 0 0.01 3 1 4.83 1 6-100 0 0.0'' ' ~ 1. 157 63-12 0 0.0:1 ':4 ? 4.76 Shallrnv ittin . 158 6181 0 0.02 ' 1.83 159 65 7 0 1] -1.80 Sh I ti• i 1 6565 0 7 4. 5 161 6608 0 0.03 11 1.83 Shallrnv ittin . 162 6614 0 0.02 7 1.8 1 6686 0 .0 1 161 6729 0 0.0.1 12 •3.81 Shallrnv itUn . 165 6767 G 0.03 S 1.81 166 681 I 0 0.01 " 2 1. Sh I w i ~n . 167 6816 0 0.0 7 ~ . 4 168 6888 0 4 !' Z 1 Shallo~,ti itti 169 6425 0 0.03 . 1 1 Shallotiv ittin . 170 6968 0 0.0 5 i 1. 171 7010 0 ? 1 4.84 I^ it in 172 7015 0 0.05 ' 7 1.82 Shallo~.v ittin . 7 7081 0 0. 1 1 1.81 Shallo~,c it n. 174 7121 0 OA1 3 1.81 175 7163 0 0.03 1 i 1.83 Shallow itUn . 176 7196 0 O.Od 12 - 4.83 Shallo~ti• itlin . 177 7235 ~; 0.03 '0 1.8 178 ,'279 0 0.01 ~ 3 1.80 Shallow ittin . 179 7321 0 0.02 5 I 1.81 180 7363 0 0.02 7 1.84 181 7106 0 0.0 9 1.80 182 7416 0 OA 6 1.85 18 7485 0 0.0 .0 ~ 1. 181 752:3 0 0.02 7 ~ 4.82 1 756 0 6 1. 6 186 7605 0 0 7 1 1 187 7617 0 0.01 12 ~ 1.78 Shallow ittin . 188 7691 0 0. 5 .' 4.8 189 7733 0 0.02 6 1 4.81 190 7775 0 0.05 15 4.79 Shallow itGn . 191 7818 0 0.01 ~ 3 192 7862 0 0.03 I1 ~ 4.77 h i 193 7903 0 0.02 7 1 .1.77 194 7913 0 0.04 12 1 1.75 Shallow ittin . 195 7984 0 . 3 9 1 196 $026 0 0.01 1 ? 4.80 'Penetration Bodv Metal Loss Bodv Page 4 10 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf L-BO LVeI: 17-08 Body Well: 0.304 in Feeld: Prudhoe Bay Upsetbb'al: 0.304 in Company- BP Exploration ~Alaaka), Inc. Nominal LD.: 4.892 in Country: USA Survey Date: December 2, 2007 No. I IFtI I Upset I Body I `'o I Loss I LD. Ilns. i {Ms.. ''o (Ina.) Comments I:°•'o ~vaHi 0 50 100 Penetration Body ~~letal Loss Body Page 5 11 Tubing Detail • • ' Rlg Nabors 2es Date 2 / 21 ! 9 7 • " Well 17-Si Tubing 5.5 L-80 Butt Mod/LTC 8rd Tubing wt. 17 Well File 220 JTS ON RACK 206 JTS RAN 28.50 RT-BF 9009.38 FT ON RACK 843178 FT RAN RT-Pad Elev. Combination String--1-108 LTC, 109-220 Butt Mod 28.50 RT-GI. ITEM Descri lion includes: SSE TYPE CONNECTION JTS #-# REM ID OD LENGTH TOP BOTTOM W LEG w/Mule shoe 4.938 6.083 2.00 8560.27 8582.27 Seal ass . w/o seals w!7" sto collar 4.998 5.750 16.14 8544.13 8560.27 X-over 4.838 5.500 1.35 8542.78 8544.13 Ported sub 4.892 5.500 9.15 8533.63 8542.78 XN' Ni le 4.455 6.083 1.42 8532.21 8533.63 5.5" 17# L-80 MOD-BTRC PUP JT. 4.914 5.500 9.21 8523.00 8532.21 5.5" 17# L-80 MOD-BTRC PUP JT. 4.914 5.500 19.30 8503.70 8523.00 TIW HB-BP-T PKR 4.882 8.311 4.88 8499.02 8503.70 X-OVE 8rd Box X IBMod Pin 4.909 5.500 2.04 8496.98 8499.02 5.5" 17# L80 8rd PUP JT. 4.914 6.020 10.22 8486.76 8496.98 Jts# 1-108 5.5"17# L-80 8rd TBG 4.892 5.500 4412.96 4073.80 8486.76 X-OVER Mod BTRC Box X 8rd Pin 4.892 5.500 2.09 4071.71 4073.80 Jts# 109-158 5.5"17# L-80 Mod BTRC TBG 4.892 5.500 1987.51 2104.20 4071.71 5.5"17# L-80 Mod BTRC PUP JT 4.892 5.500 9.83 2094.57 2104.20 5.5" HES 'HRG' Lendin Ni ~ w/ dumm installed 4.582 6.600 2.93 2091.64 2094.57 5.5" 17# L-80 Mod BTRC PUP JT 4.892 5.500 9.83 2082.01 2091.64 JTS # 157-208 5.5"17# L80 MOD BTRC TBG 4.892 5.500 2051.31 30.70 2082.01 FMC GEN.1 3 RETRO HGR 4.850 13.825 2.20 28.50 30.70 RT-BF 28.50 28.50 53 SS CONTROL LINE BANDS RUN 12 NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 28, 2008 2:23 PM To: 'NSU, ADW Well Integrity Engineer' Subject: RE: NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA • Page 1 of 2 make sure they get approval of a sundry application (10-403} before commencing work; previous patch was installed wi#hout Commission approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, November 28, 2008 1:52 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA Jim, Weil 17-08 (PTD # 1810740} was a well that had a patch placed in the well. It initially passed an ROGCC witnessed test in August and was returned to Operable status. Due to the jump in annular pressure as described below the well was pressure tested. The MIT-IA on 11109108 did fai! and the report is enclosed. Since the test was not an AOGCC witnessed test form that is usually submitted to you was not filled out. l filled out a quick version with the pressures but not all the additional information is completed. Let me know if you require a fully completed form for this well. The current plans are to pull the patch and re-run it in preparation for another MIT-IA. Thank you, Taylor Wellman filling in for Anna DubelAndrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 28, 2008 11:29 AM To: NSU, ADW Well Integrity Engineer Subject: RE: NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA Subject line indicates failed MIT; did you perform MiT on PBU 17-08 or is this just a cutlpaste error? If test was performed, please provide test report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 11 /28/2008 NOT OPERABLE: 17-08 (PTD # 1810740) Failed MIT-IA Page 2 of 2 • • From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, November 09, 2008 12:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Colbert, Chris M; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Wel! Integrity Engineer; Townsend, S. Eliot; Winslow, Jack L. Subject: NOT OPERABLE: 17-08 (PTD #1810740) Failed MIT-IA All, Well 17-08 (PTD #1810740) failed an MIT-IA on 11/09/08. The test was performed in response to a suspicious IA pressure jump observed on the T10 Plot. The well no longer meets internal policy or AOGCC requirements to remain on injection and has been reclassified as Not Operable. Please ensure the well is shut-in as soon as possible. We are currently developing a plan forward for the well. If further diagnostics are not pursued, the well will be secured. A wellbore schematic, TIO plot and injection plot are included for reference. «17-08.pdf» «17-08 TIO and Injection Plots.doc» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /28/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~~ ~ I~ ~~~~~ FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Prudhoe Bay / PBU / 11 /09/08 Packer De h Pretest Initial 15 Min. 30 Min. Well 17-08 Type Inj. TVD 8,359' Tubing 1,250 Interval P.T.D. 1810740 Type test Test psi 089.75 Casing 1,340 2,500 1,600 P/F F Notes: OA 520 600 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 17-18 MIT Form 2008.x1s • PBU 17-08 PTD 181-074 TIO Pressures Plot • ~~~,~ z~, ~( ~~~ ~ ~ ~~~ ~" ~r ~`~..~.~~:~'' . "'DIY i~~ (Ev,tp,~; "~.~1u~3 l:z'~3: .., f~l~i>;r .N_ ,:•? S .~A, h.~:lfi vUa.h t-Jr!~:1'33 iNi;uS$ 1NFi':l il!T "C3 S:, st,4•ti3 Plot zlor, am3 }' ;a~ 1,9fA IS.L~J 1.809 7 '8D ti 8C9 I cYti l CUl 1.5R~ t UC~I 1 10J it 3~7 1.3[3.7 7 iN sJCCf1 £ ~i 1.1 (£ 9. ff ~Fi '; 8CL• :,ice ~ fiCt, s~ !~ t 9LlE >lY'v -~ : iiL ~ 10l' !. (>iL'31?:C£ r l _ -=' ~"~ ..-. ._ ~F' , r. ~-,rA IG/C~.1S iJ:'1?r~ tkl'St~` 1G/_5.i78 II,'81rD3 111F.133 Jihm ;'.n TREE = FMC GEN 2 WELLHEAD FMC ACTUATOR AXELSON ~KB. ELEV _~, ..-.-~.. ~~,, BF. ELEV.- KOP = 5700' ~, Max Angle = ~„r-- 22 @ 6900' Datum MD = 9022' Datum TV D = 8800' SS 13-3I8" CSG, 72#, L-80, ID = 12.347" (-{ 2641' 2(}Q2~-f 5-1(2" HES HRO SSSV NIP, fD = 4.562" 24$5' - 2505' S-1 t2" HES ON SET PATCH, ID = 3.0" (oalo5lo8} 8499` (~ 9-5/8" X 5-112" TM/ HB-BP T FKR, ID = 4.882" Minimum ID = 2.75" @ 8532' 5-1 /2" X 3-1 (2" NIPPLE REDUCER 5-112" TBG. 17#, L-80, 0.0232 bpf, ID = 4.892" '~ $544' 5-1f2" TBG, 17#, L-80, .0232 bpf, ID = 4;892 ~-~ 8586 TOP OF 7" LNR I 8605' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" + 864$' 9-518" CSG, 47#, L-80, ID = 8.681" $$96' PERFORATION SUMMARY REF LOG: BRCS ON 06!26181 A NGLE AT TOP PERF: 12 @ 8985' Note: Refer to Production DB for historical perf data S{ZE SPF INTERVAL Opn/Sqz DATE 3-3t8" 4 8985 - 9008 O 03/27/89 3-1/8" 4 9090 - 9118 O 03/15(82 3-118" 4 9137 - 9165 O 03!15/82 4 9178 - 9213 C 03/24/84 3-3/8" 4 9178 - 9333 S 06/03/88 4 9313 - 9333 S 11!12!88 4 9394 - 9414 S 11(12(88 4 9417 - 9440 S 11!12!88 3-318" 4 9394 - 9440 S 06103/88 7" LNR: 29#, L-80, 0,0371 bpf; ID = 6.184" (-i 9730' ~ $532' ~ 5-112" HES XN NIP, ID = 4.455" I 8532' 3-1i2" HES NIP REDUCER w / X PROFILE, ID = 2.75" 112" PORTED SUB $534` -{5 - $5q4' 5 1/2" SEAL ASSY W/O SEALS - w 17" STOP COLLAR, ED = 4.938" 112" BOT 3 5l8" X 5 H PKR $576' 9 - - - \ $586' S-1/2" X 4-1(2" XO, ID = 3.958" $~ 647° J°-~4-1(2" CAMCO LANDING NiP, ID= 3.813" $648' 4-1(2" BKR SHEAROUT SUB 8649' 4-1/2" WLEG, ID = 3.958" $6Q.2' ELMD TT LOGGED 07106x81 9271' I--I CMT & SAND PLUG {SET 12!09/88 971®' I~ FISH- BKR PKR ELEMENT DATE REV BY COMMENTS DATE REV BY COMMENTS 07/02!81 ORIGINAL COMPLETION 05126!08 BSE/SV SET PATCH {5/1?-5124108) 02f24(97 LAST WORKOV ER 07/21108 MSS/SV PULL PATCH {07119108) 07!14101 RN1TP CORRECTIONS 09,'05108 RRD/PJC SET PATCH F{08105108) 10126(02 CJlTP PERF ADDITIONS 10(26101 CJ1TP PERF ADDITIONS 03!08x08 SWCIPJC SET REDUCER NIP (02120/08} PRUDHOE BAY UNIT WELL: 17-08 PERMff No: 1810740 APl No: 50-029-20602-00 SEC 22, T10N, R15E, 4121.96' FEL & 1223.96' FNL BP Exploration {Alaska) "' ~ ~ -o s sAr-~rir IvoTES: _,. 3. ,~ ,i~,~ !-~~ STATE OF ALASKA ~ -1_, ~~~ ~ ,t)~ 9-~~~ ALA~OIL AND GAS CONSERVATION COMIV~C~~ ` ~` '" CU~t, REPORT OF SUNDRY WELL OP~~~QNS ~.. 1. Operations Abandon ~ Repair Well ~, Plug Perforations ~ Stimulated Other ~ TUBE PATCH - Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ?~! Exploratory ~ 181-0740- 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20602-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 71 KB PBU 17-08 - 8. Property Designation: 10. Field/Pool(s): ADLO-028331 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 9730 feet Plugs (measured) 9271 PLUG 12/88 true vertical 9560. feet Junk (measured) 9710 Effective Depth measured 9695 feet true vertical 9531 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2569 13-3/8" 72# L-80 SURFACE - 2641 SURFACE - 2641 4930 2670 Intermediate 8824 9-5/8" 47# L-80 SURFACE - 8896 SURFACE - 8747 6870 4760 Liner 1125 7" 29# L-80 8605 - 9730 8463 - 9565 8160 7020 Perforation depth: Measured depth: SEE ATTACHED True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2"17# L-80 SURFACE - 8586' 0 0 - Packers and SSSV (type and measured depth) 5-1/2" TIW HB-BP 8499 5-1/2" BOT 3-H PKR 8576 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): f`r` G Treatment descriptions including volumes used and final pressure: = f `~~ ~` ~ ~ ~ f r ~z 208 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 12257 420 907 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil 1~~ Gas ~'' WAG ~ ~ GINJ ~~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble- Title Data Management Engineer Signature Phone 564-4944 Date 9/17/2008 Form 10-404 Revised 04f2Q0(^r~ y~~q yg~.y~ y; Ej f~ ~} (y Submit Original Only 17-08 181-0740 PFRF ~TT~('.HMFNT • Sw Name Operation Date Perf Operation Code ___ _ Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 17-08 3/14/82 PER 9,090. __ _9,118. __ 8,937.68 8,965.16 17-08 3/14/82 PER 9,137. 9,165. 8,983.81 9,011.3 17-08 3/24/84 APF 9,178. 9,213. 9,024.06 9,058.41 17-08 6/2/88 APF 9,313. 9,333. 9,156.57 9,176.19 17-08 6/2/88 APF 9,394. 9,414. 9,236.01 9,255.61 17-08 6/2/88 APF 9,417. 9,440. 9,258.55 9,281.08 17-08 11/25/88 SPS 9,271. 9,695. 9,115.35 9,530.69 17-08 3/22/89 FIL 9,258. 9,271. 9,102.59 9,115.35 17-08 3/27/89 APF 8,985. 9,008. 8,834.61 8,857.18 AB ABANDONED ~ PER PERF ~ APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO _ VED ___ FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO_ STRADDLE PACK, OPEN OH OPEN HOLE • 5~ 1~-os DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY .. _ ..... i 5/17/2008 SET WEATHERFORD LOWER PACKER ELEMENT FOR PATCH. ' ~ MID ELEMENT SET AT 2510'. MIN ID THROUGH PACKER IS 3.0" .TOP OF PACKER AT 2505' ''"''JOB COMPLETE""` ; 5/23/2008 "`"'WELL S/I ON ARRIVAL***(tubing patch) CURRENTLY HANGING AT 2,400' SLM W/ E-FIRE, 5 1/2 " X 33.09' WFD PATCH ~ NOTE: MIN ID. = 2.90", 33.73' BETWEEN ELEMENTS ~ STANDING BY FOR LRS TANKER TO ARRIVE TO LOAD TUBING W/ DIESEL x *""JOB IN PROGRESS, CONTINUED ON 5/24/08*"* _~___._ ~_....._ v ..~____~___~_.__. ,_~~_w.~~___ ___._~ ___~._w~_.___ . ~_.__ ___,___.__.__.. 5/24/2008 T/I/O = 240/200/0 Temp = S/I -Assist Slickline setting patch/ MIT IA Failed to 2500 psi./ Unable to establish LLR -amt. to small (Restore tubing integrity by setting patch) Pumped 140 bbls 45" diesel down TBG. Patch set. First test -MIT IA presured up to 2500 psi with 3.7 bbls diesel. IA lost 450 psi in first 15 minutes. Second test -MIT IA pressured up to 2500 psi with .9 bbls diesel. MIT IA lost 290 psi in first 15 minutes. Third test -MIT IA pressured up to 2500 psi with .4 bbls diesel. MIT IA lost 230 psi in first 15 minutes and 200 psi in second 15 minutes. For a total of 430 ` psi in 30 minutes. Fourth test -MIT IA pressured up to 2500 psi with .7 bbls diesel. MIT IA lost 210 psi in first 15 minutes and 230 psi in second 15 minutes. For a total of 440 psi in 30 minutes. Bled back ~ 3 bbls. Bled ` down to 0 psi. Rigged down and at departure pressure increased to 400 psi same as TBG. Tagged IA, Wing valves and notified DSO of results. Wing and SSV closed at departure, all other casing valves open to igauges. *"*Note tree has bolts with threads not showing'""` FWHP's= 6 400/400/0 _ ' ___________.~~,.~..w~______.~_____.~..~..____ __---____._______. 5/24/2008E*""CONTINUED FROM 5/23/08 WSR'''""(tubing patch) LRS PUMPED 140 BBLS DIESEL TO LOAD TUBING ' NOTE: MIN ID. = 2.90", 33.73' BETWEEN ELEMENTS ***WELL S/I ON ARRIVAL, NOTIFIED DSO"** 6/11/2008ET/I/O=SSV/240/0+. Temp=S1. IA FL (for LDL). IA FL C«~ surf. "* Note: IA ;integral installed. 6/12/2008IT/I/0= 340/240/0+. Temp= SI. Estimate LLR- IA to TBG to 2500 psi with { ~tri lex for LDL). Integral on IA. IA FL @ surface. Pumpe iese wit { ~ triplex down IA, increased IAP to 2500 psi (used 232 gallons). SD pump, X30 minute monitor. IAP decreased 540 psi in 30 minutes. Increased IAP Ito 2500 psi, used 24 gallons diesel (LLR= 0.8 gpm). IAP decreased 800 !psi in 30 minutes. Increased IAP to 2500 psi, used 51.7 gallons diesel I (LLR increased to 1.7 gpm). IAP decreased 800 psi in 30 minutes. ;Increased IAP to 2500 psi, used 52 gallons diesel. Bled IAP to 250 psi ! I (bled back 120 gal. diesel). 30 minute monitor. TP unchanged, IAP I ?decreased 10 psi ,OAP unchanged in 30 minutes. LLR= 1.7 qpm. Final u ._ ~....~__.___._. ~WHP's= 340/240/0+_. __ _~~ 6/13/2008 T/I/0= 350/250/0+. Temp= SI. Pre a-line work. TBG FL @ 60 ft. IA FL i @ surface. 6/17/2008;"'TECWEL LEAK DETECT LOG** ;WELL SI UPON ARRIVAL. INITIAL T/I/O = 450/450/0 MI PJSM RU AND PT LUBRICATOR TO 3000 PSI. RUN STATIC PASS WITH WELL SHUT-IN AND NOTICED LEAK ACROSS PATCH AT 2490'. r {ONCE AT TD., START PUMPING DOWN THE IA TAKING RETURNS TO THE FORMATION. RATE=0.18 BPM @2400 psi. t LOG FROM PBTD 8520' TO SURFACE, FINAL T/I/O = 400/400/0 ',*""' JOB COMPLETE """` 7/18/2008'''''" WELL SHUT IN ON ARRIVAL**~[patch] ""`CONT. JOB ON 7/19/08 WSR"*" 7/19/2008'**CONT. JOB FROM 7/18/08 WSR*"*[patch] ;PULL 5 1/2" WFD ER PACKER @ 2470' SLM, WELL SHUT IN,TURNED WELL OVER TO DSO"'`" 8/5/2008*"'ON LOCATION WELL SI MASTER-OPEN, SWAB CLOSED, IA/OA- ~OPEN TO GAUGES"*" INITIAL T/I/O 400/300/0 RIG UP SLB ELINE, CH2 CRANE, ~HALLIBURTON 20 FT PATCH. SET PATCH FROM 2.485' TO 2.505' F RETRIEVING TOOL IS 5.5 IN PRT, 3.045 IN COLLET, 4400# TO RELEASE, 3.0 IN ID. PATCH SET WITH GOOD INDICATION AT ;SURFACE. END OF JOB. FINAL T/I/O 350/250/0 t""`JOB COMPLETE""" • ~ 8/7/2008T/I/O= 280/200/0 Temp=S/I MIT IA PASSED to 2500 psi (Post Patch) ;Pressured up IA with 4 bbls neat to reach 2500 psi. 1 st 15 min IA lost 20 jpsi, 2nd 15 min IA lost 10 psi with a total loss of 30 psi in 30 min test. Bled 'back 4 bbls neat. "Operator notified of valve positions Swab=closed, Wing=closed w/ tag, SSV=open, Master=open, IA= open w/ tag, OA= ;open on departure" 8/19/2008jT/I/O=1000/550/400. Temp=Online. AOGCC MITIA PASSED to 2500 p. (R/C). State witnessed by John Crisp. MITIA decreased 40 psi in 1st 15 ;mins, 10 psi in 2nd 15 mins, total of 50 psi in 30 mins. Final T/I/0=1000/250/420. LRS in control of valves upon departure. 8/19/2008?T/I/O = 1000/550/400 Temp =HOT - AOGCC MIT IA PASSED to 2500 ;psi witnessed by John Crisp (Restore integrity) -Pressured up IA to 2500 ;;psi w/3.6 bbls 70* 60/40 meth/water. IA lost 40 psi in 1st 15 min and 10 :;psi in 2nd 15 min for a total loss of 50 psi in 30 min test. Bled IA to starting pressure. FWP's = 1000/450/420 *'~ Notified DSO of all valves positions: Swab ';closed, master open, SSV open, wing open, IA open, OA open ""* FLUIDS PUMPED BBLS 140 DIESEL 4 NEAT 3.6 METH/WATER 147.6 Total by To: J. Bixby/ C. Olsen Date: May 07, 2008 GPB Well Ops Team Leaders From: Chris Colbert, DS Engineer 03 & 17 AFE: PBD17WL08-N DeWayne R. Schnorr, Design Engineer Est. Cost: $70,000 Subject: 17-08i; 5-1/2" Tubing Patch IOR: 280 1. E Set 5-1 /2" Weatherford L-80 lower acker 2. S Set 5-1 /2" Weatherford L-80 U er Packer Assembl w/ E-fire. 3. F MIT-IA TO 2500 psi, Establish LLR if MIT-IA fails. (post atch) Requires 10-404 after job is completed Current Status: Last Injection Rate: Max Deviation: Deviation at Perfs: Min. ID: Last Downhole Ops: Latest H2S level: Not Operable --- TxIA Communication --- TTP pulled 10/21/2007: 12,245 bwpd @ 1286 psi 22 degrees @ 6900' and 12 degrees @ 8985' and 2.750" @ 8532', 5-1/2"x3-1/2" Nipple Reducer 04/12/2008: TecWel LDL logged to 8550'. N/A water injection well --- DS17 is an H2S site Job Objective The objective of this procedure is to restore tubing integrity by setting a patch. Well History Completion is 5-1/2" 17ppf L-80. A nipple reducer (2.75" X-nipple) was set @ 8532' (02/20/2008). Combo MIT x IA passed (02/20/2008). TecWel LDL was performed on 04/12/2007, and found a leak at 2488'-2500'. Also, the TecWel LDL had a long die-off signal above the leaks from 2488' - 2500'. This was verified by the stop counts which had a strong signal from 2460' - 2505'. A patch drift was run 12/03/2007. Caliper indicates that tubing is in good condition with maximum pitting of 21 %. If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (w), 274-0929 (h) or 240-8037 (c); or Chris Colbert at 564-5135 (w) or 907-306-2465 (c). cc:j/s: Well File .Inh (lhiortivo • • The objective of this procedure is to seta 30' 5-1/2" L-80 two set Weatherford patch over leak @ 2488' -2500' and restore tubing integrity. Ensure carbon steel L-80 patch is run (injection well.) Patch Depth Control - All depths are referenced to TecWel LDL log dated 04/12/2008. Patch Setting Depth is 2480' to 2510' (30 ft) Collar Locatc Tbg JT Tbg JT Tbg JT Tbg JT Tbg JT ~r Summary from ELine TecWel LDL to 2452-` 2494' Leak 2488'- 2500' 2536-` 2578' 2619' Eline Set 5-1/2" Weatherford Lower Patch Assembly RU EL. RIH with lower packer and tie into Jewelry at SSSV @ 2072'. Log down to setting depth. Note: Reference log TecWel LDL (04/12/2008) is included. 2. Set lower packer @ 2510'. Slickline Set upper patch assembly with E-fire. 3. PU &RIH with upper packer assembly, with E-fire and set per manufacturer's recommendation @ 2480' (ref. TecWel LDL 04/12/2008). F (Post Patch) 4. MIT-IA to 2500 psi. Establish LLR if MIT-IA fails. ~ TREE= FMCGENz e= i= D= 13-318' ~C,, 72#, L-80, D =12.347' Minimum ID = 2.75" @ 8532' 5-112" X 3-112" NIPPLE REDUCER 15-it2' TBG, 17#, L-80, 0.0232 hpi, D = 4.892' 5.112' TBG, 17#, L-80, .0232 bpf; D = 4.892 TOPS 7" LNR PERFORATDN SIAMiARY REF LOG; BRCS ON 06P1B181 ANGLE AT TOPPERF:12 (818985' Note: Reter io Ftoduction OB for hls~ical pert data S¢E SPF INTERVAL QpNSgz QATE 3-318' 4 8985 -9008 O 03+27!89 3-118° 4 9090- 9118 O 03115!82 3-1~' 4 9137 - 9185 O 03+15182 d 9178-9213 C 03124(84 3-318' 4 9178 - 9333 S 06+03188 4 9313 - 9333 S 11/121$8 4 9394-941d S 11!12188 4 9417 -9440 S 11112/88 3-318" 4 9394 =9440 S 06103/88 7" LNR, 29#, L-80, 0.0371 bpf, D = 17-08 I B~ISO i DATE REV BY S DATE REV BY COMMB~TS 07/02/81 ORIpNAL COMPLETION 02124197 LAST WORKOVHt 07/14N1 RNrTP CORRECTIONS 10/26102 CJ1fP PERF ADDttiONS 10126101 CJ/TP PERF ADDITfONS 03/08!08 SWGPJC SET R®tJCl31 NP (02120'08) SAFETY NOTES: 15-1P1" FlES t~d0 SSSV NP, D =4.562' I 9-518' X 5-112' TNV Ef3-BPT PKR, D= 4.882' 5.112' HESXN NP, ID= 4.455" 3-112° FES NP REDUCER w / X PPoOF~E, ID = 2.75' 5-112" fURTEDSI~ 5-112' SEALASSY W10 SEALS w t7" STOPGOLLAR, ID = 4.93$" 9-518° X 5-112° BOT 3-N PKR 5-112" X 4-112' XO, D = 3.958" 14-112° CAMCO LANDNG NP, D = 3.813' ~ 41 YL° BKR SHEA ROUT SUB CMt& SAND PLtiG (SEf 12109188) FSH~ BKR PKR ELBv~Vf PRUDI~BAY tNJli Wai: 17-08 PERMR No: 1810740 A PI No: 50.029-202-00 SBC 22, T10N, R15E, 4121.96' FEL & 1223.96' FPR BP t3rploratlon (Alaska) 3 • • • • • • PDS Report Overview Body Region Analysis 1Vell: 17-08 Surrey Date: December 2, 2007 field: Prudhoe Bay Tool Type: !vlfC :l0 No. 99193 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of fingers: ~0 Analyst: B. i Tubing: Nom.OD 11+'eight Grade & Thread Nom.ID Nom. Upset Upper len. Lo~yer len. 5.5 ins 17 f L-80 x.892 ins 5.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (no wall) ~ penevation body ~ metal loss body 200 150 100 50 0 0 to to 10 to 20 to ~0 to over 190 10°.'0 20°ro a0°o 850/0 85°0 Number of oints analysed {total = 212? gene. 0 182 29 1 0 0 loss 116 96 0 0 0 0 Damage Configuration (body ) 10 30 ,;, u isolates gererai Ime ria~ pole. poet pitting corrosion corrosion corrosion ~ble Hole Number of oints dams ed Itotal = 30! 30 0 0 0 0 Damage Profile (°'° wall- ~ penetration body ~ metal loss body 0 50 100 Bottom of Sun~ey = 206.9 Analysis Oven~ie~ti~ page 2 C • • PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf L-80 ~\'en: 17-08 Bodv 4Vall: 0.304 in Field: Prudhoe Bav Upset~~Va~: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 4.892 in Country: l,'SA Survev Date: December 2, 2007 Joint ~o. Jt. Depth i.Ft.) Per'. l.pset (Ins.l Pen. Body (Ins.j Pen. °o ~:tetal Lo., °~ Min_ LD. (Ins.j Comments Damage Profile f°o wall) 0 50 100 1 24 0 0.01 1 4.80 2 64 0 0.0 3 1.77 3 101 0 0.02 5 1 4.80 1 112 0 0.02 s ~ 4.a1 5 18 0 0.0 ? 6 223 0 0.02 7 1 1.82 ~ 266 0 0.02 7 ' 4.83 8 307 0 0.03 9 d. 1 9 348 0 0.0 7 1 10 390 0 0. 8 4. 11 429 0 0.02 6 '. 4.78 1 170 0 0.02 6 1. 3 13 512 0 0.0 - 4. 14 551 0 0.0 6 - 4.80 15 592 0 0.0 4.8 i 6 63-1 0 0.02 5 -1.83 17 676 0 0.02 6 1.8 18 718 0 0.02 ~ 1.81 19 760 0 0.02 4.83 20 801 0 0.03 9 -1.83 21 841 0 0.02 8 -1.82 22 882 0 0.05 16 -1.82 Shallow itGn . 23 921 0 0.02 ' -1.8.1 21 963 0 0.02 S ~ 1.81 25 100-1 0 0.02 S 4.80 26 10.1-! 0 0.02 8 _' -1.80 27 1086 0 0.01 5 ? 4.8 28 1128 0 0.02 ~ 4.82 29 1168 0 0.02 1.83 30 1210 0 0.02 4.83 Sh ti• i tin . 31 1219 0 0.03 9 4.79 32 1291 0 0.02 7 - .1.82 33 1333 0 0.01 ~ 1.81 3.1 1375 0 0.0 4.81 35 1-117 0 0.02 ' 4.80 36 1-159 0 0.02 7 ~ 1.82 37 1500 0 0.02 7 1.8 38 15:12 0 0.02 6 ' .1.85 39 1582 0 0.01 5 1.83 10 1622 0 0.03 9 1.81 11 1661 0 0. ~ -1.81 1 1706 0 0.01 1 1.85 13 1718 0 0.02 7 ~ 1.83 d4 1789 0 0.02 S 1 1.8 15 1831 0 0.0 7 2 1.83 36 1872 0 0.02 1.81 17 1911 0 0.02 % i 1.82 48 1953 0 0.02 7 ~ -1.83 19 1995 0 0.02 7 ~ 1.81 50 2037 0 0.02 7 ~ 1.82 Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf L$0 \1'efl: 17-08 Body 4Vall: 0.304 in Field: Prudhoe Bav Upset 4Vafl: 0.304 in Compam~: BP Exploration I;Alaska), Inc. Nominal LD.: 1.892 in Country: USA Surv~ev Date: December 2, 2007 Joint No. Jt. Depth fFt.} Pen. Upset (Ins_I Pen. Body flns.) Pen. °~o h1etal Loss ~~~ ~~1in. LD• jlns.) Comments Damage Profile (°'o wall;l 0 50 100 50.1 2078 0 0.03 8 1 1.84 PUP 50. 87 0 0 0 45 SS V 0.3 90 0 0.02 1 1. 4 P' P 51 100 0 0.02 ? 1 1.84 2111 0 0.0'' 7 2 4.8 53 2183 0 0.02 7 2 4.84 54 2 1 0 0.0 7 ~ 1.8 55 2262 0 0.02 7 2 -1.83 03 0 0.02 7 ' 1.81 57 23.14 0 0.0 % 1 -1.83 58 2383 0 0.02 7 ? 4.79 59 2-125 0 0.02 7 1 4.84 2466 0 0.02 5 ~ 1.82 61 2508 0 0.0 6 4.8d 62 2550 0 0.03 9 ~ 4.81 63 2592 0 0.02 5 1.82 6.1 2633 0 0.02 '. -1.83 65 2673 0 0.01 ~ 2 i 4.83 Shallrne~ ittin . 66 2715 0 0.02 5 1.8:1 67 2756 0 0.02 1.81 68 2797 0 0.02 1.$3 69 2838 0 0.02 1.83 70 2880 0 0.02 5 4.81 71 2922 0 0.02 ? ~ 1.83 7 296.1 0 0.0'' 4.84 73 3005 0 0.02 ! 4.83 71 3018 0 OA2 ? 1.83 75 3090 0 0.03 . 4.82 Shallow ittin . 76 3131 0 0.02 E '~ -3.83 77 3171 0 0.02 ? 1 1.84 78 21 0 0.0 6 1.81 7 3253 0 0.02 6 1.83 80 3295 0 0.02 5 1.82 81 3336 0 0.01 5 ~ 1.81 8 3377 0 0.02 1 1.81 83 3118 0 0.02 ? 1 4.83 8:1 3156 0 0.02 ? 1 1.83 85 3198 0 0.02 ? 1.83 8 3536 0 0.01 5 1.83 87 3571 0 0.02 1.82 88 3616 0 0.03 1.82 Shallo~,v ittin . 9 3658 0 0.02 6 1.85 90 3700 0 0.02 ? 1.83 91 3710 0 0.02 6 ~ 1.82 9 378 0 0.02 5 1 1.85 93 3821 0 0.02 1.84 94 3861 0 0.02 6 4.84 95 3406 0 0.02 6 . 1.83 96 3915 0 OA2 ? ~ 1.83 97 3986 0 0.02 7 4.80 Penetration Bodv Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 17.0 ppf L-80 l1'e~: 17-08 Body 4'lrall: 0.304 in Field: Prudhoe Bav Upset ~VaN: 0.304 in Company: BP Exploration jAlaska}, Inc. Nominal LD.: 4.892 in Country: USA Survey Date: December 2, 2007 Joint No. Jt. Depth jFt.l Pen. Upset iln•_i Pen. Body (Ins.j Pen. °~o ~4etal Loss °~ Min. LD. (Ins.l Comments Damage Profile ~ •'6 tivallj 0 50 100 98 x028 0 0.02 7 ? 4.83 98.1 x070 0 0 0 0 h,'A Tread X-over 99 4072 0 0.02 7 1 1.79 100 1113 0 0.02 ? 1.82 101 -11:9 0 0.02 1 1.80 102 1191 0 0.02 6 ~ 1.82 103 4231 0 .O t 1.81 101 4 77 0 0.0 S ] -1.81 105 4319 0 0.01 5 +) -1.79 106 -1360 0 0.01 1 4.84 107 x395 0 0.02 S 4.82 108 -1.137 0 0.02 ~ 4.80 109 14 0 0.01 5 -3.81 110 15 0 0.01 1 -1.81 111 -1559 0 0.01 ~ ~ 1.82 112 1602 0 0.01 ~ 1.80 II3 165 0 0.02 4.82 I11 -1688 0 0.02 5 4.82 115 1730 0 0.02 ~ 1.81 116 -3771 0 0.03 9 1 -1.81 117 -1816 ~"+ 0.02 6 1 4.86 1 'I S 1850 0 0.02 6 1.8 119 1889 0 0.02 5 4.81 120 -1931 0 0.03 11 1.76 Shallow itlin . 121 -1970 0 0.03 9 1 -1.86 122 5009 0 0.02 6 ' 1.83 123 5053 0 0.03 9 1.83 121 5093 0 0.02 5 _' -1.79 125 5131 0 0.03 9 i -3.77 126 5176 0 0.01 5 1.81 127 5220 0 0.02 5 -1.83 128 5262 0 0.02 6 ~ 4.79 129 5302 0 0.02 8 1 1.81 130 5310 0 0.01 1 I :3.77 131 380 ~~ 0.02 S 1 1.81 132 51 18 0 0.03 : J 1.87 133 5360 0 0.01 ; 3 ? 1.82 Shallow it>in . 131 5503 0 0.02 7 ! 4.80 135 5511 0 0.03 9 l 1.78 136 5583 0 0.02 5 1.81 137 56 I 0 0.03 ; ; 1.83 Sh low ittin . 138 5661 C 0.01 -l Z 1.81 139 5701 0 0.01 ~ ' 4.81 140 5717 0 0.01 5 1.82 141 5790 0 0.02 5 1 1.82 112 5831 0 0.03 10 1.82 1-13 5873 0 0.02 5 Z 1.81 141 59f5 0 0.01 5 i -1.78 1-35 59,6 ~~' 0.01 1.3' I ~6 595 0.03 ~3.'6 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI Pipe: 5.5 in 17.0 ppf L-80 tVe~: Body 4t'all: 0.304 in Field: UpsettVaq: 0.304 in Company: Nominal LD.: 4.892 in CounW: Surv•ev Date: • 1LATION SHEET 17-08 Prudhoe Bav BP Exploration (Alaska), Inc. USA December 2, 2007 Joint No. Jt. Depth (Ft.) Pen. Upset ilns_j Pen. Body jlns.) Pen. °~ n4etal Loss °~ Min. LD• jlns.l Comments Damage Profile r.°a wall) 0 50 100 117 6024 0 0.03 ! ; 1 4.84 Shallrnv itlin . 118 6 67 0 0.02 6 1 -1.77 149 6109 0 0.02 5 I =1.83 1 6152 0 0.02 5 3 4.8 151 6194 0 0.02 5 1. 5 152 6235 0 0.01 5 4.82 153 6278 0 0.03 ; 1 1 4.78 hall w ittin . 1 6318 0 0.01 3 4. " 155 6358 0 0.01 3 -1.83 1 6 6400 0 0.02 7 1. 157 6-112 0 0.0-1 ? 1 1.76 5hallotiv ittin . 158 6484 0 0.02 7 1.83 1 65 7 0 0.03 ? 1 1 -1.80 h l w it n. 1 656 0 0.02 ~ ' 1.8 161 6608 0 0.03 1 1 1.83 Shallow ittin . 16 664.1 0 0.02 1.83 163 6686 0 0.02 ; 4.83 16-1 6729 0 0.01 ? 2 . 4.81 Shallow ittin . 16" 6767 0 0.03 8 1.8:1 16 6811 0 0.0.1 i 2 1.83 Shallow ittin . 167 68.16 0 0.02 ? -1.8.1 16 6888 0 0.01 ; ~ 1.80 Shall tiv it n . 169 6925 0 0.03 1.80 Shallow itbn . 170 6968 0 0.02 5 ! 4.85 171 7010 0 0.06 ?' 1.81 I~ I ted ittin 172 70.15 0 0.05 -1.82 Shallo~•v ittin . 173 7081 0 0.01 ' ? 1.81 ;hallo~.ti itlin . 171 7121 0 0.01 ~ 1.81 175 7163 0 0.03 ' ! •1.83 Shallo~•v itlin . 176 7196 0 0.01 ' ? ? 1.83 Shallow itlin . 177 7235 0 0.03 ; 0 ? 4.83 178 7279 0 OA1 ' 3 -1.80 Shallow ittin . 179 7321 G 0.02 5 1 4.81 180 7363 0 0.02 ' -1.8.1 181 7-106 0 0.03 9 -1.80 182 74-16 0 0.02 6 1.85 183 7185 0 0.03 .0 1.83 181 7524 0 0.02 ? 2 1.82 18" 7566 0 0.02 5 4.86 186 7605 0 0.02 ? 1.84 187 7617 0 0.01 i 2 ~ -1.78 Shallow ittin . 188 7691 0 0.02 5 1.8 189 7733 0 0.02 6 . 1.81 190 7775 0 0.05 :5 1.79 Shallow ittin . 191 7818 0 0.01 ' 1.83 192 7862 0 0.03 ' 1 4.77 Shallow itlin . 193 7903 0 0.02 1 4.77 19-1 7913 0 0.01 '? 4.75 Shallo~ti• ittin . 195 7981 0 0.03 9 i 4.80 196 8026 0 0.01 1 ? 1.80 Penetration Bodv Metal Loss Body Page 1 10 • PDS REPORT JOINT TABI, Pipe: 5.5 in 17.0 pRf L-80 4VeY: Body b1'all: 4.304 in Field: Upset4b'al: 0.30.4 in Company. Nominal f.D.: 4.892 in County: Survey Date: • iLATION SHEET }?-08 Prudnce Bay BP Exploration !Afaska;~, Inc. USA December 2, 2047 joint No. jt Depth IFt.i Pen. Jp.e: ;`n:.~ Pen. Body ;Ins.; Pen. `o titetal La, °~ I~lin. LD- I'Ins.l Comments Damage Profile (°'o •wall; 0 50 700 i 9? 8069 0 Q04 12 I 4.80 Snallrnv ittin~. 198 8113 0 0.02 5 1 4.80 t 99 815? 0 0.02 S 1 4.86 200 8198 0 0.03 11 1 4.'9 Snallrna~ ~itCnQ. 201 8~~a o o.a2 ~ ~ 4.80 202 5253 I) 0.03 I1 I -4.80 Shallrnv ~itOn~. 203 5326 0 0.02 S I •1.83 204 8365 0 0.02 5 I 4.83 205 8108 0 0.01 3 _' 4.83 206 5451 I) 0.0-4 13 ~ 4." 7nallotti• ~ittin~. 206.1 892 0 0.01 5 I 4.?9 FOP 206? 5502 0 0 0 4.88 F.~,Ci:ER I ~ I ? I I ~ I I ~, ~ 206.' 5550 0 0.02 5 1 4.?8 FLP ZOb.B 5565 0 0 0 N .~ P.ACI:ER 206.9 85?4 0 0 0 N `A X-over Penetration Bocv 1lleial Lo.s Bodv Page ~ 11 • • ''~ Tubing Detail e e Rig Nabors 2es Date 2 / 21 ! 9 7 ~ Weli 17-Si I~~ Tubing 5.5 L-80 Butt Mod/LTC 8M Tubing wt. 1 7 Well File 220 JTS ON RACK 206 JTS RAN 28.50 RT-BF 9009.36 FT ON RACK 843178 FT RAN RT-Pad Elev. Combination String--1-108 LTC, 109-220 Butt Mod 28.50 RT-GL ITEM DescH lion includes: SIZE TYPE, CONNECTION JTS #-# ITEM ID OD LENGTH TOP BOTTOM W LEG w/Mute shoe 4.938 6.063 2.00 8560.27 8562.27 Seal ass . w/o seals w!7' sto collar 4.938 5.750 16.14 8544. f 3 8560.27 X-over 4.938 5.500 1.35 8542.78 8544.13 Ported sub 4.892 5.500 9.15 8533.63 8542.78 XN' Ni le 4.455 6.063 1.42 8532,21 8533.63 5.5" 17# L-80 MOD-BTRC PUP JT. 4.914 5.500 9.21 8523.00 8532.21 5.5" 17# L-80 MOD-BTRC PUP JT. 4.914 5.500 19.30 8503.70 8523.00 TIW HB-BP-T PKR 4.882 8.311 4.68 8499.02 8503.70 X-OVER 8M Box X IBMod Pin 4.909 5.500 2.04 8496.98 8499.02 5,5" 17# L80 Srd PUP JT. 4.914 6.020 10.22 $486.76 8496.98 Jts# 1-108 5.5"17# L-80 Srd TBG 4.892 5.500 4412.96 4073.80 8486.76 X-OVER Mod BTRC Box X Srd Pin 4.892 5.500 2.09 4071.71 4073.80 Jts# 109-156 5.5"17# L-80 Mod BTRC TBG 4.892 5.500 1967.51 2104.20 4071.71 5.5"17# L-80 Mod BTRC PUP JT 4.892 5.500 9.63 2094.57 2104.20 5.5" HES 'HRQ' Landin Ni le w/ dumm installed 4.562 6.600 2.93 2091.64 2094.57 5.5" 17# L-80 Mod BTRC PUP JT 4.892 5.500 9.63 2082.01 2091.64 JTS # 157-206 5.5"17# L80 MOD BTRC TBG 4.892 5.500 2051.31 30.70 2082.01 FMC GEN.1 3 RETRO HGR 4.850 13.625 2.20 28.50 30.70 RT-~ 28.50 28.50 53 SS CONTROL UNE BANDS RUN 12 • by To: J. Bixby/ C. Olsen Date: July 11, 2008 GPB Well Ops Team Leaders From: Chris Colbert, DS Engineer 03 & 17 AFE: PBD17WL08-N Est. Cost: $100,000 Subject: 17-08i; Re-Set 5-1/2" Tubing Patch IOR: 280 1. S Pull 5-1/2" Weatherford L-80 Patch 2. E Re-run 5-1/2" Single set Halliburton DWP L-80 preferable but can be chrome 3. F MIT-IA TO 2500 psi, Establish LLR if MIT-IA fails. (post patch) Requires 10-404 after job is completed Current Status: Last Injection Rate: Max Deviation: Deviation at Perfs: Min. ID: Last Downhole Ops: Latest H2S level: Not Operable --- TxIA Communication --- TTP pulled 10/21/2007: 12,245 bwpd @ 1286 psi 22 degrees @ 6900' and 12 degrees @ 8985' and 2.750" @ 8532', 5-1/2"x3-1/2" Nipple Reducer 06/12/2008: TecWel LDL logged to 8520'. N/A water injection well --- DS17 is an H2S site Job Objective The objective of this procedure is to restore tubing integrity by re-setting the patch. An LDL on 06/12/2008 verified the seal assembly between the patch and the lower packer is leaking. Well History Completion is 5-1/2" 17ppf L-80. A nipple reducer (2.75" X-nipple) was set @ 8532' (02/20/2008). Combo MIT x IA passed (02/20/2008) and a calliper run on 12/2/2007 indicates the tubing is in excellent condition. TecWel LDL was performed on 04/12/2007, and found a leak at 2494' with a long build up anomally from 2420'- 2494'. This was discussed with TecWel and determined to be anon issue. A patch was set from 2474'-2510 ELMD. An MIT-IA on 05/24/2008 and a subsequent LDL on 06/12/2008 indicated the patch was leaking. Specifically, the strong leak signal is 4' up from the Base of the lower packer showing the seal assembly where the spacer pipe stings into the packer is leaking. The purpose of this work is to remove the 5'h" Weatherford patch and re-run a 20' single set Halliburton DWP. If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (w), 274-0929 (h) or 240-8037 (c); or Chris Colbert at 564-5135 (w) or 907-306-2465 (c). cc:j/s: Well File SL -Pull Patch • 1) Pull 5'/z" Weatherford patch assembly from 2574'-2510' ELMD. Ensure Weatherford is on location to retrieve patch as it is pulled form the well. Send complete breakdown report on patch to Jennifer Julian. EL- Re-run Halliburton Patch 2) RU EL. RIH with 20' 5 1/2" Halliburton single set DWP patch. Tie into jewellery at SSSV @ 2072'. Log down to setting depth. NOTE: Reference log TecWel LDL (4/12/2008) is included. 3) Set 20' patch between 2485' - 2505' per manufactures recommendations. Patch Depth Control - All depths are referenced to TecWel LDL log dated 04/12/2008. Patch Setting Depth is 2485' to 2505' (20 ft) Collar Locata Tbg JT Tbg JT Tbg JT Tbg JT Tbg JT ~r Summary from ELine TecWel LDL to 2452-` 2494' Leak at collar @ 2494' 2536-` 2578' 2619' F (Post Patch) 4) MIT-IA to 2500 psi. Establish LLR if MIT-IA fails. 2 TRff= FMCGEN2 WaLHEAD= FMC ACTUATOR= AXELSON KB. ELEV = 71' BF. ELEV = KC4' = 5700' Mex Ante = 22 Q 6900' Datum MD = 9027 Daum TVD = 8800' SS ~ ~s-eras w~, ice, ~-tw, u = iz.~nt- ~--~ ~q7• Minimum ID = 2.T5" ae 8532' 5-1/2" X 3.112" NIPPLE REDUCER sa~r NOTFS: 17-08 2092' H5-1P2" I#S HRO sssv NP, D = 8499' f'19.518' X 5-112" TNY H&BPT PKR, D= 4.88Y $532' H5-1/2" F~SXN NP, ID= 4.455' 8532' 1-13.112" HES NP REDUCER 15.1Y2" 1BG, 17#, L-80, 0.0232 bpi, D = 4.892' 1 15-iP2' TBG, 17k,1-80, .0232 bpf, D = 4.892 TOPOF T LNR 41P2' TBG•PC,12.6#, P480, .0152 bpf, D = 3.958" 9-518' CSG, 47#, L-80, D = 8.681" PERFORATION Sl1ATMRY REF LOG: BRCS ON 08/2681 ANGLE AT TOP PERF: 12 (c~ 8985' Note: Refer to Productlon DB fa his~ical pert data S<zE SPF MEi2VA L OpNSgz DATE 3-38" 4 8965 -9008 O 03+2789 3-18' 4 9090.9118 O 03115182 3-18' 4 9137.9165 O 0311582 4 9178 - 9213 C 03124184 3.38" 4 9178 - 9333 S 0&0388 4 9313 - 9333 S 1111288 4 9394 -9414 S 11!12!8$ 4 9417 -9440 S 1111288 338" 4 9394 -9440 S 0610388 7' LNR 29M, L-80, 0.0371 bpT, D = 6.184' ~w / X PROFILE, ID = 2:75° I $534' 5.112" FORTEDSUB $544' 5-112' SEAL A SSY WIO SEALS w 17" STOPCOLLAR D = 4.938" $$7g' 9-518' X 5-102' BOT 3H FKR $$$s' 5-112° X 4112" XO, D = 3.958" ~d-1f2' fAMCfl LAN~1G Pte, D = 3.813" 41/2" BKRSHEARCriif SUB 4-112" WLEG, ID=3.958" ELMD T7 LOGGED 07106/81 9271' HCMf 8 SAND PLUG {SET 9710' FISH- BKR PKR ELt3~1ENt DATE REV 8Y COMMEtdTS [ATE REV BY COMMHJTS 0710281 ORIGINAL COMPLETION 02/24197 LAST WORKOVHt 07/14101 RNrTP CORRECTIONS 10/28102 CJlTP PERF ADDITIONS 10126101 CJRP PERF ADDITIONS 03/QBf08 SWGPJC SEi REDUCER NP (02/2Q`081 PRUDHOE BAY IMNf WELL: 17.08 PERMR No: ~ 810740 API No: 50-029-20802-0D SEC 22, T10N, R15E, 4121.98' FEi & 1223.96' FNL BP 6cpioratlon (Alaskay 3 • II 2000 I I 1 Z;oo 1~-08 Tu.w~l LDL . 't~iz~og ~Oo 2300 i Temperature Sub Failed I P ` Data Invalid from Surface to 2,497 t~ 2400 ~~.- f ~~ Leak Signature ~• v8s' -~ ~ '2500 ' ` - , ~sos' f'., Temperature Sub Operational; 2800 ~ 1 2700 ~ ~ 1 `~ II 2soo ~ 4o to so ~~ Temperature Scale Change ~ 'i 60 to 80 2900 ~ ~_ ~~\ S 3000 `Y 4 i - -- -- -- - ~{'~~2 fD$ F ----------- ., ~; ~~ 1 -- { ~ • I I _1__-__ ___.____-_-_._ t I } ~ .. j Temperature Sub Failed (~ 2,49T ~' ~' -- _ - --- l { ~ Data Invalid from Surface to 2,49T i {' .. -0 ' 1 I 241)0 _..._. _. .._ .. --- - +~r---~ - ---- ~ _ -j-- - i \- I . V _ - _ - . - . __ _ - a ~-- - - ~ ~ - - -- -- --- S ~y8s' ~~- ~ ~ PATGkI ... -.._-_ ._-"---fir -- - -- - - ~-- ----- - - 2500 I _ }~. t ~ z sos' ~ 3 - _ _- - - - t ~~ ~ _ t j 11t F..~. _-__-~. , _-_ ._~ ~~ A _ : __ J Leak Signature i .. I .. ~~ ~ ----L ------- -- ~, '~ i Temperature Sub Operational !, ~. - it 5 PDS Report overview ~ Body Region Analysis \Vell: 17-08 Surrey Date: December 2, X00' Field: Prudhoe Bav Tool Type: MFC ~~ ~~ 99,93 Company: BP Exploration IAlaskaj, Inc. Tool Size: 2.75 Country': USA No. of Fingers: ~10 Anal st: B. Q Tubing: Nom.OD \Veight Grade & Thread Nom.ID Nom. l,'pset Upper len. Low^er len. 5.5 ins 17 f L-80 1.892 ins 5.5 ins 6.0 ins 6.0 ins Penetration and Metal loss (°~o wall) ~ penevation body ~ metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to -l0 to o~ er 1% 10°^0 20°'o a0°•o 85°.'0 85°.0 Number of'oints anal -sed (total = 2I2} pens. 0 I82 29 1 0 0 logs 116 96 0 0 0 0 Damage Configuration (body ) -10 30 .j isolated ger+eral Ime ring hole / poss pit[iny corrosion corrosion corrosion kble hole Number of ~oint; damn ed Itotal = 30) 30 0 0 0 0 Damage Profile (%wall) ~ penetration body ~ metal loss body 0 50 1 50 98 I.18 198 Bottom of Survey = 206.9 100 Analysis Overview page 2 G PDSREPORT JOINT TABULATION S•ET Pipe: 5.5 in 17.0 ppf L-80 4b'e~: 17-08 Body 1'Uall: 0.304 in Feld: Prudhoe Bav Upset 4Va9: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 4.892 in CounW: USA Sun+ev Date: December 2, 2007 Joint No_ Jt. Depth (Ft.) Pen. Upset iln~.i Pen. Body Ilns.j Pen. °o Metal Loss '~ ~~lin. LD. (Ins.) Comments Damage Profile i;°o tivall) 0 50 100 1 24 0 0.01 1 ? 4.80 1 0 0.02 ~ ~ 4 77 3 101 0 OA2 5 1 4.80 4 i12 0 0.02 8 ? 4.8.1 5 18 0 0.02 ? ? 4.82 6 223 0 0.02 ~ 1.82 7 266 0 0.02 - -1.83 8 307 ~ 0.03 Q 1.81 9 318 0 0.0 1.80 10 390 0 0.0 8 ' ~ 4. 11 129 0 0.02 5 I :1.78 1 170 0 0.0 6 1 1. 3 13 512 0 0.0 ~ 4.8 11 "51 0 0. ii 1. 0 15 592 0 0.02 1.8 16 631 0 0.0 5 1.83 17 676 0 0.0' 6 -1.83 18 718 0 0.02 8 1.81 19 760 0 0.02 ~ 4.8 0 801 0 0.03 9 1.83 21 811 0 0.02 8 4. 22 882 0 0.05 i 6 3.82 Shallow itlin . 23 91 0 0.02 4.84 21 963 i~ 0.02 8 ~ 4.84 25 1001 0 0.02 8 ~ 3.80 26 1011 0 0.02 8 2 1.80 27 1086 0 0.01 5 ? 1.8 28 1128 0 0.02 7 ~ 4.82 29 1168 0 0.02 7 ~ 4.83 30 1210 0 0.02 1.83 Shallow it n . 3 i 1219 0 0.03 q 1.79 32 1291 0 0.02 1.82 33 1333 0 0.01 1 1.81 31 13,'•5 0 0.02 ? 1.81 3 5 11 17 0 0.02 ' 1.80 36 1159 0 0.02 - 4.82 37 1500 0 0.02 4.8 38 1512 0 0.02 6 4.85 39 158 0 0.01 5 1.83 10 1622 0 0.03 9 1.81 11 166.1 0 0.02 ' 4.81 12 1706 0 0.01 1 1 1.85 13 1718 0 0.02 ? ' -1.83 11 1789 0 0.02 8 1 4.83 1" 1831 0 0.02 7 2 4.83 16 187 0 0.02 ? 3 4.81 17 1911 0 0.02 ? 1.82 18 1953 0 0.02 7 ~ 1.83 d9 1995 0 0.0~ ~ 1. 1 50 X037 0 0.02 7 2 3.82 Penetration Body Metal Loss Body Page 1 PDSREPORT JOINT TABULATION S•ET Pipe: 5.5 in 17.0 ppf L-80 41'e~: 17-08 Body ~'Vall: 0.304 in Field: Prudhoe Bav Upset 4VaR: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: USA Survev Date: December 2. 2007 Joint No. Jt. Depth jFt.) Pen. Lpsei (Ins. Pen. Body jlns.j Pen. °'o Metal Loss °o ~~lin. LD• Llns.j Comments Damage Profile l°owallj 0 50 100 50.1 2078 0 0.03 8 1 4.84 PU'P 2087 0 0 156 SV 090 C 0.0 6 -1.84 P ' P 51 100 0 .0 :1.8:1 141 0 4.8 53 2183 0 0.02 ~ 4.84 ~4 I 0 0.0 ~ 4.8 55 2262 0 0.02 ~ 4.83 56 2 03 0 0.02 1.84 57 234.1 0 0.02 ? 1 1.83 58 2383 0 0.02 ? 2 4.79 59 2125 0 0.02 7 1 1.84 6 2366 0 0.0 5 ? 4.8 61 508 0 0.0 5 1 4.81 62 2550 0 0.03 9 ? 4.81 b3 2592 0 0.02 5 1 4.82 4 2633 0 0.0 ? 1 1.83 6" 2673 0 0.04 '? ? 4.83 Shallrnv i ~n . 66 2715 0 0.02 5 4.8d 67 ??56 0 0.02 1.84 68 2? 97 0 OA2 ~ 4.83 69 2838 0 0.02 - -3.83 7 2880 0 0.0' S 4.81 71 2922 0 0.02 -1.83 7 2964 0 0.02 ? 4.84 73 3005 0 0.02 - .3.83 7.1 3018 0 0.0 ' -1.83 75 3090 0 0.03 : 1 1.82 Shallow itiin . 76 3131 0 0.02 E 4.8 77 3171 0 0.02 ? 4.8.1 78 3212 0 0.02 6 4.81 79 3253 0 0.02 0 1 4.83 80 3295 0 0.02 5 1 4.82 81 3336 0 0.01 5 2 1.84 8 3377 0 0.02 ? 4.8-1 8 3118 0 0.02 1.83 84 3.176 0 0.02 4.83 85 3198 0 0.02 ? 1.83 8 3536 0 0.01 5 1.83 87 357.1 0 0.02 1.82 88 3616 0 0.03 1 1.82 Shallow itOn . 89 3658 0 0.02 6 1.85 90 3 700 0 0.02 ? 4.83 91 3740 0 0.02 5 ~ 1.82 9 3782 0 0.02 5 1.85 93 382-1 0 0.02 ? -1.84 91 3861 0 0.02 5 -1.81 95 3906 0 0.02 5 -1.83 96 395 0 0.02 ? ' -1.83 97 3986 0 0.02 7 1.80 Penetration Body Metal Loss Body Page 2 PDSREPORT JOINT TABULATION S• T Pipe: 5.5 in 17.0 ppf L-80 1,Ve~: 17-08 Body Wall: 0.304 in Field: Prudhoe Bav Upsetl~Va1: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 1.892 in Country: USA Sun+ev Date: Decen~er 2, 2007 Joint No. Jt. Depth (Ft.1 Per.. l.~pset ~In~ i Pen. Body (Ins.) Pen. °'o Metal Loss °b Min. LD. (Ins.) Comments Damage Profile l°o~walll 0 50 100 98 -1028 0 0.02 ' 2 4.83 98.1 -1070 0 NSA Thr X v 99 1072 0 0.02 ? 1 4.79 100 1113 0 0.02 7 ? 4.82 IO1 4149 0 0.02 7 3 1.80 102 1191 0 0.02 6 ) 1.82 10 4' 3.1 0 0. 1 5 1 1.81 10:1 1 77 0 0. 8 1 4.81 105 1319 0 0. 1 0 4.79 106 -1360 0 0.01 1 1.8.3 107 1395 0 0.02 5 1.82 108 1137 0 0.02 7 1.80 109 1-180 0 0.01 5 1 4.81 110 152? 0 0.01 1 2 1.81 111 1559 0 0.01 1 1.8 112 1602 0 0.01 3 4.80 113 1615 0 0.02 1.82 114 1688 0 0.02 5 1.82 I 1 ~ 1730 0 0.02 ? ~ 4.84 116 1771 0 0.03 9 -1.81 117 4816 0 0.02 6 1.86 118 1850 0 0.02 6 1.83 119 1889 0 OA2 5 ~ 1.81 120 1931 0 0.03 ; ! 1.76 h I w i ~n . 121 1970 0 0.03 9 1.86 122 5009 0 0.02 6 1.83 123 5053 0 0.03 9 - 1.83 124 5093 0 0.02 5 ? 4.79 125 5131 0 0.03 9 1 4.77 126 5176 0 0.01 5 1 4.81 127 5220 0 0.02 5 2 1.83 128 5262 0 0.02 6 ~ 4.79 129 5302 0 0.02 S i :1.81 130 5310 0 0.01 1 1.77 131 5380 0 0.02 8 1.81 132 5118 0 0.03 10 ? 1.87 133 5160 0 0.0-1 13 1.82 Shallo~,v it5n . 131 5503 0 0.02 7 -1.80 135 5511 0 0.03 9 1 :3.78 136 5583 0 0.02 5 -1.8:3 137 5621 0 0.03 i 1 1.83 Shallotiv ittin . 138 5661 0 0.01 1.81 139 5701 0 0.01 1 ? 4.81 110 5717 0 0.01 5 1.82 141 5790 0 0.02 5 1 4.82 142 5831 0 0.03 ' 0 ? 1.82 143 5873 0 0.02 5 ? 4.81 1.34 5915 0 0.01 5 I 1.78 145 59.6 !'' n n l 1.8' I~b ;o' i ~ Penetration Body Metal Loss Body Page 3 PD~EPORT JOINT TABULATION S• Pipe: 5.5 in 17.0 ppf L-80 1~VeG: 17-08 Body Wall: 0.304 in Field: Prudhoe Bav Upset 4Va9: 0.30:1 in Compam~: BP Exploration (Alaska), Inc. Nominal LD_: 4.892 in Country: l,'SA Survev Date: December 2, 2007 Joint No. Jt. Depth (Ft.) Pen. l:pset ilns.i Pen. Body Ilns.j Pen. °o Metal Loss °~ btin. LD- jlns.j Comments Damage Profile l°o~~'~-Ij 0 50 100 147 6024 0 0.03 11 1 4.84 Shallow ittin . 118 6067 0 0.02 i 4.77 119 6109 0 0.02 5 i 4.83 150 615 0 0.0 ~ 4.82 I 1 6194 0 0.0' ' 4.8 152 6235 0 0.01 5 ~ 4.82 1 6 78 0 0.03 I l 1 4.78 h l w it ' n. 14 6318 0 OAl I 4. 155 6358 0 0.01 3 1 4.83 156 6-100 0 .0 ? 4.80 157 6-142 0 0.01 11 ~ 4.76 Shallow itlin . 158 6181 0 0.02 1.83 159 6527 0 0.03 11 -1.80 Shall w itlin . 160 6565 0 0.02 ~ 1.85 161 6608 0 0.03 ! 1 '. 1.83 Shallow itlin . 162 6611 0 0.0 ? 4.83 16 6686 0 0.02 1.8 161 6729 0 0.01 12 4.81 Shallow itlin . 165 676.7 0 0.0 8 4.81 166 68 I I 0 0.01 ' ~ ? -1.83 h w ittin . 167 6816 0 0.02 -1.8.1 1 6388 0 0.01 '. ~ 1.80 h I iv ittin . 169 6925 0 0.03 11 1.80 hallow itlin . 170 6968 0 0.0 5 1.85 171 '010 0 0.06 ~ I 4.81 Isol ted ittin 172 '015 0 0.05 1.82 Shallo~,v itlin . 173 7081 0 0.01 12 1.8:1 Shallo~,v itbn . 171 7121 a o.ol 3 4.81 175 7163 0 0.03 11 4.83 Shallow itlin . 176 7196 0 0.0:1 12 4.83 Shallow ittin . 177 7235 0 0.03 ] 0 4.83 178 7279 0 0.0:1 13 1.80 Shallow itlin . 179 7321 0 0.02 5 -1.81 180 7363 0 0.02 7 -1.8:1 181 7406 0 0.03 9 1 1.80 182 7116 0 0.02 6 1 1.85 183 7185 Q 0.03 10 ? 1.83 1$1 7521 0 0.02 Z 1.82 185 7566 0 0.02 6 1.86 186 7605 0 0.02 7 1.81 187 7617 0 0.0.1 i 2 ~ -1.78 Shallow ittin . 188 7691 0 0.02 5 1.8 189 7733 0 0.02 6 -1.81 190 7775 0 0.05 i 3 1.79 Shallow itlin . 191 7818 0 0.01 ~ -1.83 192 7862 0 0.03 i 1 ~ -1.77 Shallo~.v ittin . 193 7903 0 0.02 1.77 194 79-13 0 0.01 12 1.75 Shallow ittin . "195 798-1 0 0.03 9 1 4.0 196 8025 0 0.01 1 ? 4.80 Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI, Pipe: 5.5 in 17.0 ppF L-80 1;Ve9: Body Wall: 0.303 in Feld: Upset~b'al: 0.30-4 in Company. Nominal LD.: 4.892 in Country: Sun,•ev Date: 'CATION SHEET 17-08 Prudhoe Bay BP Exploration (Alaska), Inc. USA December 2, 2007 joint No. Jt Depth LFt.I Pen. :Jp.e: ,ns.~ Pen. Body ;Ins.; Pen. `o 'tiletal Lo,: 'o .4{in. LD. ilns.i Comment; Damage Profile I:°o walll 0 50 100 i 97 8069 0 0.0-4 12 I 4.80 Jhallaw ~iten~. t 98 8113 0 0.02 6 1 4.80 t 99 815' 0 0.0'2 S 1 4.86 200 8198 0 0.03 11 I 3.79 a~allrn~~ ittina. 201 8240 0 0.02 5 4.80 202 8283 0 0.03 Il 1 -4.84 J~allrnv itbnQ. 203 8326 0 0.02 5 1 4.83 244 8365 0 0.02 5 1 -4.83 205 808 0 0.01 3 ? 4.$3 206 8.451 0 0.0-4 13 ~ 4.77 snallrnti ~ittina. 206.1 892 q 0.01 5 I 4.79 FUP 206.2 8502 0 0 0 J 4.88 PACKER ~~ n ~ ~ ' ~ 1~ ' ~ '7 1~ I ~~ n I 2067 5550 0 0.02 0 ! 4.78 PUP 206.8 5565 0 0 0 ~~ N A PACKER 206.4 85,'•-4 0 0 0 N A X-o•:er 'Penetration Body 141etal Loss Body Page 5 11 r~ Tubing Detail ~ , ` Rig Nabors 2es Date 2 / 21 / 9 7 I~~ Well 17-8i Tubing 5.5 L-80 Butt Mod/LTC 8rd Tubing wt. 1 7 Well File 220 JTS ON RACK 206 JTS RAN 28.50 RT-BF 9009.36 FT ON RACK 843178 FT RAN RT-Pad Elev. Combination String--1-108 LTC, 109-220 Butt Mod 28.50 RT-GL ITEM Descri lion includes: SIZ TYPE CONNECTION JTS #-# REM ID OD LENGTH TOP BOTTOM W LEG w/Mute shoe 4.938 6.063 2.00 8560.27 8562.27 Seal ass . w/o seals w/7" sto collar 4.938 5.750 16.14 8544.13 8560.27 X-over 4.938 5.500 1.35 8542.78 8544.13 Ported sub 4.892 5.500 9.15 8533.63 8542.78 XN' Ni b 4.455 6.063 1.42 8532.21 8533.63 5.5" 17# L-80 MOD-BTRC PUP JT. 4.914 5.500 9.21 8523.00 8532.21 5.5" 17# L-80 MOD-BTRC PUP JT. 4.914 5.500 19.30 8503.70 8523.00 TIW HB-BP-T PKR 4.882 8.311 4.68 8499.02 8503.70 X-OVER 8rd Box X IBMod Pin 4.909 5.500 2.04 8496.98 8499.02 5.5" 17# L80 8rd PUP JT. 4.914 6.020 10.22 8486.76 8496.98 Jts# 1-108 5.5"17# L-80 8rd TBG 4.892 5.500 4412.96 4073.80 8486.76 X-OVER Mod BTRC Box X 8rd Pin 4.892 5.500 2.09 4071.71 4073.80 Jts# 109-156 5.5"17# L-80 Mod BTRG TBG 4.892 5.500 1967.51 2104.20 4071.71 5.5"17# L-BO Mod BTRC PUP JT 4.892 5.500 9.63 2094.57 2104.20 5.5" HES 'HRO' Landin Ni le w/ dumm installed 4.562 6.600 2.93 2091.64 2094.57 5.5" 17# L-80 Mod BTRC PUP JT 4.892 5.500 9.63 2082.01 2091.64 JTS # 157-206 5.5"17# L80 MOD BTRC TBG 4.892 5.500 2051.31 30.70 2082.01. FMC GEN.1 3 RETRO HGR 4.850 13.625 2.20 28.50 30.70 RT BF 28.50 28.50 53 SS CONTROL LINE BANDS RUN 12 MEMORANDUM . State of Alaska • Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, August 27, 2008 Jim Regg ~ P.LSupervisor ~~~~ ~~~~~~~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 17-08 FROM: John Crisp PRUDxoE BAY UNIT 17-08 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT 17-08 API Well Number 50-029-20602-00-00 Inspector Name: John Crisp Insp Num: mitJCr080822125659 Permit Number: 181-074-0 Inspection Date: 8/19/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 17-08 ~ Type IIIJ. W TVD ~ 8359 ~ IA ~ 550 ~ 2500 ~, 2460 ~ 2450 ~ p.T 181o7ao ~TypeTest SPT ~ Test psi ~I 2soo OA I aoo sso sso ~ sso j Interval oT~R P/F P ~ Tubing looo j looo looo I looo I, Notes' Post tubing patch to restore integrity and to renew 4 year UIC compliance. 3.6 bbl's pumped for test. ~~N~v SAP ~. ZO~~ Wednesday, August 27, 2008 Page 1 of 1 _ ~ WELL LOG TRA/VSMITTAL °~ ProActive Diagnostic Services, Inc. Y To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspectian(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petratechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,~ D ~~ and U?.~ ! ~ 1- C~-~~( ~~ S ~} I ~' 1C~5~r- ProActive Diagnostic. $eruices, Inc. ~ 9a- O Attn: Robert A. Riche: Swi~e Cest International Airport ~~ JUG ~~ ~~4~ Anchorage, AK 99598 Fax: (907] 245.8952 1 ] LeakDetection - WLD 08tJun-08 DS 17-16 1 BL / EDE 50-029-22286-00 ~ 2] Leak Detection - WLD 18,Jt~n-08 Signed Print Name: DS 17-08 1 BL / EDE 50-029-20602-00 Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.88952 E-MAIL "~ ::a.r.~. ~ ?irk; n,? Il.~ a~'t r;~ WEBSITE " ~r~.~. ,'e.. i ~^a C:\Dacumenfs and Settings\Owner\Desktop\Tiansmit_Conoco.doc • • SELL L - T~A/1~~/TT~4L `~ ~ ~,• ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and 2o~=,s~ ~i~~ a~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~ ppR ~ ~ 20~~ 130 West International Airport Road ~ Suite C Anchorage, AK 99518 Fax (907] 245-8952 1) Coil Flag 13 Apr-08 C-03B 1 E~ 50-029-2012402 2) Leak Detection - WLD 12-Apr~08 D5 17-08i 1 Color / EDE 50-029-20602-00 / ' ~~~~~~ _-r3 Signed : ~ b Q Date : ~_ - - _~ Print Name: ~~f}c^ ~ ~.~t~ V per- ~ ~ ~ , ,~~' PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (9071245-88952 E-MAIL : pdsanehoracae(a~saaermor+llog.coraa WEBSITE : vr~v.~neraaor+!loq.com C:\DocumenLs and Settings\Owner\Desktop\Transmit_BP.doc Update: 17-08 (PTD #1810740) Repressurization Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, October 22, 2007 11:18 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; Colbert, Chris M; Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Operations Supervisor; NSU, ADW WI Tech; NSU, ADW Well Integrity Engineer Subject: Update: 17-08 (PTD #1810740) IA Repressurization ~~7_ ~ i~l~~~~~ Attachments: MIT PBU 17-08 10-20-07.x1s~'la t Jim and Tom, Well 17-08 (PTD #1810740) failed an MITiA on 10!20107. The well has been shut-in and reclassified as Not Operable. Please see the attached MIT form. The current plan forward is to continue diagnostics with the well shut-in. «MIT PBU 17-08 10-20-07.x1s» Please call With any questions or concerns. Thank you, Andrea Hughes ~'~~A~~~®NOV ~. 3 20D7 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, October 16, 2007 3:31 PM To: 'James Regg'; 'tom_maunder@admin.state.ak.us'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng Cc: NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); NSU, ADW WI Tech Subject: 17-08 (PTD #1810740) IA Repressurization Jim and Tom, Well 17-08 (PTD #1810740) has recently exhibited signs of IA repressurization. During a recent bleed, and monitor, the IA quickly equalized with tubing pressure. The well is currently injecting produced water. The plan forward is as follows: 1. F: AOGCC MITIA 2. WIC: Consider AA application A wellbore schematic, TIO plot and injection plot have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/30/2007 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska}, Inc. FIELD /UNIT /PAD: Prudhoe Bay / PBU / DS 17 DATE: 10/20/07 ~ ®~~ OPERATOR REP: Andrea Hughes ~~\ AOGCC REP: ~1 Packer Dept Pretest Initial 15 Min. 30 Min. Well 17-08 Type Inj. W TVD 360 Tubing 1500 1500 1500 1500 Interval O P.T.D. 1810740 Type test P Test psi 2500 Casing 1500 2500 1560 1540 P/F F Notes: MITIA to eval TxIA communication. OA 420 500 420 420 Attempted test 4 times with the same results. Well Type Inj. TVD Tubing Interval P.T.D. Ty e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N = NoT Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 2007-1020_MIT_PBU_17-08.x1s 17-08 (PTD #1810740) IA Represst~tion • Regg, James B (DOA) Page 1 of 1 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~ Sent: Tuesday, October 16, 2007 3:31 PM ~~~~c~ I`;I ` (~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FSZ/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng Cc: NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); NSU, ADW WI Tech Subject: 17-08 (PTD #1810740) IA Repressurization Attachments: 17-08.pdf; 17-08 90-day TIO PIot.BMP; 17-08 Injection PIot.BMP Jim and Tom, Well 17-08 (PTD #1810740) has recently exhibited signs of IA repressurization. During a recent bleed, and monitor, the IA quickly equalized with tubing pressure. The well is currently injecting produced water. The plan forward is as follows: 1. F: AOGCC MITIA 2. WIC: Consider AA application ~.~-~,~~ NOV a $ 2007 A wellbore schematic, TIO plot and injection plot have been included for reference. «17-08.pdf» «17-08 90-day TIO PIot.BMP» «17-08 Injection PIot.BMP» Please call with any questions or concerns. --.-------_--- Thank you, ~ ~ ~-~. 1~~~=~(~ ~ ~r~-~o~s° (Z I. u~~ Andrea Hughes Well Integrity Coordinator ~%,~- ~~ `'~'~`~~~ i ~;,1? _ `~~Gf'i~ ~~~ 3~~ Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~~i 10/19/2007 TREE = FMC GEN 2 WELLHEAD - FMC ~N ACTUATOR -- Kb. eiE~ - _ ~ AXELSON ~ 71' BF. El_FV = _ _ KOP = 5700' h~1ax Angle = 22 @ 690D' Daturn MD = 9D22' Daturn TVD = 88D0' SS 13-3l8" CSG, 72#, L-8D, {D =12.347" I--} 2641' Minimum ID = 3,813" ~a $647` 4 1/2" CA C®DB-6 NIPPLE 5-1I2" TBG, 17#: L-80, D.0232 bpf, ID = 4.892„ 5-1;2" TBC, 17#, L-80; .0232 bpf; ID = 4.892 TOP OF 7" LNR 4-1 ~2° TBG-PC, 12.6#; N-80, .0152 bpf, !D = 3.958" 9-5r8" CSG, 47#, L-80, ID = 8.681" I 86E}5' i $649" $896' PERFORATION SUMIv1ARY REF LOG: BRCS ON 06%26/81 ANGLE AT TOP PERF: 12 cv 8985' Npte: Refer to Production DB far historical perf data SIZE SPF 9NTERVAL Opr'o;Sgz DATE 3-318" 4 8985 - 9D08 O 03127t89 3-118" 4 9090 - 9118 O 03115182 3-118" 4 9137 - 9165 O 03/15/82 4 9178 - 9213 C 03124184 3-3r8" 4 9178 - 9333 S D6!03;88 4 9313 - 9333 5 11?12/88 4 9394 - 9414 5 11112188 4 9417 - 9440 5 11f12l88 3-3 8" 4 9394 - 9440 5 06103,'88 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" I 9730' SA -dt3TES: t~_ 2092° I-I 5-1l2" HES HRQ SSSV NIP, ID = 4.562" 8499' --j 9-5(8" X 5-1l2" TMd HB-BP T PKR, ID = 4.882" $532' S-112" HES XN MP, ID = 4A55„ $534' 5-112" PORTED SUB $544' S-112'° SEAL ASSY L'V!O SEALS 1 w f7" STOP COLLAR, ID = 4.938" $576' 9-5r8" X 5-112" BOT 3-H PKR~ $5_ $6"-] 5-1/2" X 4-112° XO, ID = 3.958" $647' --~4-1 i2" CAtt1C0 LANDING NIP, lD = 3.813,. 864$" 4-112°' BKR BREAKOUT SUB $649` 4-1f2" WLEG, ID = 3.958" $642' EL.MD TT LOGGED 07'06/81 9271 ` H CMT & SAND PLUG (SET 12.-09(88 971 {-` I-{FISH- BKR PKR ELE4lr€ENT DATE REV BY COi41MENTS 07/02/81 ORIGINAL COMPLETIC 02124/97 LAST WORKOVER 12109100 SIS-iM14'H CONVERTEDTOCAN' 02i02iD1 SIS-N1D INETIAL REVISION 0~.•„4/D1 RNiTP CORRECTIONS 10,'26/02 CJ?TP PERF ADDITIONS DATE 'REV 6Y' COM~;IENTS 3i26f01 CJ;TP PERF ADDTIONS PRUDHOE BAY UNIT WELL: 17-08 PERMff No: X181 D740 API Na: 50-029-20602-00 SEC 22, T10N, R15E, 4121.95' FEL & 1223.96' FNL BP Explaration {Alaska) 4,OOG 3,000 i«. FAF.P;`-;P 2,000 1,000 0 7M 672007 1708 TID Plat 7031(2007 8M 572007 8131 !2007 9M 572007 __ -• Tbg -al- IA -~k- OA ~~ At-~ OOA likes-~ OOOA 10M 6(2007 10731(2007 • • u a m o g o ~-~' M LL ~"' O '¢ O V N O f O 3 ~ 1..1 O + a a 0 C7 ~ C.~ o 1011 17-08 Daily Allocated Injection Plot ~~ I°vl-o~74 °o - WHIP O °o SM O M ~ ~ o = - PJN+DNN N .~ o '= °o - MGI o GkS C • e Job# LOQ Description Date BL Color CD 15·12A 11211420 RST . PACK 06/25/06 1 17-08 11211509 N PROFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13.o6A 11217266 INJECTION PROFILE 07/12/06 1 P2.o1 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16.o4A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06 1 17.09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC.o7 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 1.!-51 11212873 USIT 06/28/06 1 04-31 11217264 US IT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04125/06 1 1 L2-18A 11217234 MCNL 04/06/06 1 1 L5.o9 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 Scblln~erger ~~>"'t:I r~~~i,r""':~'-\ I.;i \ ¡I;j~'¡;: ~ì;;.';'i f;-;¡ {^ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth 1"1- 01'LI UIQ WII ~ " Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 07/19/06 NO. 3880 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay e e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I Drill Site 17 12/21/03 Anna Dube Witnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 17-08 Type Inj. F TVD 8,359' Tubing 1,100 1,100 1,100 1,100 Interval 4 P.T.D. 1810740 Type test P Test psi 2,090 Casing 240 2,500 2,450 2,440 P/F P Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi CasinQ P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) " "~"~"'7"'""-',' 1'1,' ç«~ ~ 12,003 , " -""'~ "', I1J I\:. \!,.p ~ ~. . . ',' , . , MIT Report Form Revised: 06/19/02 2003-1221_MIT_PBU_17-08.xls STATE OF ALASKA ALASKA(~,L AND GAS CONSERVATION COC, MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 J-1Operation Shutdown J--JStimulate J--J Pull Tubing [--JAIter Casing J~] Repair Well [--J Other 5. Type of well: J--J Development J--J Exploratory i--J Stratigraphic J~ Service 4. Location of well at surface 2349' SNL, 955' EWL, SEC. 22, T10N, R15E, UM At top of productive interval 1359' SNL, 1134' EWL, SEC. 22, T10N, R15E, UM At effective depth At total depth 1225' SNL, 1157' EWL, SEC. 22, T10N, R15E, UM i---I Plugging J--J Perforate 6. Datum Elevation (DF or KB) RKB = 71' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 17-08i 9. Permit Number / Approval No. 81-74 397-012 10. APl Number 50-029-20602 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9730 true vertical 9560 Effective depth: measured 9695 true vertical 9531 Casing Length Structural Conductor 110' Surface 2569' Intermediate 8824' Production Liner 1125' feet Plugs (measured) feet feet Junk (measured) feet 9271 Cement & Sand Plug (12/88) Size Cemented 20" 300 sx PF 13-3/8" 3000 sx Fondu, 400 sx PF 9-5/8" 500 sx Class 'G' 7" 420 sx Class 'G' MD 110' 2641' 8896' 9730' TVD 110' 2641' 8747' 9560' Perforation depth: measured true vertical 8985'-9008', 9090'-9118', 9137'-9165', 9178'-9213' (Isolated Perfs: 9313'-9333', 9394'-9414', 9417'-9440') 8835'-8857', 8938'-8965', 8984'-9165', 9024'-9058' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 at 8562' Packers and SSSV (type and measured depth) TIW HB-BP-T packer at 8499'; 5-1/2" HES 'HRQ' SVLN at 2092' RE:C !V D 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIG J .... .Oil & 6as Cons. 14. Prior to well operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 15. Attachments ~'16. Status of well classifications as: J--I Copies of Logs and Surveys run ' / I-1 nil r-1 ~_~ l--J ~ Daily Report of Well Op_,er~tions J.., '~ ......... ~ ...... 17. I hereby certify that th~Hrore~oing is trL~nd correct to the best of my knowledge Signed ~ ~~~.~_~.~, Dan Stoltz _.: Title Senior Drilling Engineer Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Service Water & Gas Injector Date ~'-. Terrie Hubble, 564-4628 ,, ! Submit In Duplicat~x Progress Report Facility PB DS 17 Well 17-08 Page 1 Rig Nabors 2ES Date 16 June 97 Date/Time 16 Feb 97 10:00-17:00 17:00-17:30 17:30-19:00 19:00-19:30 19:30-20:30 20:30-21:00 21:00-21:30 21:30-23:30 23:30-00:00 17 Feb 97 00:00-00:30 00:30-02:00 02:00-04:00 04:00-06:00 07:00-11:00 11:00-12:00 12:00-12:30 12:30-15:00 15:00-18:00 18:00-19:00 19:00-20:00 20:00-20:30 20:30-00:00 18 Feb 97 00:00-00:30 00:30-01:00 01:00-02:30 02:30-04:00 04:00-04:30 04:30-05:00 05:00-05:45 05:45-06:00 07:30-12:00 12:00-12:30 12:30-13:00 13:00-14:30 14:30-14:45 14:45-17:30 17:30-20:15 20:15-20:30 20:30-21:30 21:30-23:00 23:00-01:00 19 Feb 97 01:00-02:00 02:00-02:30 02:30-03:00 03:00-06:00 06:00-08:00 08:00-08:30 08:30-12:00 12:00-12:30 12:30-18:00 18:00-18:30 18:30-02:00 20 Feb 97 02:00-04:00 04:00-06:00 Duration 7hr 1/2hr 1-1/2 hr 1/2hr lhr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 2hr 4hr 1 hr 1/2hr 2-1/2 hr 3hr lhr lhr 1/2hr 3-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2hr 1/2 hr 3/4 hr 1/4 hr 4-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/4hr 2-3/4 hr 2-3/4 hr 1/4 hr lhr 1-1/2 hr 2hr lhr 1/2 hr 1/2 hr 3hr 2hr 1/2 hr 3-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 7-1/2 hr 2hr 2hr Activity Rig moved 100.00 % Retrieved Hanger plug Fill pits with Seawater Held safety meeting Bullhead well Flow check Installed Hanger plug Removed Xmas tree Worked on BOP - All functions Held safety meeting Worked on BOP - All functions Worked on BOP - BOP stack Worked on BOP - BOP stack Bullhead well Flow check Held safety meeting Removed Tubing hanger Tested All functions Singled in drill pipe to 120.00 ft Installed Bridge plug Tested Wellhead primary components Removed Tubing head spool Held safety meeting Removed Tubing head spool Installed Seal assembly Installed Tubing head spool Tested Seal assembly Tested Wellhead primary components Worked on BOP - Wellhead connector Retrieved Bridge plug Conducted slickline operations on Slickline equipment - Retrival run Held safety meeting Rigged down Slickline unit Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Rigged down Logging/braided cable equipment Made up BHA no. 1 Fished at 35.00 ft Circulated at 8556.00 ft Circulated at 8556.00 ft Pulled BHA Laid down 4000.00 ft of Tubing Held safety meeting Laid down 8556.00 ft of Tubing Installed Bore protector Conducted slickline operations on Slickline equipment - Retrival run Made up BHA no. 2 Singled in drill pipe to 2000.00 ft Facility PB DS 17 Progress Report Well 17-08 Page 2 Rig Nabors 2ES Date 16 June 97 Date/Time 21 Feb 97 22 Feb 97 Duration 06:00-10:00 4 hr 10:00-11:30 1-1/2 hr 11:30-12:30 1 hr 12:30-13:00 1/2 hr 13:00-15:00 2 hr 15:00-17:00 2 hr 17:00-18:00 1 hr 18:00-18:30 1/2 hr 18:30-19:30 1 hr 19:30-21:30 2 hr 21:30-23:30 2 hr 23:30-00:30 1 hr 00:30-03:30 3 hr 03:30-06:00 2-1/2 hr 06:00-06:30 1/2 hr 06:30-08:00 1-1/2 hr 08:00-09:30 1-1/2 hr 09:30-10:00 1/2 hr 10:00-22:30 12-1/2 hr 22:30-00:00 1-1/2 hr 00:00-00:30 1/2 hr 00:30-01:30 1 hr 01:30-02:30 1 hr 02:30-03:00 1/2 hr 03:00-04:30 1-1/2 hr 04:30-06:00 1-1/2 hr 06:00-06:30 I/2 hr 06:30-10:30 4 hr 10:30-12:30 2 hr 12:30-13:30 1 hr 13:30-14:15 3/4 hr 14:15-15:00 3/4 hr 15:00-15:30 1/2 hr 15:30-19:30 4hr 19:30-20:30 1 hr 20:30-22:00 1-1/2 hr 22:00-06:00 8 hr Activity Singled in drill pipe to 8556.00 ft Circulated at 8561.00 ft Fished at 8561.00 ft Functioned downhole tools at 8550.00 ft Pulled out of hole to 100.00 ft Laid down fish Made up BHA no. 3 R.I.H. to 1539.00 ft Serviced Block line R.I.H. to 8545.00 ft Washed to 8735.00 ft Circulated at 8735.00 ft Laid down 5700.00 ft of 5in OD drill pipe Serviced Drillstring handling equipment Serviced Drillstring handling equipment Laid down 2800.00 ft of 5in OD drill pipe Pulled BHA Serviced Drillfloor / Derrick ' Ran Tubing to 8562.00 ft (5-1/2in OD) Circulated at 8562.00 ft Held safety meeting Space out tubulars Rigged up Tubing hanger Tested Seal assembly Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Circulated at 8534.00 ft Circulated at 2200.00 ft Set packer at 8499.00 ft with 2500.0 psi Tested Tubing Tested Casing Installed Other sub-surface equipment Rigged down BOP stack Installed Adapter spool Installed Xmas tree Tested Xmas tree ~01 STATE OF ALASKA l~"', ALASKA L AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2349' SNL, 955' EWL, SEC. 22, T10N, R15E, UM At top of productive interval 1359' SNL, 1134' EWL, SEC. 22, T10N, R15E, UM At effective depth At total depth 1225' SNL, 1157' EWL, SEC. 22, T10N, R15E, UM 12. Present well condition summary Total depth: measured 9730 feet true vertical 9560 feet Effective depth: measured 9695 feet true vertical 9531 feet Plugs (measured) Junk (measured) 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 71' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 17-08i 9. Permit Number 81-74 10. APl Number 50-029-20602 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay J-KILulI L Casing Length Size Structural Conductor 110' 20" Surface 2569' 13-3/8" Intermediate 8824' 9-5/8" Production Liner 1125' 7" Perforation depth: measured Cemented MD TVD 300 sx P F 3000 sx Fondu, 400 sx PF 500 sx Class 'G' 420 sx Class 'G' 8985'-9008', 9090'-9118', 9137'-9165', 9178'-9213' 110' 110' 2641' 2641' J AN 9Z3~0' 1997 9560' -. Alaska 0il & Gas Cons. Commissi0~ Anchorage true vertical 8835'-8857', 8938'-8965', 8984'-9165', 9024'-9058' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 at 8586'; 4-1/2", 12.6#, N-80, PC tail at 8649' Packers and SSSV (type and measured depth) BOT 3H packer at 8576'; 5-1/2" Camco BaI-O SSSV at 2191' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation February 11, 1997 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Contact Engineer Name/Numbec Winton Aubert, 564-4825 Prepared By Name/Number: 17o I hereby certify that t~f e~nd correct to the best of my knowledge Signed Dan Stoltz :~_.~d"~__.~/~~ Title Senior Drilling Engineer Commission Use Only Terrie Hubble, 564-4628 Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test /./' Location clearance Mechanical Integrity Test f Subsequent form required 10- Original Sign~. Approved by order of the Commission David W. J0hnst0r, Form 10-403 Rev. 06/15/88 [Approval No.,~_I~-''' ~j)J~j Appr¢~~er Date /~['~/{~ Sub~t In T~'iplicate~ Objective DS 17-8 RWO Summary DS 17-8, an injection well, is currently shut in due to parted 5-1/2" tubing at _+ 10'. This workover will replace the 5-1/2" tubing and restore tubing-annulus integrity so the well can be returned to injection. Pre-Rig Procedure 1. Notify AOGCC prior to commencing RWO operations. , RU coiled tubing unit. Place a sand plug in well from TD to _+150' above top per- foration @ _+8835' MD. 1 , , RU electric line unit. RIH, drift tubing and tag bottom. Make chemical cut in mid- dle of first full joint above 5-1/2" PBR @ _+8530'. Test 9-5/8" packoff and service lock down studs. Release pressure from tubing and inner annulus. Cumulate tubing and inner annulus with clean sea water. Freeze protect with diesel to _ 2000' MD. Install BPV. 6. Remove well house and flow lines, level pad, dig out cellar, and prep for rig. Drilling Rig Procedure 1. MIRU Nabors 2ES. ND tree, NU and test BOPE. 2. Pull 5-1/2" tubing from surface. 3. Fish remaining 5-1/2" tubing from above chemical cut. 4. Test 9-5/8" casing against sand plug, if possible. 5. Run custom overshot, new 5-1/2", 17 #/ft, L-80 completion and new 5-1/2" x 9-5/8" packer. 6. Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO rig. Prepared by: Operations Drilling Engineer ARCO Alaska inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 July 31, 1996 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Recent Injection Weil failures. Dear Mr WondZell: Attached are six documents, the last five are verbal notification reports which are made to document incidents on injection wells where we observed some form of pressure control failure. These reports are ARCO internal reports which identify the AOGCC contact and response. In all cases a failed MIT was the concluding data, and the problems were identified through other monitoring routines. The MIT's were run to confirm the extent of the problem, and none of these tests were routine MIT's that identified the problem.. All five wells are SI at this time, and a summary of what we have found on each well is listed in the first attachment. If you require additional information or clarification, please feel free to contact either Richard Ortiz or Dave Smith at (907) 659-5102. Very Truly Yours, David D. Smith · Annular Communication Engineer DDS/RAO Attachments cc: Marty Lemon Ron Bowden PRB-20 PRB-24 RECEIVED AU(3 0 5 1996 Alaska 011 & Gas Cons. Cmn~ Anchorage RECEIVED 11-08: AUG.O 5 1996 Injection Wen l:h-oblem Surmnary Alaska Oil & Gas ~ons. ~mmission Anchorage Initial indication of a problem was identified on 6/2/96. Since then we have determined that the PBR has unstung from the packer, leaving the Tbg in communication with the IA. It appears that the packer has failed and has slipped down hole and is resting on the liner top. We are unable to secure the well with a TTP or IBP due to the separation in pipe. However the well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$23,600.00 Current plans for the well: Keep the well SI until a RWO can be completed to effect the repair. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 12-23: Initial indication of a problem was identified on 5/30/96. Since then we have identified the problem as two holes in the tubing at ~7,466' and 7,482'. We have been unable to confirm 9 5/8" casing integrity at this time due to a small (~1.6 GPM) leak at the TrP. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$56,600.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 13-15: Initial indication of a problem was identified on 5/5/96. Since then we have identified the problem as two holes in the tubing at -4,516" and 4,520". We have confirmed 9 5/8" casing integrity with a Combo MIT completed to 3000 psi on 5/26/96. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$45,300.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 17-08: Initial indication of a problem was identified on 6/22/96. Since then we have identified the problem as parted tubing or separation from the Tbg hanger at or near surface. We are unable to secure the well with a TI? or IBP due to the separation in pipe. However the well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$3,300.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to m-establishing injection. 17-10: Initial indication of a problem was identified on 7/1/96. Since then we have determined that we have competent Tubing with an MITt to 3000 psi completed on 7/5/96. We have identified the problem as a hole in the 9 5/8" casing at -3,150'. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$15,100.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. IN--ION ~ ~ V~RBA~ NOTIfICaTION OF AOGCC P~R ~ ~ON ORDER #4 DATE: June 24, 1996 TIME: 03:05 P.M. NOTIFIED BY: Richard Ortiz AOC~C CONTACT: Blair Wondzell ~N: Injection Well 17-08 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 DI~U881ON: Well 17-08 is a water alternating with gas injection well that exhibited a tubing failure on 06/22/96. Wireline operations have shown that the tubing is parted. The well has been SI and Freeze Protected. Seven hours prior to the failure a 2000 psi MIT was performed indicating competent casing and packer. ACTION PLAN: The well is SI and Engineering is evaluating the well for a rig workover to repair/replace the tubing. Earliest possible repair for 17-08 is first quarter 1997. AOGC~ RESPONSE: Leave well SI until remedial action occurs. Sundry Notice Req'd at this time? YES NO X Sundry notice will be required for Rig Work approval. required post RWO & pre-injection. A state witnessed MITIA will be SIGNED: Annular Communication Engineer Orig: Annular Communication Engineer cc: Wells Superintendent, Wells Operations Supervisor Area Field Eng. FS 2 DS Supervisor FS Superintendent DS 17 Engineer // ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27o92 REFERENCE: ?~'/ 14-2 ~-r~- 14-3 72~'~ 14-4 ~z~/ }14-5A *'-14-5A ?~'~14-6 ~/ *~* ~16-9A /~ ~ 16-9A ~/-~ 16-13 ~-~ 16-15 ~/~ 16-21 ~ ~/16-22 ARCO CASED HO!.~- FINALS 3-3-92 PITS Run 1, 2-10-92 Leak Detect Run 1, 2-11-92 Prod Prof R~m 1, 2-29-92 Prod Prof R-n 1, 3-17-92 PITS R~_m 1, 2-13-92 Jewelry R~_m 1, 3-12-92 PITS R~_m 1, 2-24-92 Jewelry Run 1, 3-16-92 Prod Prof R~m 1, 2-25-92 Prod Prof Rim 1, 2-24-92 Prod Prof R~_m 1, 3-8-92 PITS R~_m 1, 2-26-92 InJ Profile Run 1, 2-20-92 PITS R~_m 1, 5" 5" 5" 5' 5" 5" 5" 5' 5" Cttlnco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Pleue sign and return the RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 attached copy u receipt of data. RECEIVED APR 3 0 1992 Alaska Oil/& Gas Cons. C~mm!_~sion Tmn~# 92080 # CENTRAL FILES # CJtEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FH, F~ R&D # BPX # STATE OF ~KA TEXACO The correct well name for this log is 14-5A. The correct well name for this log is 16-9A. STATE OF ALASKA ALA~ \ OIL AND GAS CONSERVATIOI(" REPOR OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing ~ Alter casing ~ Repair well Perforate O~er X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2349' FNL, 955' FWL, Sec. 22 T10N, R15E, UM At top of productive interval 1359' FN L, 1134' FWL, SEC. 22, T10N, R15E, UM At effective depth At total depth 1225' FNL, 1157" FWL, Sec. 22, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic ~,'~' 9730 feet Plugs(measured) 9560 feet Effective depth: measured 9695 feet true vertical 9531 feet Junk(measured) feet 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-8i 9. Permit number/approval number 81-74 10. APl number 50 - 029-20602 11. Field/Pool n ~~ ~~oo~ I~E~E! V CIJ DEC - ¢ 1991) Alaska 0il & Gas Cons. C0m~ssiOa Anchorage Measured depth 110' 2641' 8896' 9730' Casing Length Size Cemented True vertical depth Conductor 110' 20" 300 sx PF 110' Surface 2569' 13-3/8" 3000 sx Fondu & 400 sx PF 2641' Production 8824' 9-5/8" 500 sx Cl G 8747" Liner 1125' 7" 420 sx Cl G 9560' Perforation depth: measured 8985-9008'; 9090-9118'; 9137-9165'; 9178-9213' true vertical 8835-8857'; 8938-8965'; 8984-9165'; 9024-9058' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 8586' MD; 4-1/2", 12.6#, N-80, PC tail @ 8649' MD Packers and SSSV (type and measured depth) BeT 3H packer @ 8576' MD; 5-1/2 Camco Bal-0 SSSV @ 2191' M D 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Prodvction er Injectign Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 69O6 7263 Tubing Pressure 602 701 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,Signed Title Sr. Area Engineer Date Form 10-404 Rev 06/15/88 566 C: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE . ( ( DS 17-08i DESCRIPTION OF WORK COMPLETED CHOKE PACKER INSTAllATION 2/1 6/90: RIH & tagged Bridge Plug (set 5/14/89 @ 9046' MD), at 9211' MD. 2/17/90: RIH & fished Bridge Plug from wellbore. RD. 2/26/90: RIH w/3-3/8" Choke Packer, and set at 9052' MD. POOH. RD. ~: No orifice has been run in the Choke Packer; it is blanked off. Returned well to seawater injection, and obtained a valid injection rate. REC?EIVED DEe ... 4 1990 Alaska Oil & Gas Gons. Commission Anchorage ARCO Alaska, Inc. (' Prudhoe Bay~. =~ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 30, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-8, Approval No. 8-589 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-13) Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA[' AND GAS CONSERVATION Cqr,' ~IlSSION n REPORT b,: SUNDRY WELL OPF_.rIATION 1. Operations performed: Operation shutdown Stimulate :-' Plugging Perforate X Pull tubing Alter ca_sing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2349' FNL, 955' FWL, Sec. 22 T10N, R15E, UM At top of productive interval 1359' FN L, 1134' FWL, SEC. 22, T10N, R15E, UM At effective depth At total depth 1225' FNL, 1157" FWL, Sec. 22, T1 ON, R15E, UM 5. Type of Well Development :X Exploratory StralJgraphic 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-8 9. Permit number/approval number 81-74/8-589 10. APl number 50 - 029-20602 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9730 feet Plugs(measured) true vertical 9560 feet Effective depth: measured 9695 feet true vertical 9531 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF 110' 110' Surface 2569' 13-3/8" 3000 sx Fondu & 400 sx PF 2641' 2641' Production 8824' 9-5/8" 500 sx CIG 8896' 8747" Liner 1125' 7" 420 sx CIG 9730' 9560' Perforation depth: measured 8985-9008'; 9090-9118'; 9137-9165'; 9178-9213' true vertical 8835-8857'; 8938-8965'; 8984-9165'; 9024-9058' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 8586' MD; 4-1/2", 12.6#, N-80, PC tail @ 8649' MD Packers and SSSV (type and measured depth) BOT 3H packer @ 8576' MD; 5-1/2 Camco Bal-0 SSSV @ 2191' MD 13. Stimulation or cement squeeze summary ~'~ii ~'"~ iii"~ ~ ~¥;' 14. Intervals treated(measured) See attached Treatment description including volumes used and final pressure Representative Daily Average pr0du~ion 0r Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 4821 -- 364 Subsequent to operation 5591 -- 875 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .. 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. ~igned __~~~~,c~~ Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 215 Richard A. Clausen 263-4538 SUBMIT IN DUPLICATE DS 17-8 Post Job Summary The Application for Sundry Approvals had proposed to (1) Perforate the Sag River Interval and (2) pump a hydraulic propped fracture treatment into the Sag River perforations. The hydraulic fracture treatment was not performed. In its place an inflatable through tubing packer was run and placed between the Sag River and Ivishak perforations. A sized orifice was placed in the packer to restrict the injection of waterflood water into the Ivishak perforations thereby allowing more water to enter the Sag perforations which was the goal of the fracture treatment. Sequence of Events: 1. Perforate Sag River interval with Halliburton 3 3/8" Tru-Jet XVI guns, 4 spf at 8985'-9008' MD (referenced to BHCS log dated 6/26/81) on 3/27/89. 2. MIRU with coil tubing on 5/11/89 and RIH with inflatable packer. Set packer at 9060' MD which is 30' above the top Ivishak perforation. 3. MIRU with slickline on 5/12/89 and RIH with injection orifice receptacle with 1/2" orifice installed to latch onto the inflatable packer at 9060' MD. Packer came loose and was pushed down to 9240' MD. RIH and retrieve packer and orifice. 4. MIRU with coil tubing on 5/14/89 and RIH with inflatable packer. Set packer at 9075' MD which is 15' above the top Ivishak perforation. 3. MIRU with slickline on 5/15/89 and RIH with injection orifice receptacle with 1/2" orifice installed and latched onto the inflatable packer at 9075' MD. 4. Place well back on injection. ARCO ALASKA, INC. F'.O. BOX iQ0360 ANCHORAGE, ALASKA 995t~ DATE: 8-tt-8~ REFERENCE: ARCO CASED HOLE FINAL~ ?-i -~,-.~,'~o-89 PRODUCTION PROFILE RUN t, 5' 7-!2 ?-28-8~ F'RODUCTION PROFILE RUN 7-23 7-34)-89 F'RODUCTION PROFILE RUN ~, 5' 9-8 7-26-89 INJECTION F'ROFILE RUN t, 5' 12-3 8-4-89 PERF RECORD RUN t, 5' i2-7A 8-4-8~? PERF RECORD RUN i, 5' i4-36 7-29-89 INJECI'ION PROFILE RUN t, 5' ~5-~ ?-3~-89 PRODUCTION PROFILE RUN ~ ~ 5' ~7-8 ?-27-8~ INJECTION F'ROFILE RUN ~ ~ 5' PLEASE SIGN AND RETURN THE ATTACHED COP~Y AS RECEIPT OF DATA. DISTRIBUTION CENTRAL FILES CHEVRON DAM EX]'EN$ I ON EXPLORAT I ON EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R & D BPX STATE OF ALASKA TEXACO CAMCO CAMCO CAMCO CAiiCO $CH $CH CAMCO CAMCO CAMCO ARCO AL:-~KA INC ~" 0 BOX i :" ,,, .~ .~ · ANCHORAGE, ALASKA 995i DATE ' 5-i 2-89 REFERENCE' ARCO CASED HOLE FINALS i-t9 5-J-89 PRODUCTION PROFILE RUN ~ , ':2-2t 5-4-89 COLLAR/PERF RUN 5-j~, 5--5-89 COLLAR/PERF RUN 7-~ J 4-J5-89 F'RODUCTION PROFILE RUN J, 7-~ 4 4-3¢3-89 COLLAR/PERF RUN ~, 9-3 4-28-89 F'RODtJC'FION PROFILE RUN ~, 9-6 4-29-89 PRODUCTION PROFILE RUN ~, 9-7 4-3()-89 I-'I<UDU~IION PROFILE RUN J, 9-o,. 4-27-89 PRODUCT~'ON ,. F'I~¢OF ILE RUN ~ j - t 4-29-89 COLLAR/F'ERF RUN ~3-26 4-26-89 FL[)WHETER ]"EMP SURVEY RUN ~3-33 4-26-89 FLOWHETER TEMP SURVEY RUN J 7-8 3-27-89 COLLAR/F'ERF'" RUN WGI-2 5-2-89 PFC RUN ~, F'LEA,'.]'E SIGN AND RETURN THE AI'TACHED COPY A,? RECIFIF'T Ok DATA. 5' 5' 5' 5' 5' 5' C A i"i C' [3 ATLAS' Ai"[..A~' CAMCO A T L A C A M C 0 UAt-~t.;U C A i4 C 0 CAMCU ,, . ~ A~ C A f.i C 0 CAMCO HLS RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-J529 DISTRIBUTION '"'.if CENTF(AL FILES :~: CHEVRON D & M ~ EXTENSION EXF'LORATION · "- EXXON MARATHON ~ MOBIL · "' F'H!LLIP$ 'If F'B WELL FILES R&D $ BPX $ -STATE OF ALASKA · .-'"' I'EXACO · .,,,,,.,,~ 0il & ~as C~ns. "- ,---' - AncJ:orage ARCO ALASKA, INC. (' P,,O,, BOX i(~:S~ ANCHORAGE, ALASKA 995t DATE' 5-9-89 REFERENCE' ARCO CASED HOLE FINALS t-8 4-t 6-89 INJECTION PROFILE RUN i t-24 4-8-89 PRODUCTION PROFILE RUN i, 5' -1 ~ 4-2S-89 TEMP RUN 2-i4 4-i 5-89 PRODUCTION PROFILE RUN i, 5" 2-iT 2-t7-89 S'PINNER/TEMP/FLUID DENS/GR RUN t, 5' 2-23 4-t 3-89 F'RODUCTION PROFILE RUN t, 5' 4-7 4-1 6-89 PRODUCTION PROFILE RUN t, 5' 4-~ 4-t8 89 SF'INNER/TEMP RUN 7-'~ 4-t0-89 ' LEAK DETECI'ION RUN 9-t 4-t 3-89 PRODUCTION PROFILE RUN i, 5 tt-3 4-24-89 LEAK DETECTION RUN t, 5' tt-t0 4-t4-89 LEAK DETECTION RUN t, 5' tt-i6 4-i2-89 PRODUCTION PROFILE .. RUN i i2-?A 4--i9-89- PRODUCTION LOGGING SVCS· RUN i2-iO 4-2i-89 GAS LIFT SURVEY RUN i, 2' i 2-29 4-23-89 TEMP RUN f3-3 4-t4-89 LEAK DETECTION RUN t, t3-8 4-22-89 PRODUCTION PROFILE RUN t3-23A 4-23-89 MI INJECTION F'ROFILE RUN t, 5" t4-2 4-t 9-89 PRODUCTION PROFILE RUN t4-t8 4-6-89 PITS RUN t, 5" i6-ii 4-24-89 LEAK DETECTION RUN i t 7-6 4-1 9-89 INJECTION PROFILE/TEMP I<UN i , 5" i7-8 4-i7-89 MULTI-RATE INJECTION PROFILE RUN t, 5' f8-3 4-2i-89 F'RODUCTION LOGGING SVC$.. RUN t, 5' t8-7 4-2t-89 F'RODUCTION LOGGING $VC$. RUN t, 5' PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIF'T OF DATA. RECEIVED Bf , r ATO-t 529 ... .2x.}:}~.~)xa-Oil ~uas cons. ~ummtso: -~TRAN3'~ 89~7 ~. · ...... :,~ . ~ ~ .... . " D~$~RIBUI'ION CENTRAL FILES ~ PHILLIPS CHEVRON ~ ~ MOBIL EXTENSION EXPLORATION ~ ~ BPX EXXON ~ ~ STATE OF MARATHON ~ TEXACO ALA~'KA CAMCO CAMCO CAM(;() CAMCO CAMCO CAMCO CAMCO 0 T t $ CAMCO CAMCO CAMCO CAMCO CAMCO ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMUO A"i'L A ~,' ATI_A,? * THE CORRECT AF'I~ FOR 2-12 IS ** THE CORRECT API~ FOR t6-~ IS ARCO ALA~'KA, INC P,O. BOX ANCHORAGE, ALASKA DATE' 8-26-88 REF'ERENCE: ARCO CASED HOLE FINAL t-i S ?-i i-88 COLLAR/PERF RUN i , 5 2-iA 8-t7-88 PERF RECORD RUN i, 5" 2-26 7-22-88 COLLAR/PERF RUN i, 5' 3-2i 8-i 8-88 COLLAR/F'ERF -' RUN 5-2 8-i6-88 COLLAR/TEMP RUN t, 5" 5-6 8-S-88 PRODUCTION PROFILE RUN i, 7-t 5 7--9-88 COLLAR/PERF RUN t , 5" 7-28 8-20-88 PFC RtJN 1 · ~ · ~ -- ~.~ 7-29 8--.:.0--88 FC RUN i,~:'" 9-.i '7--"7-88 COLLAR/PEI~:F' RUN i, 5" t4--S 8-i~-88 L. EAK DETECTZON R. UN i t 5-i 4 7--'25--88 COLL. Ai~/F'ERF' - RtJN i . t6-i"4 8/i2-t4/88 PRODUC'I'ION PROF: GAS' L. IF"i" F(UN i 7-5 8-t 0-88 , 6A~' LIF'i' 'I'Ef'iF' RUM i , t7-8 8-t~-88 INJ PRO 'i'E)qP F'LOW~ETER RUN t '7-i 4 8-t t -88 PRODUCi'~ON F:'i:(UF'.LLE I:(UN i 8'-t'6 8-5-'88 F'I'F';J R. UN 1 F'WDWt-i '7'-i8-88 ..... '"'" 5 U(JI..L.~.~I~ i t::' E i~'. F' RtJN FLE:.A.,E .*:,'IGN AND RE't"LJRN TH'E AT'f'ACHED COPY AS R'ECEIP'F OF DAf'A. GEAR SCH GEAR ATLAS' CAMCO CAMCO GEAR Al LA~' A 'f' L. A G E A R [; A d C 0 [;A~'ICO UR~CtJ L;Rr.iUO CAMCO CAMCO GEAR RECEIVED BY ' .------~:~--~.,, HAVE A NICE DAY! 'fRANS ~8855i~ · A P F:'R 0 V E D ....... ~ ~ Alaska 011 & Gas Cons. Corem'ss'on ~chorage ~ ~ 5' T R i B U T I ~ N ~ CENTRAL Fll, ES' ~: PHILLIPS ~ CHEVRON F'L'~ WELL. F':[LE$ D & M R & D ~ EXTENSION EXF'I_OI~:A'f' ~ ON :~ ~AF'C . '",. EXXON ~: :¥'f'A'I'E OF:' ALAZ~'KA M A R A T H 0 N ~ T E X AC 0 :~' MOBIL ARCO Alaska, Inc.f~ Prudhoe Bay E.gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-8 Permit No. 81-74 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RAC/jp Attachment cc: Standard Alaska Production Company J. Gruber, ATO-1478 Pi(DS 17-8)W1-3 detailing work to be WELLS2/175 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM $SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate '~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 72 ' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 2359' FNL, 955' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1359' FNL, 1134' FWL, Sec. 22, T10N, R15E, UM At effective depth At total depth 1225' FNL, 1157' FWL, Sec. 22, T10N, R15E, UM 7. Well number DS 17-8 8. Permit number 81-74 9. APl number 50-- 029-20602 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9730 feet true vertical 9560 feet Plugs (measured) Effective depth: measured 9695 true vertical 9531 Casing Length Size Surface 110 ' 20" Intermediate 2569 ' 13-3/8" Production 8824 ' 9-5/8" Liner 1125 ' 7" Perforation depth: measured 9090-9118'; 9137-9165'; 9178-9213' true vertical 8938-8965'; 8984-9011'; 9024-9058' Tubing (size, grade and measured depth) feet feet Junk (measured) Cemented Measured depth 300 sx PF ll0' 3000 sx Fondu & 2641' 400 sx PF 500 sx C1 'G' 8896' 450 sx Cl 'G' 9730' ~ueVerticaldepth 110' 2641' 8747' 9560' 5½", 17#, L-80, PCT @ 8586' MD'; 4½", 12.6#, N-80, PCT tail @ 8649' MD Packers and SSSV(type and measured depth) ~0~ 3~ pac~er @ 8576' MD; 5½" CamCo Sal-0 SSSV @ 2191' ND 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July 1988 14. If proposal was verbally'approved Name of approver ~, ....,,~_ ~-, .~ , , Date approVed 15. I hereby certify that the foregoing is tru~'~n~'c'o"~rect t° the~'~~~~ledge Signed ~~~ ~~~ Title Operations [~ee~ Ha~a~e~ Date Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved bY ~-4 ~ tb~Ye°~doemr re°Is s, o n Form 10-403 Rev 12-1-85 ~ / / S~'bmi~'in triplicate WELLS2/175~R. A. Clausen, 263-4538 Drill Site 17-8 Proposed Hydraulic Fracture Treatment ARCO Alaska Inc. proposes the following hydraulic fracture procedure. I . e 1 1 . , . . 10. 11. 12. 13. Pump fullbore sand slurry to fill casing from PBTD to 9040' MD. Perforate Sag River interval from 8985' to 9008' MD. Run pump-in temperature test to determine if there is cement isolation above and below the Sag River Zone. If step 3 shows that there is insufficient cement for isolation, continue with step 5. If step 3 shows there is cement isolation, then skip to step 7. Perform CTU cement squeeze to seal casing both above the below the Sag interval. Reperforate Sag interval 8985'-9008' MD. MIRU fracturing service company Pressure annulus to 2500 psig. Pump propped fracture treatment for Sag River zone using gelled water and Carbolite proppant at 20 bpm. a. 100 bbl Formation breakdown and shutdown for ISIP. b. 250 bbl Pad c. 120 bbl Slurry :11-14 PPG d. 210 bbl Flush RDMO fracturing service company. MIRU slickline unit and tag fill, Cleanout sand to 9260' MD with CTU. Place well on injection into both the Sag and Ivishak intervals. Run spinner log to determine post frac injectivity. 6 5 4 2 COILED I'UB]~Nt3 UNIT BOP E0U ! p~IE aT 1. ~)00 PSi 7" WELLHEAD CONNECTOR FLANGE 2. ~ PSt 4 1/16" PIPE RA~S 3. 5000 PSI 4 1/6" HYD~L~ SLIPS 4. ~X)O PSI 4 1/6" SHEAR RAMS 5. ~K)OC) PSI4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 BOP E, pU] PH,EN'I' 1. 5000 P.~I 7" WELLHEAD CONNECTOR IrLANO! 2. 5000 PS;I WIR£LIN[ RAUS (VARIABLE ~3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PkCK-Orr DATF' 7-~ ~-RR RFFEREN£F' ~Rr:n £AKFI) HOl F F TNAt COI..I..AR AND PFRFRRATTNg I..0~ g~MMA RAY COI_I..AR I...~R C~I..I. AR AND PFRFOR~TTNg I. ng £BI..I...AR AND PFRFORATTNR I.~g £fll I..AR AND PFRFnRATTNg I_OC Cnl. I...AR AND PFRFORATIN~ l.O~ RI IN t , r.,-.,. RI.IN i: 5 · F, FAR R!IN i; ~' F, FAR RI.IN t-A: 5" F, FAR I;,'IIN i . ~' R'llN t : 5' F;FAR I:'[.FA,~F ,~TF, N AND RFTIIRN TI-IF ATTAENFD gnF, Y A~ RFRFTF'T 13F DATA.. RI-.--. C F_ l; VlF T) BY HAVF A NTCE DAY! F'FGgY RFNNFTT TRAN,~ ~8R472 AF'F'ROVE)) DT,..,TRI AllTI ON CENTRAl._ CHEVRON ~ EXTF'N,~!ON FxP.I.. RRAT!ON '"' E-.×%FIN MARATNFIN ~ MOP, II '"'-,-F'H l: I...l.T. F ,., F'P, WE'.t...t... FII.. F2 -"- · ,,-'"' ,~TATE OF' AI...A,.?K'A · ,.- T .F. ¥. A C.f'l' ARCO Alaska, Inc.'~(' Prudhoe Bay 'r_,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 27, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 17-8 Permit No. 81-74 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SA~/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 17-8)W1-3 detailing work to be WELLS 2 / 167 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension © Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~'~Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 72' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 2359' FNL, 955' ~rL, Sec. 22, T10N, R15E, t~ At top of productive interval 1359' FNL, 1134' FWL, Sec. 22, TION, R15E, UM At effective depth 1225' FNL, 1157' FWL, Sec. 22, TiON, R15E, UM At total depth , 7. Well number DS 17-8 8. Permit number 81-74 9. APl number 50-- 029-20602 10. Pool Prudhoe Bay. Oil Pool 11. Present well condition summary Total depth: measured true vertical 9730 feet 9565 feet Effective depth: measured 9695 feet true vertical 9531 feet Casing Length Size Conductor 110' 20" Surface 2641' 13-3/8" Production 8896' 9-5/8" Liner 1125' 7" Plugs (measured) Junk (measured) Cemented Measured depth ~ueVerticaldepth 300 Sx ll0' ll0' 3000 Sx 2641' 2641' 500 Sx 8896' 8747' 450 Sx 8605-9730' 8462-9565' Perforation depth: measured 9090-9118';, 9178-9213'; 9137-9165' true vertical 8938-8965'; 9024-9058'; 8984-9011' ~bing(size, grade and measured depth) 5~", 17#, L-80, 'plastic-coated tubing @ 8586' Packers and SSSV(type and measured depth) BOT 3-H 4.75 I.D. Packer @ 8581' MD; Camco Bal-0 SSSV nipple @ 2191' M? 12.Attachments Description summary of proposal [] Detailed operations program E~ BOP sketch 13. Estimated date for commencing operation May 1988 14. If proposal was verbally'approved Name of approver Date approved 15. ' hereby~ertify 'tha/t,)t~,~ fo,~going is true and correct to the best of my knowledge Commission USe Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Operations Engineering Manager Approved by [ '. ,.. ~' ,,(.~ ~,,~/~~ Commissioner Form 10-403 Rev~'l'Cf1-85' WELL~2/147 fS A Digert, 263-4290 the commission Date Submit in }riplicate ARCO Alaska, Inc. proposes to add perforations in DS 17-8 for a selected interval within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operations. Currently DS 17-8 is an injector. The expected static bottom-hole pressure is 3850 psi. Sea water will be in the well when the perfs are shot. Perforati on Data- BHCS CNL/GR/CCL Footage Footage Flow (06/26/81) (07/06/81) MD TVD Unit SPF 9313-9362' 9313-9362' 49 48 V2 4 9368-9440' 9368-9440' 72 70 V2 4 Ref' BHCS 6/26/81 JRE/O04-5 II i ~ I 1. '5000 PS1 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PS1 WlRELINE RAMS (VARIABLE SIZE) ,3.5000 PS1 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-OFF Id ! REL ! NE BOP EOU ] PHENT DATE: 2-i6-88 REFERENCE: ARCO CASED HOLE FINAl_ t-4 ~-22-88 ~-t3 t-22-8R ~-t6 ~-2t-88 t-t9 t-28-88 t-25 i-2e-88 t-23 t-24-88 4-7 2-4-88 4 ~8 2-3-88 4-22 t-29-88 7-t3 2-5-88 9-34 t-23-88 tt-t8 t-3e-88 tJ-t t-24-88 t3-t7 t-23-88 t3-28 i-22-88 t4-22 t-27-88 t6-2 t-25-88 t6-5 t-28-88 t6-t9 2-t-88 t6-t9 t-28-88 t6-2e t-29-88 t7-2 t-3t-88 t7-~e t-25-88 PR, PRFLE/FM/TP/FD/W RUN FL. OWMETER RilN PRD,,PRFLE/FM/TP/FD/W Ri. IN PRO., PRFL E/HPFM/TEMF'/DEN RLIN PRO ~ PRFI_E/HPFM/TEMP/DEN/WHI.IT RUN PTT,~/TEMP RI. IN F'TTE/GR/TEMP RI.IN PIT,? ~:' RUN F'I T,.~/TEMP :t RIJN P I T£ RUN FI_OWMETER RUN PIT~/TEMP RUN PRO ~ F'RFLE/HF'FM/WHUT R!JN PRO ,. PRFLE/HF'FM/WH[,IT/GR RUN GAMMA RAY RUN F'RD ,, F'RFL. E/HPFM RUN PRO,, PRFLE/EPIN/TEMP/WHUT RUN IN,..I~PRFLE/FM/TP RUN INJ, PRFLE/HPFM/TEMF' RI.IN ., P I T,.~/TEMF' RUN F'RODIJCTION PROFILE R. UN F'RD, PRFI-.E/$P IN/TEMP/GR/WHUT RUN PRD ,, F'RFLE/HPFM/GR/WHUT RUN INJ., F'RFL E/HPFM RUN INJ,PRFLE/HPFM RUN F'LEAXE SIGN AND RETUR~ THF..~TTACHED COPY A,~ R~.PT .DF DATA, PEGGY BENNE~ ..... ATO-~ 529 TRAN.~ ~88i APPROVED D I ~TR 18I.IT I ON CENTRAl_ FILES ~ PHII_.I._IP~ CHEVRON PB WELL FTIEX D&M R&D EXTENSION EXPLORATION . ' SAF'C EXXON ~:. STATE OF ALASKA MARATHON . ~ TEXACO MOBIl_ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCn CAMCO CAMCO' CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DATE: 2- t 6-RR REFERENCE: ARCO CASED HOLE FtNAI. PR , PRFI..E/EM/TP/FO/U FI. OUMETER t-22-@8 -~~~-27-88 &-5//~-28-88 ~-28-88 ~~25-88 PRD.PRFLE/FM/TP/FD/W RI.IN PRD,PRFLE/HPFM/TFMP/DFN RIIN PRD,PRFL.~/HPFM/TEHP/DEN/WHIIT RUN PIT£/TEMP RIIN PITS/CR/TEMP PIT2 ~:' PIT~/TEMP PITE FLOWMETER PIT2/TEMP PRD.PRFLE/HPFH/WHL~oiI&G~ Cons. Com~g~CRIJN F'RD,PRFL.E/HPFM/WHE~GR ~chorage RUN _~" RIJN t , 5" RUN t, 5 · RUN t ~ 5' RUN t , 5' RUN t ~ 5' RUN t , 5' RUN,~ ~ 5' RUN ~, 5' RUN t / 5' RUN ~, 5' G~MMA RAY PRD,PRF[.E/HPFM PRD.PRFLE/$PIN/TEMP/~HUT .~ IN,J,PRFLE/FM/TP . INJ,PRFLE/HPFM/TEMP PIT£/TEMP PRODUCTION'PR~FILE PRD.PRFLE/HPFM/GR/~HUT ~NJ,PRFLE/HPFH INJ,PRFLE/HPFH CAMCO CAMnn CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAM~O CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PLEA2E SIGN.AND RETURN THE ATTACHED COPY__s.,,_ . . _A2 RECE!~ . ~ R .F. CE~VE~ ~Y ..... ~ -- ~ '.r,' TRAN,~ ~88t05 ~ / ~ ~ - ~ / ...... ............. ~ CHEVRON PB UELL FTL E,~~~/ ~ EXTENSION EXPLORATION ~ ~F'C ~ ~ / . EXXON ,~ . 2TATE OF AI..A2~A ~;;, ' / MARATHON ':":~ ~ TEXACO /" ~;~' . / DATE: 2-t6-88 R .F..FERENCE : ARCO CASED HOLE FT. NAI.. t -4 t -22-88 t-t 5 t -22-RR t-t 6 t-2t-88 t-t 9 t -2G-88 t -25 t -2~)-88 i -25 ~ -24-88 4-7 2-4-88 · 4-~ g 2-~-88 a-22 t -29-88 7- ~ ~ 2-5-88 9-54 ~ -25-88 ~ ~-~ 8 ~ -~9-88 ~ 5-t ~-24-88 ~ ~-~ 7 ~ -25-88 ~J-28 ~ -22-88 t4-22 ~ -27-88 ~ 6-2 ~ -25-88 t 6-5 ~ -28-88 ~ 6-~ 9 2-~-88 ~ 6-t 9 ~ -28-88 ~ 6-2e ~-29-88 ~ 7-2 ~-5~-88 ,~t~8;- ~ -25-88 ~ 7-t 9 t -25-88 PR, PRFI_E/FM/TP/FD/W RI.IN Fi, OWMETER RI IN PRO,, PRFLE/FM/TP/FO/W RI.IN PRO. PRFL E/HPFM/TFMP/DFN RI. IN PRD, PRFI..E/HPFM/TEMP/DEN/WHIIT RI_IN P.T T.~./TEMP RI. IN F' .'[ T,.~/C,R/TEMP RI.IN P.T T,~ RLIN P I T,~/T .F..MP . ~, Ri.IN P.T. T,~ RI. IN FI_OWMETER RUN PIT,9/TEMP PRD, PRFLE/HPFM/WHI..IT R. IJN I::'RD, PR'FL.E/HF'FM/~H[IT/C,R RI. IN GAMMA RAY RUN PRO, F'RFLE/HPFM RUN PRO. F'RFLE/$P IN/TEMP/WHLIT RUN I NJ. PRFLE/FM/TP RUN INJ.PRFLE/HPFM/TEMP RUN F' ]' T.~/TEMP. RUN PRODIJCTION PROFILE RtJN PRO. PRFL.E/~PIN/TEMP/GR/WHUT RUN F'RD . PRFI_E /HF'FM/ GR /WHIJT RLIN I NJ. F'RFI.. E/HPFM RI.IN INJ ,PRFLE/HPFM RUN R.F. CEIVEi .... 5.:./_J_'SJ._?_. ?- ....~ -r' ......... --'-~.: n" Uui[',~5:3%- .... RECEIPT OF DATA., ~AMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PEGGY BENNETT ATO-tD29 TRAN~ ~88t85 APPROVED P .,. STR I BUT I ON .. -,,-- CENTRAl_ FII_E.~ .~' CHEVRON D & M -,-- EXTEN,~ION EXPLORATION ~,,- EXXON MARATHON · MOBIl_ ~ PH I1_1._ IP,~ PB WELL FTI R & D ~ ,.~AF'C · ,~ ,.~TATE OF AI..AEKA '~ TEXACO ARCO Alaska, Inc. Anchorage, Alaska. 995~0 DATE' March 27, i986 REFERENCE" ARCO Cased Hole Final DS ~7-6 .-~--86 Inj Spinr~er/Temp Run ~ 5' DS ~7-8 ~---~4-86 Inj Spinner/Ter,'~p Run ~ 5" DS .'i7-t0 "'~-~-86 Inj ..Spinr, er/Temp Run t 5' DS t. 8-~ .~ t0-3t-85 CNL Run DS t 8-~ t8-3t-85 Ep i log Ruin C8 ~ICZ 0 Ca nic o C8 nIC o DA DA F'[ease ~ign and return fhe a$*,ached COpy as receipf of da~a. HAVE A. NICE DAY~. . . ~as~ ~1 & ~ ~,~s. ~,~i~ · - .. I r ~r, a .Ca r [ i n ATO-t 429F .. ' TRAN$ ~862t6 - DISTRIBUTION · " Cent'ra !. Fi [es "- Phi I. [ i ps: "il"' . '"'.-Chevron PB We[[ Fi les: D & M R & D ~ Ex~el~$ i on Exp Lora~ ion ~ ~ohio ~ Exxon ~ ~af.e of Alask~ Marathon $ Texaco ARCO Alaska, Inc.[ Prudhoe Ba~ gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil 'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 'DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 Permit # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS 17-10 Permit # 81-97 Dear Mr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/JEB/mjb R E C E ! V E D At tachment s JAN 2 5 lgS§ cc: Sohio Alaska Petroleum Company Alaska 0i! & Oas Cons. Commlsslort Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ( ALASKA L)IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL]~] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-74 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20602 OTHER [] 4. Location of Well 2359' FNL, 955' FWL, Sec. 22, T10N, R15E, UM 1359' FNL, 1134' FWL, Sec. 22, T10N, R15E, UM 1225' FNL, 1157' FWL, Sec. 22, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 72' RKB I ADL 28331 12. Check AppropriateBox Tolndicate NatureofNotice, Report, orOtherData 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-8 11. Field and Pool Prudhoe Bay Field. Prudhoe Bay Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling 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 details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska Inc. has converted DS 17-8 to water injection service. The well is part of the Flow Stations 2 waterflood project. The well began receiving water on June 24, 1984. JAN 2 5 1985 Alaska 0il & (~as Cons. CommissJOrl Anchorago 14. I herelTg'icertify that tl;~e foregoing is true and correct to the best of my knowledge. Signed ''N ..... Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate o ,-_, 5: i -'""; .... · ........... ~ ....... ':':. ..................... F"h i I. L iF:' .': !::: ::-:: i' ,:::,: ~.::. i :':: ~; ;:":' .... .' :.'. :' .... :"~ '~' ::.,. !' i :: ", F:"r u d h o e B a y !:.j. e I. I. Exxon R & D '" h Gel ±>' ~.o i o "" '"~ ............ Si:ale of' Ata::ka l'l.:':i T' .¼1 ;. ~ ~ ,...= ~; F:'i L .e ::-.' ARCO Alaska, Inc~ F'..O, Box iOOS60 Anchorage, Alaska oo,=: t DATE' Decembpr 2i ic:'°~ _. ~ ..' ~.., '~'r REFERENCE' AR[:O Ca~.ed Hole Fina L~ i - t A ~' c" - '--:'. 6 -- S 4,..,CCL/E:'er I"' Record_ ~ _ o .,, I::, ' ":' f 'T' _ 3-4 t i--,: ,_.,., ; ; emp L.r-,g 3- t 1 'i¢,... i i - 3- 84 C F S' .-'" :=.: p i n 'ne r 3 .... '~ ti-i© ~'"~ · - ..,- c: ,-, C N / M S / O R .... ~4--3; ~. I i--i ?--.E:~4 CN/HJ...'/[;R '"~"-- ' :-/' ' " ....... .... 4 t 'i --; 4--84 E:N/F;;::.'/GR 7'--4-~ 8-2;6,--84 C[:L./PerT Record 7-4-' ,~:°--'Jc'-":'4~..... ::CET L_o9 f'-- r~ t i -I 6-84 CN/MS/G'R ?-t 6., ~'~ I i -i L~;'-84 CN,,'M:'--]/GF,' , ,-,.,~ . ~ i i" '"" ~,r~. ...../GR -' ~.', -' c:, 4- i2-2S/~ ii-Sr.;-°''' P6, rfor~tinq Record i %-- 2 A -"~' t (!::-c:',_., _ ,_,°'*-,C CL./P er I: R ¢:,r' c,r d ..... t 4-I 3 -." i i --22-S4 (7;(3 / Lar/F'erf Lc,,:;; t-q.-~67 o-"~'=--S4 CCL/F:'erf Record t_.,- ~ -,; c;..,_, i O-E:".-' L. i ~"-- '" 0 ' ,:0-" S 4 r' ;.-"D _; ,' ,. -- 'I :, B L_/' t 7-6 / I t ---2-84 C..F;~.'..-"¢'p i nr~er -, ~ /j ". F" r." 'T' .' ' i ,"-8'-~' i t- ;.-E.:4 ........ · Sr.:, i 'nr~er -6 ~E-.', sign and 'Fe't'urr~ i;.-he a~!'a,:::hed cop';,-" a.s receiF, i' Rece,,..,'ecl Bv / / ~' ""' HAVE A HAF'F'Y HOL_]ZDAY ,".-';EASON! ~r.,. ..../ KeLt. y Mc:Far La'nd A 'I" 0 -. ~ 4 ''~ ':::' P' TRANS. -,,-..,.21 ,3 'f' d ,.':i 'i; a, Chevror, I) & H Exp.i.c',ra'tic, n Servic:es E x + e'.q :? ~: i o ;", E x r-:, 1. o r a !' i o r, E x x o n Get!>, M ..':~ ~"8 't' h o ':3 ALASKA OIL AND GAS CONSERVATION COMMISSION / 3OOl PORCUPINE DRIVE / ANCHORAGE, ALASKA 99501-3192 December 27, 1984~ ~ TELEPHONE (907) 279-.1433 ADMINISTRATIVE APPROVAL NO. 192.9. Re .. Substitution of pressure fall-off surveys in five injection wells for transient pressure surveys in producing wells as required by Rule 6(d) of Conservation Order No. 165. Mr. D. F. Scheve Regional Operations Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Dear Mr. Scheve: On December 6, 1984 ARCO Alaska, Inc. requested pressure fall-off surveys in Prudhoe_Bay Unit water injection wells DS 3-13, DS 9-12, DS 9-14, DS 16-3, and DS 17-8 be accepted to satisfy requirements of Conservation Order No. 165, Rule 6(d). At a meeting with ARCO representatives, December 26, 1984, data were submitted which demonstrate that appropriate reservoir pressure data for reservoir management can be obtained from a four hour minimum pressure fall-off survey in injection wells. The Alaska Oil and Gas Conservation Commission hereby approves the substitution, of four hour minimum pressure fall-off surveys in Prudhoe Bay Unit water injection wells DS 3-13, DS 9-12, DS 9-14, DS 16-3, and DS 17-8 to satisfy requirements of Conservation Order No. 165, Rule 6(d). This action is taken pursuant to Rule 2 of Conservation Order No. 192. Yours very truly, Harry W. Kugl~r Commissioner BY ORDER OF THE COMMISSION HWK/RAD..be.. 1.AA 192 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 17-6 DS 17-8 DS 17-10 Permit No. 80-132 Permit No. 81-74 Permit No. 81-97 Enclosed are Sundry Notices for Change of Well Status for the proposed Drill Site 17 Water Injectors. Very truly yours, D. F. Scheve DFS/WT/kg Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 17-6)W1-3 File P1 (DS 17-8)W1-3 File P1 (DS 17-10)W1-3 RECEIVED JUN 1 8 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, Is a Subsidiary of AtlanflcRIchfleldCompany L '. STATE OF ALASKA ALASKA ~. AND GAS CONSERVATION CC[ ~llSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 31 Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 2359' FNL, 955' FWL, Sec. 22, T10N, R!5E, OM 1359' FNL, 1134' FWL, Sec. 22, T10N, R15E, UM 7. Permit No. 81-74 8. APl Number 50-- 029-20602 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-8 1225' FNL, 1157' FWL, .Sec. 22, T10N, R15E, UM 5. Elevation in feet'(indicate KB, DF, etc.) i 6. Lease Designation and Serial No. 72' RKB I ADL 28331 12. 'Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' 1 1. Fiel~ and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other r]~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to change Well 17-8 status from oil producer to water injector. It will be operated as part of the Prudhoe Bay Waterflood Project. Work Beportecl RECEIVF D JUN 1 8 1984 Alaska 0il & ~as Cons~ C0mmlssl0n Anchorage. 14. I hereby ce, r,~fv that the for~goin,g is true and correct to the best of my knowledge. Signed .. .. _ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: Approved bv Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc%. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 1, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 17-6 DS 17-8 Permit No. 80-132 Permit No. 81-74 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 17-6,8)W4-3 RECEIVED MAY 0 ? 19M Anti.age ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany · ALAS ~ILAND GAS CONSERVATION _,,?1MISSION ~.. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ Water :[njector ._ 2. Name of Operator 7. Permit Number ARCO Alaska, :[nc. 81-7z, 3. Address 8. APl Number ?.0. Box 100360, Anchora§e, Alaska 99510 50-029-20602 4. Location of well at surface 9. Unit or Lease Name 2359' FNL, 955' FWL, Sec. 22, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1359' FNL, 1134' FWL~ Sec. 22~ TiON, R15E, UM DS 17-8 At Total Depth /2,~ ~;: /f~/'/i- ~ //5 7 zl~'~,~,J~'_~ ~',.~". 11. Field and Pool ~ FNL, ~ FWL, Sec. 22, TiON, R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 72' RKBI ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/11/81 6/28/81 7/2/81 ._ feet MSLI 1 l~th (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost Q9715"MD~ ~7 2 % 9695'MD YESx~ NO [] 2121 feet MD 1900' (aDorox) 22. y~'V-P~Electric or Other Logs Run DIL/SFL/GR, DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. ·GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9/*~f H-&O Surf_ 11 O' 32" qh~ mw 13-3/8" 7:24f L-80 Surf. 2~&1' 17~_" ~O(%O g~ Fmnd~ ~, /~ .~w 9-5/8" 475A L-gO Surf. 8R96' ' ~12~" gOO .~w C.1 -,g 'g 7" 29~ L-80 8065' ~9730~ 8~" &50 sx Clmgg G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ' ' SIZE DEPTH SET (MD) PACKER sET (MD) 9090-9110' MD 8937-90Z~0' TVD 5~" 86~'~' I 8576' · 9110-9118' MD 9137=91~5, MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,, 91/,5-9165' MD .' '. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9178-9193' MD N/^ .- 9193-9213' MD ' . ' , , . ,,, ,, · . ,. ~ :~ , ; · ~ · Ref~ g~C~ 6/26/81 ~ ":,' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Future I~ector ~ :. ' ~ ...... - Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO N/A ' ' :' : TEST. PERIOD I~ ,, - ,. Flow Tubing Casing Pressure CALCULATED '~ :Q L-BBL .GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATEII~ . : . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED · .: MAYo 719 , ' Alaska 0tl & Gas Cons. Commission Anchorage ,- Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ., 29. 30. GEOLOGIC MARKERS NAME Include inte MEAS. DEPTH TRUE VERT. DEPTH GOR, and t~ Top Sadlerochit 9088' 8936' N/A O/W Contact 9260' 9105 ' Base Sadlerochit 9628' 9465' · 31. LIST OF ATTACHMENTS 32. I hereby certify that the forego:rog is true and correct to the best of my knowl( Signed ~ ~ .._.~ ~-~, ,~_.../-,.¢.-*,-~ Title R, FORMATION TESTS .~rval tested, pressure data, all fluids recovered and gravity, ime of each phase. ~ledge giona] Enginme. r Date 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 this well is .completed for separate production from more than one inter, val (multiple completion), so state in item 16',:and in item 24 show the.~oducing intervals for only the int~'~Val 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- ing and'the 'location of the cementing tool. Item 27' Met. hod 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 ARCO Alaska, Inc{ Prudhoe Baby ~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 1, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 17-6 DS 17-8 Permit No. 80-132 Permit No. 81-74 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 17-6,8)Wl-3 RrcCEIV'rcD 0 7 rgB4 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany STATE OF ALASKA ALASK(''~ .)IL AND GAS CONSERVATION'{,. MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-74 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20602 4. Location of Well 2359' FNL, 955' FWL, Sec. 22, T10N, R15E, OM 9. Unit or Lease Name Prudhoe Bay Unit 1359' FNL, 1134' FWL, Sec. 22, T10N, R15E, UM 1225' FNL, 1157' FWL, Sec. 22, T10N, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 72' RKB 6. Lease Designation and Serial No. ADT, 28331 10. Well Number DS 17-8 11, Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforation operation on 3/24/84. RU perf unit, pressure tested equiPment. RIH w/gun #1, shot 9193-9213' MD, 4 spf (20'), flowed well, SI well, POH, all shots fired. RIH w/gun #2, shot 9178-9193' MD, 4 spf (15'), flowed well, SI well, POH, all shots fired. RD and secured well. Ref: BHCS 6/26/81. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. ~~ /~.~' ~'~,,~ Title Regional Engineer The space below for Commission use Date ~'''''~ ~ - ~' 9'~ Conditions of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date ion Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Donald F. Scheve Regional Operations Engineer March 1, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr?Chatterton: Re: DS 16-1 DS 16-2 DS 16-5 DS 16-11 DS 16-16 DS 17-6 ~S 17-8 Permit No. 80-136 Permit No. 80-150 Permit No. 81-37 Permit No. 80-118 Permit No. 80-127 Permit No. 80-132 Permit No. 81-74 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File 100.0 ARCO Aleske. Inc. is e Subsidiary of AllanflcRIchfleldCompany STATE Of ALASKA ALAS OIL AND GAS CONSERVATION'L, OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-74 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20602 4. Location of Well 2359' FNL, 955' FWL, Sec. 22, T10N, R15E, UM (Surf) 1359' FNL, 1134' FWL, Sec. 22, T10N, R15E, UM (Top Prod) 1225' FNL, 1157' FWL, Sec. 22, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 6. Lease Designation and Serial No. ADL 28331 OTHER 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 17-8 1 1. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Welt [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling 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 details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARco Alaska, Inc. proposes to add perforations on DS 17-8 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9178-9213' MD Ref: BHCS 6/26/81 Subsequent Work Reported EECEt 'ED 14. I hereby,~ertify that thg, foregoing is true and correct to the best of my knowledge. Sign ed ~~//, ~/~,-f,'~ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: ORIGINAL SIGNED BY LONNIE IL SMITH e,,, Orde. of Approved by COMMISSIONER the Commission Approv. ed Copy ' Returned · Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office Box 360 Anchorage. ~' ~ka 99510 Telephone 9[ .77 5637 December 30, 1982 RE' ARCO Cased Hole Finals D.S. 13-5 10-29/30/31-82 Spinner Camco D.S. 14-13 ' 10-6-82 Spinner Camco D.S. 17-8 10-28/29-82 Spinner Camco D.S. 18-7 Initial run Perf. and Collar Log Camco sign and return the attached copy as receipt of data. Becky Benedict. AFA- 403 Trans. #685 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D &M~~ ~ STAT~~I ~ C ~" ~ ~! ~: 5- Alaska Oil & Gas Cons, Cc: Anchorage ~ zSsion ARCO Alaska. Inc. is a Subsidiary of Allar~ticRicttfieldCompanv ARCO Alaska, Inc. Post Office~'r ~ 360 Anchorage.\..-,ska 99510 Telephone 907 277 5637 November 3, 1982 Reference- ARCO Pressure Data D.S. 13-18 9-28/29-82~ D.S. 17-8 10-22-82 D.S. 1-5 9-21-82 Pressure Build-Up Survey Pressur. e Build-Up Survey Pressure Build-Up Survey Please sign and return the attached copy as receipt of data.- Camco Gearhart Otis Becky Benedi ct AFA- 403 Trans. #592 DISTRIBUTION' NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON /' --x~ MOBIL GETTY D&M .STATE OF ALASKA DALLAS RECEIVED NOV 0 5 i982- · Alaska Oil & Gas Cons. Commission Anchorage · ARCO Alaska, Inc. Post Office 3.? Anchorage. ;.las May 25, 1982 Mr. C.D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S. 17-7 Permit No. 81-66 ~D.S. iT-:8~Permit No. 81-74 ~D.S. 17-9 Permit No. 81-90 D.S. 17-10 Permit No. 81-97 Enclosed are our Subsequent Sundry Notices detailing the work done of the above-mentioned wells~. Very truly yours, D. F. Scheve District Operations Engineer DFS:TKKW:mlc Enclosures Distribution: Sohio Petroleum Co. ALASKA AND GAS CONSERVATION C ',, SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL;Ii3 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-74 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 so- 029-20602 OTHER [] 4. Location of Well 2359' FNL, 955' FWL, Sec. 22, TION, R15E, UH 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 12. I 6 . Lease Designation and Serial No. ADL 2R331 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 17-8 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations - I~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling 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 details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 3-14-82. Tested tubing and annulus~tested tree.: NU and tested perforating equipment. NU and tested wireline BOP and lubricator. Perforated 9145-65' M.D. with 4 spf. Unloaded to tanks. Flowed to flow station. Perforated 9137-45', 9110-18' and 9090-!.10' M.D. with 4 spf. Recorded BHP. Rigged down perforating equipment, Secured well 3-15-82. MAY 2 71982 ~ka Oil & Gas Cons. Commissior~ Anchorage certify that the foregoing is tru and correct to the best of my knowledge. 14. I hereby ~~ Signed ,~_~.-~ _ Title District Operations Engineer pate Conditions of Approval, if any: , By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7~1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate April 12,1982 Reference: ARCO CASED HOLE FINALS · D.S.17-8 3/15/82 Collar & Perf Log Run 1 2"/5" D.S.17-9 3/13/82 Collar & Perf Log Run 1 5" D.S.328 3/12/82 Collar & Perf Log Run 1 5" '~~Pl'ease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 89 DISTRIBUTION NORTH GEOLOGY EXXON PHILLIPS D&M :~i.. ~. GEOLOGY Alaska Oil & Gas Cons. Comm.~s~lort SOHIO Anchorage MARATHON STATE OF ALASKA CHEVRON ARCO Alaska. ~nc. is a sul;~,J~ary o! Ailanuc~,chf~elclCompan¥ April 12, 1982 Reference: ARCO PRESSURE DATA D.S.16-16 D.S.16-1 D.S.7-2 D. S. 2-1 ~'~'~ D.S.2-6 D.S.6-1 D.S.6-9 D.S.2-15 D.S.17-9 D.S.2-15 D.S.17-6 D.S.2-14 DS..6-4 DS..5-11 D.So5-17 D.S.17-7 D.S. 17-8 3/10/82 Pressure Survey 3-12/13v82" " 3/4/82 ~i~ ,, ,, 2/lO/82 ". ,, .2-7/8-82 " " 1/24/82 " " 2/5/82 " " 1/23/81 " " ~.3/14/82 " " i/24/81 " " 6/26/81 " " 11/9/8o " " 3/8/82 " " 2/7/82 " " 2/26/82 " " 3/13/82 " " 3/15/82 " " ~'/~Pl~ease sign and return the attached copy as receipt of. data. Mary F. Kellis North Engineering Transmittal #92 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL ~ DRILLING GETTY PHILLIPS SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Ai~ '..~..~'~, , ,~'¥:~. North Slope L ,.": Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 29, 1982 Mr. C. D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Porcupi'he Drive ^nchorage, AK 99501 Dear Mr. Chatterton. Subject. D.S. 1 D.S. 1 D.S. 1 D.S. 1 D.S. 1 D.S. 1 D.'S. 1 D.S. 1 D.S. 1 6-5 Permit No. 81-37 6-6 Permit No. 81-51 6-12 Permit No. 81-26 6-13 Permit No. 81-27 6-14 Permit No. 81'-32 7-7 Permit No. 81-66 7-8 'Permit No. 81-74 7-9 Permit No. 81-90 7-10 Permit No. 81-97 Enclosed are our Sundry Notices detailing the work to be done on the above mentioned wells. Very truly yo?s, · ~. A. Rochon JAR'TKKW:ml c Enclosures ARCO Alaska. Inc is a subsidiary of AllanlicRichfieldCompan¥ AC STATE OF ALASKA ALASK IL AND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-74 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20602 4. Location of Well 2359' FNL, 955' FWL, Sec. 22, T'10N, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 12. I 6. Lease Designation and Serial No. ADL 28331 10. Well Number D.S. 17-8 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling 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 details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating the well will be flowed to the flow station for Clean up and production. Should additional drawdown be necessary to unload the wells it may be flowed to a tank for initial clean up. The perforated intervals will be given in the subsequent report. Ail wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. - The SSSV will be installed at the conclusion of the perforating and clean up operation. RECEIVED FEB 0 3 1982 ~aska Oil & Gas Cons. Commissio~ t~chorage 14. I hereby cer]Lify that the foregoing j~true and correct to the best of my knowledge. STOned /~~~' Title District Engineer e space .b~/l~w for Commission use Date Conditions of Approval, if any: Approved by AFproved Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc ..... Post Office ~ Anchorage. AI::,,.;~ '~ :!9510 Telephone 907 277 ~-,637 September 28, 1981 Mr. Harry Kugler Sta,te of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 16-4 ~lest Sak #18 DS 12-12 DS 16-5 A-2 DS 14-9A DS 16-14 A-'3 DS 14-19 DS 17-7 B-4 DS 14-20 DS 1 7-8 C-8 DS 16-1 DS 17-9 Dear Sir: Enclosed please find the Completion Reports for the following wells: A-2, A-3, B-4 and C-8. Although these Kuparuk wells have been per- forated, production test data has not been obtained; this information will be forwarded to your office when available. Also enclosed are Completion Reports for the following wells' DS~12-12, DS 14-19, DS 14-20, DS 16-4, DS 16-5, DS 17-7, DS 17-8 and DS 17-9. Production test information is noi~ applicable for these wells since they have not yet been perforated but will be submitted to your office when we obtain the information.~ Previously unreported information such as locations for bottom hole, producing interval and geological forma- tions have been added to the updated Completion Reports. DS 14-9A and West'Sak #18 have been plugged and abandoned. An updated Completion Report with Drilling Histories for these wells is enclosed. Information regarding West Sak #18 is of a confidential nature and we would appreciate securely storing the report where it will receive minimum exposure. The initial Gyroscopic Survey for DS 16-1 was unacceptable and a rerun is presently being authOrized by our engineering staff. An updated Completion Report for this well will be sent to your office subsequent to our receiving an acceptable survey. The remainder of the requested information- an overdue Completion Report on DS 16-14 and an incomplete Completion Report for DS 12-11 was sent to your office August 27, 1981 and was apparently enroute at the time of your September 2, 1981 letter to this department. Also included are completion Gyroscopic Surveys for DS 12-12, DS 17-7 and DS 17-9. I E£EIVEI) Sincerely, pj, s,,t;~,i..,Ct,,.Dri 1.,1.i pg, Engineer SEP '¢ 0 1981 Naska Oil & Gas Cons. CommJssior~ Anchorage ~ ALASKA' ,L AND.GAS CONSERVATION C .,.~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-74 3. Address 8. APl Number P.O. Box 360 Anchorage, Alaska 99510 5o- 029-20602 4. Location of well at surface 9. Unit or Lease Name 2359' FNL, 955'FWL, Sec 22, TION, R15E, UN '~ Prudhoe Bay Unit At Top Producing Interval VERIFIED I 10. Well Number 1359' FNL & 1134' FWL, Sec 22 TION, R15E, UM JSurf. _~ DS 17-8 At To~alL~epth //57 ' 11. Field and Pool ~ FNL & j,~35" FWL, Sec 22, T10N, R15E, UM~ Prudhoe Ba.v Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe 0i ] Pool 72' RKBt ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore ] 16. No. of Completions 6/11/81 6/28/81 7/2/81 -- feet MSLI 17. Total Depth <MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set i 21. Thickness of Permafrost ~ ~3'~ 9695'MD YEs~(X NO[]I 2121 feetMDI 1900' (approx) .. 22. Type Electric or Other Logs Run DIL/SFL/GR, DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBt 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ?Q" 94# H-40 " Surf 110' 32" 300 sx Permafrost .13. 3/F~" 72# L-80 Surf 2641' 17 1/2" '.3000 sx Fondu & 40C sx Permafrost g .5/R" 47# L-80 Surf .. 8896, 12 l/4" .500 sx Class G 7" 29# L-80 8065' 9730' 8 1/2" 450 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD . , interval, size and number) , . SIZE DEPTH SET (MD) PACKER SET (MD) · 'N/A 5 1/2" 8649' 8576' · , . , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL usED · . - .... . N//A - · _ . . . · . · . 27. ' pRoDucTI'ON TEsT Date FirstProductior).:. ~ .; "' t Method of Operation (Flowing, gas lift, etc.) N/'A' '"''" ~ ' " ..... ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ' WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing,""' Casing Pressure CALCULATED 't~ OIL~BBL GAs:McF WATER-BBL OIL GRAVITY-APl (corr) Press. ' ' " 24-Hot]R RA~E~ ~ ' ' " ": ' 28. cORE DAT~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' SEP 3 0 1981 "~' ' " Alasl'~ Oit & Gas Cons. C0mmissi0r~ A~c.h0rag~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9087' 8935' N/A 0i 1/Water 9260' , 9104' Base Sadlerochit 9628' 9465' , Dri lling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _ _ _ Title Dist. Drlg Engr. Date 9/17/81 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 eleYation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for.:iSeparate production from.more than one interval (multiple'~ completion)ii:.'So state in item !6, 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 multipie stage cement- ing 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 September 2, 1981 , Mr. P. A. Van' Dusen District Drilling Engineer Arco Alaska, ~'Inc. , P.O. Box '360' .' .Anchorage, Alaska 99501 Roi Overdue D,Bta Submission : ~ear Mr. Van Dusen: . Wells on the attached lists are those for which Completion Be.ports (form 10-407) are either incomplete or apparently overdue, with completion,i abandonment, or suspension dates prior~..to August 1, i981. The first list is of those wells for which an incomplete Completion P~eport was filed, with the comment that the locations at the top of the producing interval and at the total depth were be submitted" or "N/A." The,completion dates go back to January 9. The second list is of those wells for which.available information indicates the wells have ~een ccmpleted, but the 30 day filing period has passed without a Completion Report having been submitted. We need to be brought up-to-date on directional survey problems that may be responsible for these late filings, or have the required directional surveys° and reports submitted to us. We would appreciate a respon~se at your earliest convenience. Sincerely yours, Harry Rug ler Commissioner B~K/JAL/g lh ARCO Alaska, Inc. ( Post Office Bc'L. ,,60 Anchorage, Alaska 99510 Telephone 907 277 5637 June 28, 1982 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 17-8 Corrected Bottomhole Location Dear Elaine' The DS 17-8 Completion Report, dated September 17, 1981, incorrectly lists the BHL as' 1328' FNL, 1155' FWL, Sec. 22, T10N, R15E, UM The correct location is: 1225' FNL, 1157' FWL, Sec. 22, T10N, R15E, UM Sincerei~, Gruber Assoc±ate Engineer JG'hrl cc' M. Kell±s, AFA 403 R. W. Grick, ANO 912 G. Arnold, ANO 927 Op. Engr. Coord., PBOG 103 Well File ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany RECEIVED JUN 3 1982 Alaslm Oil & Gas Cons. Commission Anchorage . - O~,~_"A STATE OF ALASKA - ALASKA ND GAS CONSERVATION CO ,,... ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-74 3. Address 8. APl Number P.0. Box 360 Anchorage, Alaska 99510 so- 029-20602 4. Location of well at surface 9. Unit or Lease Name 2359' FNL, 955' FWL, Sec. 22, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number At Total Depth//~" 11. Field and Pool To be Submitted ,' Prudhoe Bay Field ~5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe 0i I Pool 7'2' RKBI ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 6/11/81 6/28/81 7/2/81I -- feet MSL 1 17. Total Depth {MD+TVD) 18. Plug Back Depth {MD+TVDI~ 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9730 9695' M.D. YEE--X[~X NO[]]I 2121 feetMD 1900' (approx) 22. Type Electric or Other Logs Run [1TI/gFI /GR; DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED r . 20" 94# H-40 Surf llO' 32" 300 sx Permafrost !3 3/8" 72# I-R(1 Sur.f 2641' 17 1/2" 3000 sx Fondu & 400 sx Permafrost q ~/R,, 47~ I-R[l Surf 8896' t2 '1/4" 500 sx Class G 7" 29# ~-80 8605 9730' 8 1/2" 450 sx Class G 24. Perforations ope, n to Product,ion (.MD+TVD of Top and Bottom and 25. .TUBING RECORD interval, size and number) SIZE" DEPTH SET (MD) PACKER SET (MD) 5 1/2" 8649' 8576' 9090-9110' M.D.~ · . ' 9110-9118' M.D.~ <])3/~ ~/~t~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9137-9145' M.D."/ · ., DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9145-9165' M.D._; N/A ~'"'~. . . 8937-9011' TVD .. . . . P bDUCT ONTEST ' Da,t~ First'Production ~ 't Method of Operation (F ow rig, gas I ft, etc ) 3-15-82I Flowing "~' ''~ ~ ,., ,,, Date of Test Hours Tested PRODUCTION FOR OIL-BBL' GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATI° - 3-:2z~82'~ 6..1 TEST PERIOD ~i',, 860 615. · 0 55 716 FI0wTubing Casing'Pressure . CALCULATED I~ O.I.L-BBL GAs-MCF WATER-'BBL OIL GRAVITY-APl (corr) Pr'ess, "812. .' ;. N/A, 24-~OuRRATEI~ '3382 ' :2420 0 .... 26.6 28. ' CORE DATA · · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core'chips. · , · · MAY 2 71982 .. , , Alaska 0ii & Gas Cons. Commission : ' Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ./ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ?. Sadlorochi~c 9087' @935' O±l/~ater 9260 ' 9104 ' B. Saclleroch~c 9628' 9465' :. ., · . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Dist. Oprs. ]g~crE. Date ~ r - - ~ .. 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 :!~¢d 24: If this Well is completed for separate production from more than one interva.!~,(multiple completion), so state in item 16, an"d in item 24 Show the producing intervals for only the intervai 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". 'orm 10-407 P. A. Van Dusen .~eptember 2, I981 Incomplete Completion Reports Well Name and Number Comp 1 e t ion / Aba ndonme nt ..,Suspension Date' Prudhoe Bay 'Unit DS 16-1 Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Prudhoe Bay Unit DS 16-5 Kupa r uk C- 8 Prudhoe Bay unit DS 14-19 Prudhoe Bay Unit DS 17-7 Prudhoe Bay Unit DS 14-20 Prudhoe Bay Unit DS 12-11 Kup a r Uk A- 2 Prudhoe Bay Unit Overdue (?) Comp_l.etion Reports 1-9-81 3-21-81 3-27-81 4-17-81 4-21-81 5-15-81 6-6-,81 6-10-81 6-30-81 7-1.-81 7-2-81 7-2-81 Prudhoe Bay Unit DS 16-14 Kuparuk B-4 Kuparuk A-3 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit DS 12-12 7-9-81 7-14-81 7-24-81 7-25-81 7-26-81 ARCO Oil and Gas C%mpany North Alask,. ~,~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 26, 1981 Reference: ARCO Directional Surveys D.S.17-8 8/21/81 Gyro-Multi-Shot ~~Ptease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #548 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL PHILLI~ ~~ SOHIO ~-~'- z~~~ MARATHONA~S~ Oil & Gas Cons. Anc~0~0 CHEVRON ARCO Oil and (;as Company is a Division o! AtlanticRichfieldCompany Aug 7, 1981 Reference: ARCO Cased Hole Final Prints D.S.i-13" 7/10/81 CNL Run 3 5" D.S.3-7'.'"/' 7/8781 EPL Run 1 5" D.S.3-7 ?;,!': 7/8/81 TDT Run 1 D.S.5-3 / 7/27/81 CNL Run 3 5" D S 14-207 7/3/81 CNL/GR Run 1 2/5" ' DOS.16-3 :' 7/12/81 CCL & Perf Record Run 1 5" D,So16-9t 7/22/81 CCL & Perf Record Run 1 5" D,S. 16-14 7/10/81 CNL/GR Run 1 2"/5" ~D, So16-14v 7/7/81 ACBL/VDL RU'n 1 5" D,S,17-6 ~ 6-11/28-81 Diff Temp Log Run 1,2 5" D'So17'8" 7/6/81 CNL/GR Run 1 2"/5" Pleasesign and return the attached copy as receipt of data. Mary F. Kellis North Engineering DISTRIBUTION Transmittal #489 NORTH GEOLOGY EXXON "~; R & D MOBIL DRILLING ENG. MANAGER D&M . GEOLOGY NARATHON STATE OF ALASKA CHEVRON ARCO 0~1 and (;as C.~.'~pany ~$ a Dsw~,,on of AllanhcR~chheldCompan,/ ,.':-' . :1. "~(;;Ei~,,7.': District Operations Engineer July 31, 1981 Reference: ARCO Directional Surveys DoSo16-14 7/11/81 Gyroscopic D.S.12-10 5/15/81 Magnetic Multi-Shot D,S.14-20 7/3/81 ~. Gyroscopic D.S.12211 7/4/81 Gyroscopic ¢~~*¢~"~ 6/30/81 Single-Shot D.S.17-9 7/21/81 Single-Shot D',S°14~20 7/2/81 Single=Sh0t D.S.16-14 7/2/81 Single-Shot ease sign and return the attached copy as receip~ of data. Mary F. Kellis North Engineering Transmittal #481 DISTRIBUTION NORTH GEOLOGY R & O DRILLING ENG. MANAGER D & M GEOLOGY STATE OF ALASKA PHILLIPS SOHIO MARATHON CHEVRON ARCO 0~1 and C;J$ Company is a D~¢,sion of Atl.lnh¢ R,(.hh~ldCompan¥ Jerry A. Rochon District Operalions Engineer July 22, 1981 Reference: ARCO Cased Hole Finals DOS.12-11 6/30/81 ACBL/VDL Run 1 D.S.12-11 7/4/81 CNL/Ga~!i!a Ray Run 1 D.S.i~-6 6/28/81 ?LS Run 1 D.S.17-6 6/21/81 Fluid Density Run 1 ~%!~'?,~ 6/30/81 &CBL/VDL Run 1 2"/5" 5" 5" 5" ~/~lease sign and retUrn the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #449 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY CHEVRON ~ Gas Cons. A~:~,r~;~ C°mmissNa ARCO Oil aod Ga~ .mpany North Alaska..,.)istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 22, 1981 Reference: ARCO Magnetic Tapes & Listings D. S. 1/~-20 D.S.12-11 7/16/81 TaPe #8340-9700 Dresser 7/16/81 Tape #8700-10286 Dresser 7/16/81 Tape #8750-10144 Dresser ECC 1 ECC 3 ECC 20 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TransmittalS50 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON GETTY _ . . PHILLIPS ~U~ ~ ? 1~1~'~~ SOHIO ~1~ 011 & t~,~s ,,,,,,~ '.~' MARATHGN A~f~0r~l;e' commission CHEVRON ARCO OH and Ga5 Company is a D~vi$,on o! AllanlicR~chfieldCompan¥ ARCO Oil and Ga.~ "~mpany Nbrth Alaska Oistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 17, 1981 Reference: ARCO Open Hole Final 'D. S. 17-8 6/22/81 Arrow Plot w/Cluster Results Job No. 4074 ~e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #444 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON EEIVED ~aska 0/! & Gas Cons. ComrnJssJOrl Anchorage ARCO Oil anc~ Gas Company is a Division of AtlanticRichfieldCompany Jerry A. Rochon District Operations Engineer .., . July 16, 1981 Reference: Arco Magnetic Tapes & Lists D.S.12-9 5/1/81 Tape #62000 Run 1 & 2 Schlumberger 6/22/81 Tape#61740 Run 1 & 2 Schlumberger 7/3/81 Tape#61757 Run 1 " Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #443 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY MARATHGN .~I':,Sk,.'l Oil .Y. CH E V RON A r:','-' ARCO Oil and (]J$ Con, party is ,3 Davl~,~on O! AllanhcR~¢hh~-I(~Compan¥ July 21, 1981 Mr o Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' ., DS 14-19 A-1 DS 14-20 A-2 DS 1 6-13 B-3 B-4 Dear Sir- Enclosed please fi nd- l) The.monthly reports for DS 16-14 & B-4. 2) The subsequent Sundry Notice for DS 14-18. 3) The Completion Reports for DS 1 -.~DS 12-11 DS 14-19, DS 14-20, DS 16-13, DS 17-7, I~.~~A-1, A-~- & B-3. 4) The Gyroscopic Surveys for DS 12-10, DS 14-20, DS 16-13, A-1 and B-3. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG: s p Enclosures JUL 2 1 ~aska Oil & Gas Cons. C;ommls=ion /mchorage ARCO Ai~ska. Inc r- I I ... -.-' !II' . ( STATE OF ALASKA l ALASKA Oil AND GAS CONSERVATION CÜ,vIMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I I 1. Status of Well Classification of Service Well OILtX GAS 0 SUSPENDED 0 ABANDONED 0 SERVICE 0 2. Name of Operator 7. Permit Number ARCO A 1 ask a, Inc. 81-74 3. Address 8. API Number .. P.O. Box 360 Anch or age, Alaska 99510 50- 029-20602 4. Location of well at surface 9. Unit or Lease Name 23591 FNL, 9551FWL, See 22, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number To be Submitted OS 17-8 At Total Depth 11. Field and Pool To be Submitted Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool 721 RKB AOL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 6/11/81 6/28/81 7/2/81 -- feet MSL 1 .17. Total Depth (MD+TVD) 18.Plug Back Depth (MDtTVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost -~MO rì J>~ 96951MO YES ex X NO 0 2121 feet MD 19001 ( approx) 22. Type Electric or Other Logs Run OIL/SFL/GR- OIL/SP/BHCS/GR, FOC/CNL/GR/CAL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ?O" q4# H-40 Surf 1101 3211 300 sx Permafrost 13 3/8" 72# L-80 Surf 26411 17 1/211 3000 sx Fondu & 400 sx Permafrost q ~/RII 47# L-80 Surf 88961 12 1/4 II 500 sx Class G 7" 29# L-80 80651 97301 8 1/2 II 450 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 5 17211 86491 85761 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ., .' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N//A ., ,,' 27. PRODUCTION TEST Date F=irsrProduction . . , Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ..' TEST PER 10D . Flow Tubihg Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 24-HOUR RATE. 28. CORE DATA .. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , N/A RECEIVED ., JUL 2 1 1.981 .. " J\laska Oil & Gal:' Co . . . , .. ' .. 0 ; ns Co . AnchoraYD mrnlsslon Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS ....... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..... To be Submitted N/A , , 31. LIST OF ATTACHMENTS Drilling History 32. I hereby certify that the foregoing is true and correct to the best of ~y knowledge S~oed . . . Tit~e Dist Dr 1,9 Engr. Da~ 7/10/81 , , , 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 o~'herwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this jell is completed for separ:gte production from more than erie 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". DS 17-8 DRILLING HISTORY NU 20" riser. Spudded well @ 0200 hrs, 6/11/81. Drld 17½" hole to 2665'. Ran 67 its 13-3/8" 72#/ft L80 csg w/shoe @ 2641'. Cmtd 13-3/8" csg w/3000 sx Fondu, 400 sx Permafrost. ND 20'" riser. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12¼" hole to 8917'. Ran DIL/SFL/GR. Ran 123 jts 9-5/8" 47#/ft L80 csg w/shoe @ 8896' Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5060 psi - ok.. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8½" hole to~ Ran DIL/SP/BHCS/GR, FDC/CNL/GR/CAL. Arctic packed 9-5/8" x 13-3/8 annulus w/300 bbls H~O, 300 sx Permafrost type C & 131 bbls Arctic Pack.. Ran 38 jts 7" 29#}ft L80 Inr fr/8605- 9730'. Cmtd 7" liner w/450 sx Class G. Drld cmt to 9695' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Ran CBL. Ran 5½" completion assy w/tail @ 8649' & pkr @ 8576'. Tstd tbg hanger & packoff to 5000 psi - ok. 'ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Set pkr. Tstd tbg to 3000 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 3500 psi - ok. Closed SSSV. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 0130 hrs, 7/2/81. JUL 2 1 1981 Alaska Oil & Gas Cons. CommiSSion Anchorage IfORM D"~O~' ~2 ~l~'l Eastman l l A PETROLANE ~PANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY JOB NUMBER ARCO ALASKA, INC. DS 17~ Well N~ber. 8 . Prudhoe Bay, North Slope, Alaska [0CATI ON TYPE OF SURVEY SURVEY BY Pef ferkorn/Merkle OFFICE Alaska A781G0416 DATE Gyro-Multi Shot Eastm. an Whipstock A PETROl. lINE COMPANY P. O. Box 4-19?O/Anchorage, Alaska 99509/(907) 349-4617 August 21, 1981 Arco Alaska, Inc. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: Drill Sight 17, Well Number 8 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro-Multi Shot Date: 6-Jul-81 Method of C6mputation: Radius of Curvature Surveyor: Pefferkorn/Merkle Job Number: A781G0416 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Gyro-Munti Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. ~ ~/.~/~.~~e~~ Di~ct Technical Coordinator TJ/bD cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA~ iNC~ F'tR~:DHOE ~AY~ NORTH SLOPE', ALASKA CAMERA NO~ 1488, 11~}'-'~ GYRO NOi 5o4 I L,F~E~]:GHTi N 8 qE:G ki ..... . ........................................................................................................................................................................ , RAf-~iUS OF' CUF~VATURf" ifiETi-'tOD // · _, 17, k/ELL NO+' W, LS.ac, dO'"'~:, NO~ A78tG0't16 TIHE :'RU.U'FI'OE'"B~Y]; .... N'O'~'TFi'-' SEOPE, .... i:iL'A"Si<~A' 16: 49: Oo .L t"1 / 1~. 24-dUL-81_ TRUE ,z,.~oURE.~ DRIFF DRIFT L. uU~b. v~.al~c.~-~L VE.,.lzbaL ":'~" '- ...... o t ~N~.~. DZREC T i~ . DEPTH ANGLE DIRECTION LENGTH Dar-T~ ..... ~"'z N SEVERZT'f ~., iON FEET D H D H FEET FEET FEET FEET FEET FEET B PI DG/IOOF:'T ................................................... ........................................................................................... - 0, 0 0 O. 0 ,;:"~, 0.o0. 0,~00 .... 71.00 ~q.00., 0.o0. 100, 0 ...'3.0 N -.', 0 W 100, I00.00 -<"+4i.. 29~00 O~4Z, N 0,05 W 200* ........ 0'30 '~c:' '=:'~,...., ...... ;"~,., ~:."~.. .... ~. ,,.,~ ,-) ;.-, ;:'~ ......... ~. ,. ~, ~ ~ .~.:i ~. c:;'" c~;-;; .......... ,.-. · ~z~ ;';" ::~ '~ ..... .~ ,~:,_., , ~,.i' .-~ o ' ~,5 ..... ?,"~,. · r o':': ;'~; N' 0 , ,..'1~"'; ' g `300, 0 30. ,_.~. 2,3 0 E 100, 299.,99. 0~::~,6_ .:~o"-',99 0+10 N 1.07 E 400, 0 `30 S 23 0 IE I00. `399,99' .-O.:.SS 328,9? 0,7i S 1,41 E ......................................... 0,00 0 0 0,44 H 7 0 W . ,... N ::!;4 ,.:~::'.4 E 1. ;'~.. 8 i'-,t 8 .-i .J~':' 1 I, 58 S 63 27 E 0 · 00 0 · 92 O. 26 ~0. 0 ,30 S 6:/. 0 E i00. 499.c,'8 ~q.80 ""-~'-' 98 · , ----,, .~.~o · i, 34 S 1,99 E 700. 0 .70 S 54 0 E 100. 699,98 -!.I0 628.98 2.06 S 3.57 E ~300, 0 15 N 1~ 0 :Z i00., 7'-:.'9,97. · -0,78 728.97 1.6:6 S 4.09 E 900. 0 15 N '~ ..... ~-.., 0 iE ].00. 899.c~7, -0.-'''=o~, 8z8.9/' 1.46 S 4,25 E 1000. 0 45 S 54 0 . / ~:.~x.:,~;~ 0.00 "'"''-' 97 I , 29 S ..,=' · 00E I. 100 0 4,. S ,.:;8 0 E ':,. ',,.o.::~x<:,-~ -:::'t', ~4< 10----'~,.:9~_~!' ~. ~u o ,~ · 94 E i 2:00. I 0 S :[ 0 E i :::::::::::::::::::::::: o9o c:a._:: o:::'::?- ,",,~;'; ,-',. ,~. o-~ :o S: -' i500, i 0 S 'o~ 0 E LO0, 1499.92 -5,66 142:3~¢''':::< ?:, ~. ':::: z'"",-':: '~:: .=, ~/,F:;O_.E: J. 600, I 15 e ............... o I 0 W .~ 00 ~ 1o=99,90 - 7 ~ .:'::'.., 1 ~,='"'-' ,~: o 90 ':'. ./a, o"" x, ~,,~ E 1800, 0 45 S 5 0 g .,.~00. 1799,87 -'10,~'~',~ i7''~-,`~,8~ i":.,,24 S 7,58 E 1900, 0 45 S 2=,., 0 W i00, 1899,86 -'12.2:[ 18'::q~86 14,51 ""d 7+36 E ....... ~. ............................................................................................................................ .............. 2u~,O. 0 `30 S 8 o .- ~ , , 85 - 12 ~ 89 :I. o-> q ~., =. -.. -. -. .,,a.~ ~ 7,81 E 9100, 0 SO S ,1'~ 0 E .J. O0~ 2099~~'~' ---1S 08 2(')98,~'~ 15+'72 S 8,5~~ E 2~ ..... 0 / 0 E i00. .... ~'"~'~' '~" .........."~ ......... 2300, 0 4=~, S 2500. 0 `30 S 13 0 E lO0. 2499,83 -13.26 2428.83 16.82 S 12.10'E: 2'600. 0 0 0 0 100, 2599,83 -13,65 2528.83 i7,25 S 1.2,,20 E 2700; ................ '0"-:[5-'S'-'7z~ ........ O""W ................ '1'00, 2899;83 ............. ='13,76' ' '2628,'83 ........ 17,31 'S 11,99 E 2800 0 1 ~ 0 '" · .., N 12 W i00. 2799,8~ --13.oo"=' 2728.:----~.~ .... 17+ It ~,'-' 11. 2.5 kS 29oo. 0 30 N 2.5 0 W :LO0, ~:;-379,,5.32 -1~,:I. 0 '-'"'::'"-"-:' .... ~o~o,,W:'-' 16,4¥' S 11..,'":' E 10.81 S 4,3o'::'~:',... E: .:,3 S 2;7 49 E 1 .:~'" · '? 2S .~' 4 '~ E: J. 5,,26 S 2':;' 49 E: 16,27 '- :L 7.21 '"' c, 27' 0 E 17.91 S 28 [:::6E I8.65 S ,~:'-'9 5-',"E 19.46 S S2 ;3 E: 20.04 :3 34 -44 E ~0.72 S :5:.¢5:5 ~.~3 ii:: '"-21.:1.3 S :35 i. 6 E: '"1,.~::, <::,34 42 E 20,70 S 34 :t6 E 20.0-:' " 4 , -'.:~ 3 .<:.6 E: 0.33 0. :I.l 0,17 0,64 0 · C-? 0,82 0,21 0.36 0.5i 0,46 2:3 ~:"" .-.,':" 27 G 9 O .~ .3:5 0.30 ..-'-. r:- 4 0 ~ 76 .. ..~ 0,3'7 33 I7~ WELL NO:, 8, UHo ,jOB NO: A781G041o ;:' R U I)H O E ....~-::~ T' "¥:, N 0 R Ti':t'"'SI,'O'F'E ;~ '~ I.,.'A SKA ~ 16~49:00 24-jUL-...S 1 TRUE · · ;, ....",'"f ,.~. ...... ~T'.'"' ........................... · :~r-- I.~:~ ,-'r~ .... : .......... ~r"~"~T ,-,-~ :,"~Or"'.~ ,r, T -tt::.,ea, CR~:.l] dR~.r'i DKiFT CObR.:.,~ g..:.Rl iL. AL Vr.:.~-s,ICAE ou~r:.~ n E"C A N G U L..A R DEPTH ANGLE DIRECTION LENGTH ¥'1'"' · :,. ~:P'i"H SECTION 'rV C 0 0 R I N A T E: F'E E T D M D M F' E E T F E E T F' E E T F' E,E T F E E T F' .................................................. ..................................................................................... · ' · ..... ,-, ,--, --, ,"- ", o ~.', .-,'= 58 -' '~ '- 3000, 0 45 N e.u 0='"' lO0, 29Yy,o',: -.-12,16 ,::-,.:-,-,,82 , b ..I.,80 E .... ,. .... ,-- ,- '~ 'i~, ,--' r" " =: "-? ;X C, :P 8., U I ...., .~, ,.~ 100. 0 45 N ~:.~:> u ~.:. 100, :~ 099, U 1 .... 1 i... ,..,,., ..... ~. ,., "~'""~ ......... 0 '7,5 : ' "' '~"' ...... ":" ~, ..., ~ .,..,: c., · 80 I S, t'-, o S 14,58 E ,:,.,,:C 0, I ...... N .......O'E .... ~. u.',..' · ,.:, 19'9';~80 .......... =i0'-' ''''~ ...... -""' · :~,~uu. 1 1.:;,. N. 72 0 =:. '"' 10'"'..,, g29'-~.., 78 -9.. '-/..~ 3;228,78 .... ~ ?;.. '-4,7 E 7,400, 1 r,... N 71 O. E t00~ SS9e,/'o. -;3+ ~¢,~ ,:,.:,.:,..,, 7~ 1S,89 S 18.'~"~'.-.., E ............... . ~0 I .1.5 N 74 0 E I00, .:,499,74 -7~82 '"-'""-',74 :I.~,,2':;' S 20°20 E 00, :1. 0 N 63 0 ~:. 100, S599,72 -6, '-' ...,._~.8,/,:: ,:, ~ "" o/ -"'::'"~ '""'-' 1'" 58 S '":":~ 05 E "'~""~ , "~ ............ ; '11 ." k: 'lOC.', ..:~.e,¥9+/u -5,,~,4 .~,.~2o,/0 11 6b S 2-'$ /6 E ,~/00, I 1.., N '6I 0 ............... * ....................... """'* " .......~" "" .... -,.~,-~ 10 "~5 '"'""' 3;0 E :::,u uu ~ I 0 N-,.a'~,., 0u.'"' .1.00 , S79e, · 68 -- 7_-; ~ -:~/, ..:"~; ..... / .~""-',:> .~ ,b' :::: ..... , , 3900, I 0 N 49 0 E 100+ 3899,,'37 -.-2,50 3;828,~:,/ 9,24 S · .............................................................................................................. -,; -- -' ~,?.:,o ,- =. . _ :; ~;,,:--, --. c;,.~ o A ~-',::.: · z '::; ".-, 7 91 iii: 4000 i 0 N 53; 0 E .~ Ou ,,;.,,¢:,:¢¥, , 0 o..,;~;~s~ u, , ..< ...* .... ,..,, _,., r~, 1 :} 4;'~00, 1 0 N 6:[ 0 E .i. 00~i~?~4297,60 ;;S..~0:::;i::;14228,60 4,721;S }:;51~85 11": -45()0~ 1 0 N :.53 0 ~:. ~.uO, 4-41.~,,..,/ o,~ 4~,~-.o~,.~, . l,U.. o .S~,48 E 4600, :[ 0 N -.,"-"0 0 E: 100, 4599,:,=15 S,SS 4528,55 0,55 S · '"'"'"' N ~{0 0 E .....J.O'O"; 4'679,b,.', ~;~:a';' '4628,53 0164 N g-,~' 02 4 / Ou, ':iL15 "' ' ............... ~--- -'-., "" 4800o. 1 15 N 54 0 E 100~ -?,~"'99.51 11~9I 4~':',e,.,.-.51 2,¥2 N 58.61 E 4900. 1 30 N 62 0 E 100. 4899.48 13~64 4828,48 3;,59 N 40+64 E 5uO0~ I SO N 6'~ 0 ...~:'I00~.~ 4999,44 i5,41 4928~44 4~E12 N 4°~.~95 E 5].00~ i 30 N 48 0 E 'I00~ 5099~41 17~'~0-~. 5~o~41 ~'?00, .... 1 SON' 60 0 ~::. i0~¢+ .¢I:,:,~oo i9,41 5i~'58 7~:16 N a7,~:u E 5300, I 45 N 64 0 E !A~, ="'¢"~ ,53 5221S,54 9+19 N -' 5400, ,~ 30 N 36 0 ~ 100, .............. ............................................................................ 5500, 5 30 N 16 0 ~:. 100 :;. 5600, 7 45 N 6 0 E 100, .70 N 5 0 E 100,..,='795 ............... ~9oo., 14 ~0 N i~- 0 E iO0~ =',~,:~+~4'{ ..... ' 101,71 ="'"do~.i, 54 88+4'5 N 64.32 E: . ~,~., ,,.~ .,.. .................. ..................................... C L 0 'f'Ai!CE EET 19.,..,":'5 20,12 .,,~ 21,9"::' '23, O0 24.18 ~15.56 26.47 27.38 ~8~1~ 29.08 30.03 30.98 32~20 3;3,51 59,74 66.21 75~60 S U R E DOGL. E::] Fi I ;'i E C T t O N S E V E R i "F Y D M ]]G/' I 0 G F' T S 2;'7 ':';' E 0,92 S 40 S2,'.:. ?' 0,2113 S 44 :5 Ii!: 0,29 4d .5..' b 0,2,:~ S 5'~.. 51 E 0,2='~ S 73 45 E: 0,"'-',.,,' ;ii; 7"6 34 E '-."", i'7 S 7'9 i'7'"El 0,07 S 81 2;5 E :'D~2-':; S 8 4 6 iS 0 ~ 5 i c. 86 56 El 0 27 :3 E:9 7 E 0.,30 N 8:3 ":;2Fi 0,;52 N 86 ':~ ':~' ~:' 0 30 -..., ._, L'.. + N 8..~ ''~ ,.,'::' 7 E '":".., 3; I o~" i r_ () + .'~ ." N 80 33 E C'.,SI N 79 1!!;2 E O,.,:- N 7' 7 11 i.'." 2 ,, i 2-:: DS 17, WEL. L. NO~, 8y GMS ,~ JOB NO~ A781G0416 F:'RUi)I:.iOE B~qY~' iNORT~ S'LOPE' A'[~ASKA ' T I ME DA 16:49~00 24-,..iUL.--.8 i ~hE'A'SURED']:iRIFT ............ DRIF'T ....... ...... SUBSEA R C 'T A N'G U L' A R C L.. 0 S U R E ~ DEF:'7'I-.t AiqGLE' DIRECTION L_ENGTt-.i .OEF'Ti--i SECTION TVill C 0 0 R D I N A T f:' S DIS'f'ANCE DiRfi:r3'TlOi'.~ SE,'-.-.E:R.:' ~ F f: E T D i"l D M '" '" "" "' ~-' ~' '-TM r t:.~'. ~ , r.:.~:. ~ Fii:'i:: i FEET ........................................................ FEE T FEET 9000. 11 0 N 16 0, i:-.': 9100. 11 0 N 12 0 E 9200`` 11 0 N 11 0 'E 9~00. 11 0 N 7 0 E 9400. 1:1. SO N 5 0 E 100`` 884o",,'29 .... i r:' 08., 62 o/':" '"' -: '-' ,' ,:::, `` -.: · '"' ':? °94,., 04i',J'. i O0 `` F1947-" .,. 45 1027 ,, -:',""' ........ J. i , i"J. ,.., ,- ~, ;:::: U i ,f, .,. 4 5 '"~ '? ~-- ~' :i. 00":, 904 ~ ........ z'-', ..... ,". ¢``o..,: 1046,,'75 L'¢:/,"4.,62 !031 ,.2"5 i"/ i00,, 9145,,78 'i065,74 9072 ,, :-'-':'::: 1050-,.09 N I00. , 9241 .,. S6 1",.,.., o.._,',,04 '-' ~ -/0.86,* - .... t 0-'¢.9., 49 N 184.61 E J, Oll,04 N 10 31 E i ?'''''' "':' ':) ... -' ,, ' ....,_ o ':, · ..-,. E: 1030 `` ,"" U i'.~1 "'" :3: c.:., l::' 193``03 E ' 1049``16 N. J.O :!..6...~ 19'6``01 E 1068,23 N 10 .34 E 19S,05 E 1087,68 N 10 29 E ,,,,,-~,. u u ,, 11 4._.,'":' N 4 ,.. E 600. 1""..-0 N 3 0 E 9650, 11 45 N 3 0 E ~'~,~. 81 1104~8c' .... ._. ';,'Z-o ~; `` 81 I O89 `` 5U 100`` 94S7.67 i125.09 9366.67 1110.12 50'+ 9-"~8,6,,60' ~,....," "'"'::'"17 9415``60 1120``40 199.6.3 E J. 107 -""')' ,,,= N t0 23 E 200., 89 E 1 J. 2 :,:3.15 i'.l1 n., "'; 201+43 E 11~,~ -~o36 N 10 1,,'-' E '~', 0, .32 969'::',.., MD l"'"c, PL..UGBAK:.I'( 96'.7' 5 · i I a ,:.- ..., N 3 0 E 971,5 MD iS TD 201,91 E 114 ';:' ,, 45 N J. O <::' :::' 0 + FINAL CLOSURE -. 'qlF:,:EnT!ON.~ N 10 fIE:SS 6'. ?tiNS 34 SECS E D I S'T~t~CE ~: ................. J.":[ 5'i *' 5 O'"F:'E i:::: ........ .. ~:".'; .:!.7.r.. WEL.L. ...N.0 :,. 8, . Gt',iS ..................... .,, ........ ,..~OB i'..,!O: "'"*'"' :'RU![:I.-iOE BAY, NORTH SLOPE~, ALASKA TIME DATE 16:49;00 .. 4-,..~L.,L-~ 1 f:/iuiL, t'~U+ r T R U E . oEvEr..i ~ ~' · .,'-', ..... .q -'--,' ' ,.:.C ION "'""""': ...... DEF'TH ANGLE DIREC]"iOiq LENGTH i.,~::.FiH ,..EL,:iON TVD C U 0 R D I N A T E S ZiISTANC. E DIR::" T 6000 ,, 17 0 N '~, 0., E I O0 ,.. 5988., ....,o = '"' 6100,, 1'7' :,',.5 N 7 0 E 100., 6083.,./''~ 6400,. , 20 0 N ,...~"0 E .,.:0''*.v 6866., 18 128.7n,.. 5917.,58 1 i":',..,. 28 N 68,33 E: 159.~61 6012.61 146,08 N 72,66 E 19'2,50 6106,94 .,'y 01 N ,.,e,./u 225.80 6201.18 2i2,54 N 8,:},80 E "' = 295; - 6 ~ ...., 9 ~ 42 6 ~0. 20 15 N 5 0 E: 100. 6460~07 293°36 6589.07 c, ...,0,, ~¢ I N 6 0 ~." 100.., 6:=~.':";3,,89 .327.:-',o 6482 8':,,' ' ~ ,..0 ~u d ,.. u L. J...._., ,..~4..,.,E~ ,,,., 98 6576.68 ,5700 ...... 4": ..... -. x,':/ ...... z, ...... -:., "::- ' ', On ......(&" ::' ..... : ~ ............... .~" i, '"' ..... ;..'2.:0 45 N 5 0 i::' I00, 6741,23 7;96,78 d~670 23 6900,,' 21 ~0 N 5 0 E i00, 683-4 ,._,u="' -43:2 ,. 3'?,.. o'763 ., .'":;0_ ....... . ................................................ 280.48 N 87.3;'5 E: 314.,88 N 90.66 E 349.50 N 94.30 [:' Sf::4 =:7 N 97.68 E 420.-47 N 100.82 E ............. 4oo, N ].04.00 :- -','" o .... 2!1 =' i .,, 63 · '::' ,: 78 "' ,.' ,,' ..., u-, I o N 5 0 00 ~ ~ ¥ Z 7 · ": ': ' ............. ......... : .-;,::i~.,¢-. 1" ~"" ?:200. 20 I5 N 6 '0 E: 100~:':w:i:,' 526+87 N 111,05 E 73'00, 19 ,'J5 ~'.~ 6 0 ir:: 'J. OO'l~;l:::::Y20E:+// ._:,1.73 7137 /./ 560 SS.';' i',l 114.65 E 44ol .::$:'16: ,.., ..,. 4, "'"" N 118.,,, 14 E ~' ' ,.. ' ~'- 7 7"::;Or:.,.. ,,, ri.u- :.30 N 7 0 E lO0, 7397.51 637,,:1.9 /,~,..:,_',.....,1 626.64 N 1'"i.~ , E-:'-':".,_ E: .... "'-' ...... ': ~: '-' ~ 742 J. =' `:'- ~', ~:''': 54i'.i 1 --' o 7<':'.,00, iv, 4"i,..,N 6 0 E i00., /4::,~, o::.:, ,.,,,..,o ,, oO , ._,,.., ,',..,,,, ,, "'5 ,3 E 7700 ' 'i ¢ 0 N ::3'" "' ' '"' ""-;""'~ ~ "" ' '"'"" ' '""::' '. 99 ' 0 E. ].uO, /5o7.9Y or/.,60 /,.,16 687.18 N 128.98 E 7800. 16 45 N 7 0 E: ...'JO().,, 7683.68 726.,42 761'"~,68 715.96 N 132,,.77 E'. · ...o ,, 2~ E ... 8000. _1.~ :1.5 N 8 0 E ].00. -" "' "" =' 0 q * ..... ,. /o,',..,...,. 7U1.52 /::::0"~,.81 7'7:1. . 06 N 139 ~ 7b..: E ,. . ='. . -,5. 79.72.29 ...... 8~00 I5 1,_. N 7 0 E: let ::::0/'.62 7901.29 797.14 N 143.2,t E o0oo, 99 832 ' , ~,"' 7 / 8200. ].4 .1. 5 N :1.0 0 E 100. "' ~ ''* .............. 822 '~.9 N 146 '~7 E 8300. 14 0 N .1. r, 0 E J00. 81'=,97 o~.:; - E e.o ~,~7,27 80Y4 .+ '""-" ...... .~.. . -;,, -,- ,--=- o-o, 19 81':;'"" 05 869,93 N 155 58 E 8400. 1~ 4'":-' N 11 0 E loo., ...., 8263. u,.., ~.~,1 ............................................................................................. 8500. 13 0 N 1~'7' 0 E I O0 + ,.,,.,,..,.,o~ ,~ 4,66 904 · 29 '"'- <""~ - ..... .................. R'P 914 4:' ' 4 8'600. 12. 45 N 11 0 [: tOO+ 84":'-'.82,.,/ ¥26,,:::.b b:6U6....,_ . ,... N io .64 E .....W, O0.~ ................ 1-~- .... 1,~:' ............ N .,4'~ ........ un" E- ............... luO.n .......... 8~,.,J. 4~'~ ~ = ........ ~" ........... 9 48;1'7" ,:>-,J .::.--,. -,,~'~" ~' a' · ~ *:' .... 93 5. ,, ..~P; '-< ' N .... 169, ;32' E .... :::..7;3 N 17:*,..3;5 E 8800. :1.1 4:'.., ~'.~.. 14 0 E .~"00. , o,_.',..,...*'"" ' ='-' ~ 26 ':;', 6:'2: · 97 <::, ~ c"' "":' A'"~,.: , 26 q" ~:;'"..,., 9900. I1 ~0 N 15 "' E :it}O, 87....i,,21 ?',e'?~..~.2 ~:.5U0,,21 9'7":: ~.~24 N 179,37 E: · FEE'[ ri M ri G / 100 i::' T :1.34.01 f'4 3;0 39 E 163 ,,. 15 i'.t "2,':, 27 ii-] 194.,.75 N 23 12 E · ~. % -:,, .... '~ c:' ~...., , ].'-,' N,:.0 ,..0 E 260.20 H .1.8 55 ["' ...:, -v -~ ~. + -..Sd. 0.25 0,25 0 * '-': % 293,,72 N ].;? :',_"3 E 327,,A7 N 16 4 E 362+00 N _1.5 6 E: 3;?6 ~' '"' 4 ., o N i ]. 5 E 432.39 N 13 :::'-7' E: 468.+47 N 12 50 E 503.83 N 12 ].9 i:: 538.,45 H 11 5 4 E ../.,:,48 i'tli o3 E 658.37 N il C' E: 6,":. 9,38 i",~ 10 4 E: E 69<.:;'.,.18 N 10 38 ["' 728.i7 N I0 30 E 756.52 ,+ ::-")., 0 , '-? 6 0., S8 0,50 906.86 N J.O j.O 929,13 N 10 J.,'.'"' E 950,76 i'¢. 10 16 ,': 971.5t .N 10 '20 ["' 99].,61 N ].0 '::' ARCO ALASKA~ iNC. DS 17~ WELL NO~ 8~ OHS JOB NO~ ~'~L,I. hOE BAY~ NORTH SLOF'E, CAMERA NO~ 14°-' '" ii0.,'., GYRO Nil.~. 564 SURVEY /x 'i"' JOB NO: A781G0416 · ~, 17~ WELL. NO ~'RUDHOE'BAY" NOF~T"H' S£.OPEi~ ALASKA ..................... i~i A R K E R ................ T R U E S U B S E A ........... CODE:---=:: .... =" 'NEABURE[t~'VE'RTiCAL.'~'"'~;~D=TVD VERT'iCA~~ R'E~ C T A' N G U L A R C L 0 S U R E VERTICAL ........................................ ~,"' r'~ T ~ i NAf'iE DEF'TH DEPTH [tiF'F' ~:.r n C O 0 R Z~ i N A T E S ~iI~TANCE OtRECTION TI--tlC~'~N~:~ F'E E T F' E E T F' E IE T F' E E T F' E E T F' E E T [I M ...... .~ ~ iUP SAD 90':~-' ............ . .,:,/ 00 89~4,69 152 J. "~ .~.z~ ~:~s~,,A9 101u,15 N 88~6 E 1027~61 N 10 -"" E OiL/WATER C~3NTACT 9260,00 9104~;1 1~5 90SS,~;t 1042.E;6 N !94,~7;2 E 1060~60 N 10 35 E BASE SA[~ ...................... 9628~'00 .... 9=~6~;~07 ........1'~,2,9 9~$94- ~07 11zu,om ~='' ~'~ N. 20i,19 E 11~-'~,k~/-- N 1013 E /? _. . t RLn ............. ~ ....... OJE'CZT( IN: 17,'. WELL 'NO: ;MSoPE~' .... R"'~;': ............. [ ..... ' ...... ~ ............. ~ ........ ~E ~1 .IN. = 200 FEETZ~ RLRSKR,, ................... DS 1% NELL NOr RLRSKR .............~ .............. 9006 .......... : :': t': ...... . :'.::::::: .I':: :7:: :':'I::::::: :': .... i ........ :: '~:i:'::?'::':"; ::.:'!:~? ~i;:::, , ':'~:;':~ L';.; ::.""~.~: :. ', '~,, . . WELL NAME '. :.'~:~ /- .'..: '. ~ '~> ':~ : : .... ,.~/.~.~'~-~;~"?'L~::.:::T:, ,~','';'.';?.:::':'t:: .: . :' :"...;.:?;~:'~"?:':;? ~ . :, ,: ,. LOCATION . .:.. ,'.. , .>.~. ,.-, ,.., ..,.:.' , .,,, . -., .. ~ ,~: .. ? :. :,'. ::: :: :::." ::.::~'::'.: , ,,, · .-,:~:~....:.:: ....... .... : .... :¥.::.::~:...,, .:::...::....>,.. ~. JOB NUMBE~ _,:.,:.,: .....':,::":':::TYPE OF SU~VEY .... . : .,. · ~OFFICE Eastman Whipstock A PETROLANE COMPANY P. O. Box 4-19?O/Anchorage, Alaska 99509/(907) 349-461 June 30, 1981 .. -. ' ' .... t',. ARCO ALASKA, INC. P.O. Box 1479 /~chorage, Alaska 99510 Well Number: D. S. 17-8 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: 30-June-81 Method of Computation: Radius of Curvature Surveyor: J. Cook Job Number: A681D0384 . . Attn: 'Bob Hines Dear Mr. Hines, .. I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. - S~cerely, ' . ] Dis r~Fct Technical Coordinator TJ/dj enc. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/SaleS/worldwide 17, WELL NO; 8 l'lSS ~.~ . '~'~'.'>;'.i. ' -.JOB'NOI~:A&810 384' '~' '~ ~:' '"" ...... ':''-" PRODHOE BAY, NORTH SLOPE, AI.ASl~'i~'i:'i"-:~'!!''-<ii'''''''':- -.."-,'. ' - '.' -'?~,~ ' ~, ' -. .. ~:.'.'~ ~" i,.':',~7"~ ~ .6' ~'.~ . '~-~'::: :.' , '~- ''~ ~"-.~. ' '~'~;~ : ~(:"-~,' t~..~'::'~,~.~' ~ ' ~ .%" ~¥' ' .,~ . .,... . :~. .- .:. ."~ .., -. ,.. .... ..~...-:,: .., ¢-,~ ..... : '.." ...~,,.....,... . ...,. .... .. :::~ :~..,~...., .~..,:.,.? :.. - . ROWAN 35 DECLINATION~ 30 1/2 DEB EAST . . .... :.. . ,, ....~..~........... ... ~ ...... .. , ::::~'i' ... .. . .. "'"" , ' · N'.":'>:' '~:.' ". ~' :iS 17, WELL NO~-8' DSS - JOB,NO:~A'68i'])0384':,:ii:.~.,: .: ,,..':.:;.-,'~,-'.'..:~,>-¥Z~E . .~.=[r~ .... " :'RUDHOE BAY, NORTH SLOPE, A'LAsKA' ;/"'.". .... "' ' ~ '":":';>~"""~; '~ ' ' ''" ' ' --" . .... .:,,.,,,.->.-,.. 08,~4.44 ~ ~ ; ~' .' . -' . , . - . . ", ." .; ,;. ~ ' , . . , . · , ..¥ .- ,- ..... · . .: /~..,, -..:;'; ....... -': - -. .... ......... ?,. ~E~SURED DRIFT - DRIFT COURSE VERTiCAL'~VERTICAL':.'-~-SUBSEA ~.. R E~"~'C...T..A';~."N'"~'G~U L:~.~' F<~.;~:,:~.:~'~:.C'~"L?:?'O~-.~S:"U E E DOGLEG DEF'TH ~NGLE DIRECTION LENGTH., DEF'TH );~SECTION ;":~.-- TVD .. ~.~;.'C':'O>:O,R~D~"I'."N~"T E.~.S':;DIS'r~NCE-~,~.DIRECTION SEVE'RIT~ -"FEET .... D ..... H ........... D .... ~ FEET-~"~'EET~FEET FEET .... ,.. ' ;~'FEE1- .. ~3 'D M"'-~G/'IOOF~ . ' .. .... . . · ..~,_~ .-.-' ', -. :..;.~.-. . . L . . ~:.... -.' · ,, -. %~:.-'""; ."'~. ,-. :. o,oo 1481 ,: 1 15 S lO 0 E ' 4S&, '- 14~0,?0.?;-"...Y..'-0,S5 ...:.140~,?0 ;~/~'.;".:;7:, 4,14 S.'~:.~:..'.':~;:~.~12,61?."E .~.~?..:;s':.13,27:~.;-:~J~.S '71 :'~l-~::E'~':~;... 0,2? ~...., '.. . . l-15 N'35' o o23, 37'E 0,07 ~'I'~7; ' 1--~'~5'5~0-~-4'~~5~-~&-,~'7-~'-' 1~';70~'~-'2~~~~?~-¥;-:' 5~'?'-~~5~~~'?--~'~~0";-1~--' 5495, 5 30 N 14 0 E 298, 5493,62'-;;;~, ~'31,03 5422,62 .':y"14,?0 N :'... 66,37 E '":-'"&8,02 N 77 21 E '. 1,45 5583. 7 30 N 10 0 E 88. 5581.05;;',-:,'. 40.?8 5510.05. :724.&5 N . &8.44~'E .': 72,74 N 70 12 E 2.33 ~'"~0~~~3'0-~7~~'E 11''''~ .............. ~~ ....... ~r;-~-'r-~.-~-' ~ ....... . . . -' 7, - ~,~~? ~-: . ~,~ . ~,~? . ? ~,x~--N - '7"1;-~-~-'.-'.:_/B3~0'0~--5-~ .... ~'~: 2,5? . -. . .~:-, ~ ?.~.. . . . . . ... .. . . ~;- . . _ - ' ~ :?:S?.. ' ~ ' ~: ~"':'" '".':~'~'" ..~ :.." :~?..:;;;;L...; '.. 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'.',.~:,~.. ,' · ',;'- ~'~'~'-',,.'/_-.:-' :'.,:..~:,~:-:~ ~':,..~'~:...,-~.-~,-.~,.,.,'~:..,~'.,."~,:,~. -~ ..>.~- · -~ -::-,?>~.-.-t~:,.~,. ,,?,.'-'.'.,' :,-,~:',.,~ -',',L ~'.: . ,- ~ ', '' :. - ~z*~. ~'. '~:; .~-, , ..--~?' ',.. ': ' ' ~ . - - ..- - ' ' . ,' .... ~,. ~--:,. ~ · ~,,~. ,,.-~ . ,~ "~. , ,~-, -..~::..-'. ~:' .-~ .... :-.~ ,~ -.,.~-~:~' .~.. :.;',, '-. ~.~',~' -~'-. ~. ~'~ , --~-~.:~' ,- ' · , ~ · ~.~ .... -.~. ~ -~ ~ . .~'~ . · ...... .... · ,.~,.._-~, ,,,.,~.. :, .., . . . , .. ... , ~ :,.~,.: . . . · , ...... ,- ............ , ~ :-, .,., .., .....,..., .~...~,.~,. ....... ......... ~. ........... ,., ,. ~4..~-~-~ ~0: :R6~ ~UD~OE .SRY,. NORTH i S_LO?~?LRSKR I iSEHBLI RHGLE BUZLD'I:i~£HBLY .HOLERSSE,BL¥ HOLE ARCO ALASKA, :-INC. ~-F4-;-~-=' · 1'7.' NELL NO: 8 'DSS BRY, :-NOR TH 'SL OPE,' ALASKA 'WHIPSTOCK,,. - IZONTRE .-:-? ;--;:, ...... --f-:-~ ROJEgTt ON-- IN. 200 FEET i -.STATION= LDEPTH 9730 MD. 9554,36-TVD NORTH 1166.34 ERST 235.67 : 1189,.91' 7316 iRCO ALASKA, INC. · ~'RUDHOE BAY, NORTH SLOPE, . . ,.~,,"~~-,.,,.,~. ,,,.,." A681'Zi'0384- . -. '.. ~ : -./,,... . !.!::..' ... :-_.. :.- . -. : :.:.. %'..':;./::,:.:. '.- .... .... :. ~ ; ~..: ..... ALASKA ;URVEY FILE NUMBER 230 rlEPTH 5300.00 6158.00 8917.00 · ~-~.~ ;.' ~-::-? :-,? - ,' · '' ' .'-'..: .... :.:'.~:'.~.2. ....... . ..... ..~.~' ': ':: ~'..;-'i". ::-:i_.,.-'. .: ' ' '.-', '' ; .' .~i: ':~' ~.: PACKED HOLE AS~M~LY'~::~.. ".. _..'':.'~ ~ "_ .':L:'~~~?':?'.:'~:'~:~"~.~'': :' '"":: '.: . PACKED HOLE ASS~'~:?'3??<'~:~:~'"./' -;~" ~ . -:~," :~J~???:':-;-~' ':: "'~'.- :' '" : . .. : - . . PETRO~NE ~MPANY - :: ..... - ' 't-: .... ...:.. :. ' ~E~GHT ON ~T''' ". '.:.t'?;~:'-....''.' " . :'.-' '"" '' ...... ' .... WE'I"GH~ ~'~~'~O-~'~ZrS - ., · _..'~'. _-~:. 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'".;.':. ::'..:':, "; -. . i~.~.';~ ..... . ,' , .~. :.:, "; ~-: ' .-: -' :. . -; .' :. ;.'-: ', '-' .'; " ..... /',::.- : .... -:' ":::~:::: :;- ~ :'" :'-] .... F':-.;-.'~'?.`''', '" ~- ' ,.::~"':-.":""".: 2"v-~'~}'.'~,;,~fi.::., .,:'.': ..:.~ ~ ~' .'.-..'.,' . ": ' . ' %'~. ~' .'',.~,'~&"','; .. ' .-.. , . ~ ~ '' . ..~- .,. '--'./'. l~:, · . ' -' . .h. ~'',. '. ~,"),' ..'. ',", -.' ' " ',~" '~ , ', ' -:'": ': - .'L ,. -'"'~ ....: , .. ...... . . ,--.,.,..--' , ,--,, ,: ...... .:-' _ ",.: - '.-.--..~ -':-:'~- ~?~;T.'.~%'.~-_T...,,'1'.-.,; .: ...'-.,7~'. -'- ; --,' ~.:; ..'.:,' .~:.:.:.- .:'-::!'.~u::'...._::.~> :.-.":...;..:3j~::-:;::.-...:,t.j~:.,· ..,.::,'>:',.::;.'-'.- '-. 'h.:]:: ~,...":;:..:'. :-'. '' "., .: .' ". ': ,', · · :"~ t~' DEPTH '".:<.'~ ...... ,' '.", .";, R, P, H ,. '-:;'~,-~-~ ..;-'-~,.'~.,:-:~ -:,:, .:~:..:'-:. ".<'-:'."?~?p~:'~.. :'": .... :...~:-:...., ::-: '.,.. ~:.":'-,,w'.~.:?~.::~ .~.::~ ..... ~':'.':-'.< ',:"::.-~'."~., .:.:~ ..... '.:~,.~ .... ,;,:,~;-~- ?:,' .-' '. "-:.',,'.' :.:;-~:~;:.:~..:=~::..:" ,, :~ ' '. :~' ::'.'.: ::; ~:' .... .-' '- ~:~.~:~;~ · ,, .:. >' ..,~, ~,,t:. :;~- ;., ,,~t :;~' '. ?:.. ,. E'.:" ' ., -,'.;. j:-.::,, .'-<.~:.~ ~'..~ )i- ~t'.-37~t~,~,~-:-~ ~:~:i' :' '.':.-7" '-' '"'. ="~:::':t':.7..' L ~ ':: :?.¥.?~;' :=' :: ~'"--,f'-~' "t:'~' ~.Y :";: '.4~'.:.:.,:' :.,'..::.: ':. t ~:~:.::' =' :'-.:y - .'> F' "]:'. t ~ .':'.~'. .... ~----~ ' ~' L"-.:":: '~:::h'"t ..... ;:: -: -.: ,' '.L:.t. ---~:-=-. =':== '---:-'h . I', ;a ..,', ",~ (~ "t~: ,', Check Form fQr tirœly cŒlpliancc with our regulations. ARço - PEDS /7-? O~rator, Ylell Narre and N~r . Reports and Naterials to be received by: !j'- / -t?¡ , Date Drill Stem Test Reports i . d ¡ I I REXjulre ' ! Date Received I I I ! 1 ~ I ¡ ¡ ! -- Yes ~- 7 -:21-~ I t-- òf( . I ! ' I Yes, [1- .;¿(-fl ' ¡ 0 t<. I I I IÆ~--=_PJJ J ó 1< I I I, ~ - P I I l æ I( ¡ !' ¡ I ¡J/cJ ;t/e- ~--- :--¡_._--~ K ¡ ,! ¡ ¡ I I 0,', /# i /f/'cJ /'Y'~'-i ,- ..1 , r( ¡' I : ! I I "y~s, I, 5~ ;2ß-gl-i- OJ< ! ' l.._.__.. -!" I~~~~ ¡_~_ff~-fL ---~{li~~ krf~ !~Æ €-' . ..__.._~._..- I ,._u,...-l1/(.. ~ proouction T~S tRefDrts~l~ ~ - Pe rfZ>! --- i oj< "7~ /3-f?¡ 7- ;2;¿- ~I 01< - . 7 - ~ Ã-;~- 9")---' ---, 7-'(i1 ¡ø-,f / -- Ô'/<' Remarks Completion Report Hell History , Samples Mud Log . Core Chips Core 'Description , i , t Registered Survey Plat ~~ion Survey .-/' >,/' ' ..J/;;:".> . / .-----'~ ,..----/"'"(/ J g irectional Survey" ',' . "'\ Logs Run , Yes Digitized Log Data Ye6 .. t.. ~~~ "f:, STRATIGRAPHIC HIGH RE'SOLUTION DIP METER LOCATED IN THE APPENDIX ARCO Oil and Ga~,~' ~mpany North Alaska_ District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 8, 1981 Reference: ARCO Open Hole Finals D.S.17-8 6/26/81 FDC Run 2 2" & D.S.17-8 6/26/81 FDC/CNL Run 2 2" & D.~.17-8 6/26/81 BHCS Run 2 2" & D.S.17-8 6-22/26-81 DIL/SFL Run 1,2 2" D.S.17-8 6/26/81 C?L(Cyberlook) Run 2 5" D.S.17-8 6/22/81 Dipmeter Run 1 5" 1! 1! & Please sign and return the attached copy as receipt '.o.f.. :data. Mary F. Kellis North Engineering Transmittal $416; DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOB I L GETTY ~,,,!: ~, E ~~ MARATHON Alaska 0il & Gas Cons. Commission CHEVRON Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le H. Hami ltoq/~ll Chairman Thru~ Lonnie C. Smith~ Commissioner Doug Amos Petroleum Inspector June 24, 1981 Witness B.O.P.E. Test on ARCO ' S D. S. 17- 8 wel 1, Sec. 22, T10N, R15E, UPM Permit #81-74 on Rowan Rig No. 35. FridaY.. June 12, 1~98.1~ I traveled this date from Anchorage to PrUdhoe Bay to witness the B.O.P.E. test on Rowan Rig #35. ~at~urday__June 13, .1981.. The B.O.P.E. test commenced at 4,00 PM and was concluded at 6t30 PM. There were no failures. I filled out an A.O.G.C.C. B.O.P.E. test report which is attached. In summary, I witnessed the B.O.P.E. test on ARCO'S D.S. 17-8 well. I filled out an A.O.G.C.C. B.O.P.E. test report which is attach ed. STATE OF ALASKA ~' ALASKA OIL & -CAS CONSERVATION CGMMIS~±ON B .0. P.E. Inspection Report: Date Well Operator ~--~c~ Representative, Well ~ ~- [ ~- ~ ~/~' ~tion: Sec ZZ T ~ ~ R ~ 6 M ~, ~ ~, %% ~asing Set ~illin~ ~n~a~or ~o~ Rig ~ 55 Repre~ntative Location, General Wel 1 Sign Ceneral Housekeeping Peserve pit BOPE Stack Annular Preventer--.I -- Pipe Rams B1 ind Rams ~ Choke Line Valves. ~".C.R. Valve-- Kill Line Valves !.~heck Valve , · : Test Pres sure .__~_000 ACCUMU[ATOR SYSTEM Full Charge Pressure ~\5c~ psig Pressure After Closure %~c~3 psig Pump incr. clos. pres. 200 psig ..... Full Charge ~Pressure Attained: , ~ N2 ~/~_o~ Y~ ~/.t)%Zo~ psig Control s: Master ~ ~ Remote ~ Bj!n4.s_~i_._t..ch cOVer Kelly and Floor Safety Valves- Upper Kelly i Test Pressure' Lo~er Kelly_. I , 'Bal 1 Type ...... } , , Inside BOP I Choke Manifold No. Valves__ Test Pres sure Test Pressure Test Pres sure I Test 'Pressure No. flanges. Adj ustab le Chokes__ Hydrauically operated choke min ~ sec. min_ol_sec. Test ResUlts: Failures. kl,~cl~ Test Time.',, ~, .... hrs .. 1 CD ~ ~ ,~ Repair or Replacement of failed equipment to be made within 'days and Inspector/C~mission office notified. Remarks: Distribution orig. - AO&C~, C cc - Operator cc - Supervisor I, IL llll May 29, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Prudhoe Bay Unit DS 17-8 ARCO Alaska, Inc. Permit No. 81-74 Sur. Loc. m 2359'FNL, 955'FWL, Sec 22, T10N, R15E, UM. Bottomhole Loc.{ 1342'FNL, 1218'FW~, Sec 22, T10N, R15E, UM. Dear Mr. VanDusen{ EnClosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If a~ilable, a tape containing the digitized log information shall be s,abmitted on all logs for copying except experi~ntal, logs, velocity surveys and dip~ter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habi~t Coordinator's office, Department of Fish and Game. Pollution of any waters of the S~te 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 Mr. P. A. VanDusen Prudhoe Bay Unit DS 17-8 -2- May 29, 1981 co~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very , honnie C: ~mith Commissioner of BY ORDER OF THE CO,~SSlON Alaska Oil& Gas Conservation Commission EnClosure ecs De~rtment of Fish & Game, Habitat Section w/o encl. .Department of Environmental Conservation w/o/encl. LCS ~be ARCO Alaska, Inc.( Post Office [~,.._ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 28, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 17-8 Permit to Drill Dear Sir- Enclosed please find our application for Permit to Drill DS 17-8 and the required $100 filing fee. Attachments to the .lication include a plat detailing the section and plan s of the proposed wellbore, a proximity plat showing the subject wellbore's position to the nearest well drilled, and a sketch and description of the BOP equipment and testing procedure, including anticipated pressures. As we anticipate spudding this well on or around June 10, 1981, your prompt review of this application would be greatly appreciated. Very truly yours, P. A. VanDusen District Drilli.ng Engineer PAV/SLB:sp Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~[] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL I~ SINGLE ZONE [~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. BOX 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 2359'FNL, 955'FWL, Sec 22, T10N, R15E, UM Prudhoe Bay Unit At top of proposed producing interval MAY 2 8 ]98] 10. Well number 1342'FNL, 1218'FWL, Sec 22, T10N, R15E, IJ~a DS 17-8 At total depth $1{a Oil & Gas Cons Co 11. Field and pool 1342'FNL, 1218'FWL, Sec 22, TION, R15E, UN 4n~.h .... ' m~-.Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. ,~/~ Sm~rudhoe 0i 1 Pool 72' RKB ADL 2833l 12. Bond information (see ~O AAC 25.025) Type Statewide Surety and/or number Fed ]:ns Co #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed ENE Deadhorse, AK 5 miles 3940 feet well 2640 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9722'MD 9521 'TVD feet 2560 June 10', 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~ psig@ Surface KICK OFF POINT5200feet. MAXIMUM HOLE ANGLE 28°l(see2OAAC25.035(c) (2) 4634psig@__~.~ft. TD(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT" . Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30 20 94# H-40 Welded 80 '32 132 112 ~1]12 275sx PF I to surf.' 17½ 13-3/8 72# N-80 Butt 2668 32 32 2650 2650 2300 Fondu + 400 PF 12~ 9-5/8 47# L-80 & Butt 96;12 30 '~30 8957 ~18756 Stg 1,500ex Class 'G S00-95 Butt ~ I Stg 2-300sx PF I' " .8~ 7 29# L-80 Butt 1107 8657 ~,8456 9722 ~'9521 400 sx ClasS G 22. Describe proposed program: · ARCO Alaska, ]:nc. proposed to direCtionall~v dril;l this we;Il to 9722'MD (9521'TVD) to · produce the Sad;lerochit zone. Logs wi;il be run across se;lected intervals. A. 5000 psi RSRRA B0P stack will be instal]ed and tested to 5000 psi. .The BOP,-equipment will be pressure tested each week and operationa;ll~v tested each trip. A st~ing of 5½" ;17# L-80 tubing, packer and necessary provisions for subsurface safet~v equipment will be run. A non-freezing f;luid will be left in a;l;l uncemented annu;li within the perma- . frost interva;l. The packer wi;l;l be set above the Sadlerochit. A separate Sundry Notice will be submitted when the w'e;l;l is to be perforated. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge i S'GNED ,-~/~, ~~ T'TLEDistrict Drlg. Engineer DATE/I~,.I~' The Space below for Commission use .... '~'"; ' CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required J APl number r-]YES ~lO [-]YES ~O ,~YES [--INOJ 50-- 0 '~¢-'C° Permit number Approval date ~'J"'~2~ ~ nr--~f~c)/l~l J SEE COVER LETTER FOR OTHER REQUIREMENTS ~ APPROVED BY ~,~"~ _- ,COMMISSIONER DATE ' t~:y :29~ 1981 v " ~ %/ ...... " by order of the Commission Form 10-401 Submit in tripliCate Rev. 7-1-80 7. Y = 5, 928, 400. 63 x: tAT = 70 12'27. 01" LONG = 148°18'47.9.12'' CELLAR BOX ELEV = 36.5' ~TY MA, P I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY' MADE BY ME, AND THAT ALL .DIMENSIONS AND OTHER D~=TAILS ARE CORRECT, AS OF: N~,//~) { D.S. 17 CONDUCTORS 7 THRU 11 as-Bu~ LT tOCAT~ 0~S STATE PLANE, LAT & LONG 10. Y : 5,928,051.78 X ~o9,259. LAT 70~2 '24.248" LONG 148~18' 45. CELLAR BOX ELEV = 8. Y = 5,928,284.55 X = ~09,203.60 LAT 70 12'26.552" LONG = 148°18'47.19 CELLAR BOX ELEV = 36.5' 9. Y = 5,928,167.69 x: LAT = 70 12'25. 95" .LONG' 148°18'46.471'' CELLAR BOX ELEV = 37.0' 11. Y = 5,927,935.32 X = ~09,287 76 LAT = 70 12'23.695" LONG = 148°18'45.031'' CELLAR BOX ELEV = 36.9' IIII I II II I II I II NORTH AMERICAN PRODUCING DIVISION ALASKA' DISTRICT- PRUDHOE BAY i iii I I i Il/ III I ' i ARC8 RLRSKR. l.,~C. os ~. ,ELL ,~, ~ ~~SEO PRUDH~ BRY, NORTH SLOPE, RLRSKR ERSTMRN WHIPSTOCK INC. 300 200 [00 5.00 ~ 400 ~00 200 · 1~00 100 2OO 300 NORTH 4030 3857 3676 6077 SCRLE 1 IN. = 100 FT. 100 200 300 I I,, RECEIVED Oil & Gas Cons~ Com~tss Anchorage ion RRCOP. L.RSK~ INC. NELL NO= 8 PROPOSED PRUI~ BRY, NORTH SLOPE° RLRSKR ImlPST~CX. I~C.. . ~ · . 'I~ --- TVD-8906 -. T""=9107 EEF. I050 ""~TH 101"/ ERST :=63 ;. , 16{15 21 22 1~42 Ft' !Flf 1218 .. ' ..... ' '"i:.'-.:-::'!'..:~,'::;~.::. ::.:.:{':.!:t:':.:i::-:-:-:--i ....... , ............... ~ .................... ,._..--.~_: .. ............................... · .. .... :.~ ....i : ........... :'".'~ ' :: --- ::' : ' :' i' '.. ' . 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L~ 77:::-"_:: -.:.& ..:2'_;.~~ ....... : ................... : ~ .......... :..: .'. : i .: .'. ':'.:.: . .' : . ' .'.:.:: .:.i ",:":i' ',":::,'-, "'.. ......................... 7~"T'"T '::'"-'??':' 'T-~'--? :. ':- . I : ". :" '.. ',. 'i , I : , : ' ',: : ,.; ...: :.,: ' . · : :. ~ ...... I . ., ................. .* .,.,..,{ .... ~ ......... ; :: ~ ........................... { .............. ~ ............. ! ........ , , .......... { ............. ~. ._, ......... {. _,,~. · ..... .--.._ ;. .{ ........ .] .... : .... , ..... ,~ · : ............... ; ........ ,.. ,m, ......... , ..... ,. , ..... :-:'; .......~'-;i'-:'-:-q---': ..... :: .... ;:'-:-~': .......... ;'-:-!-::-.-; _ :..L._: ...... : .... ~-.-.'..j::-.:-'-:-~ ..... :..:.: ......... '..:~i.:::;.u.:'.:r:'._X_:_;-:-::'.~-:.2.:.-~;_:._',.:..:-' ': " : ..... ' ' ' .... :::::":' ' ' ' ::'t'"' '":'::';:'~:': '"' "':''::':':~:" '":': : "'"':i-:::'-t::::: === ====== ================== Ora'~,-::: :::'.: ........ . · ' .... ~ ........... ' ................. ~ ............ .~ .......... , ......... , ................. 1.' .... g ~. .................. -!' '.'. :..~: ::: :.'I;._ ': ': '. . : '..::'..:.~:. '."I : .: .': .. ~ ...'i;;::~ :_:_: ,: ':::J';:.,: :_[::%;.I .... : .....~ ......... : .......... '-" : :.:- .., _:_--:_'. '.:_'.;. ~ ._2:_: L: ; ' ' i ":: ':':" .: ': ]:::'i!.:::!'i:i: .... ............................... : ........... :_._:::'.: ........~ .............. _:_: ..... : ............... : :: .".: ............... ..... . -_ ...... - ........... ': ~ - '_ _ - .... 7. Y : 5,928,400.63 X = ~09 1 75 53 LAT = 70 12~27.~01'' LONG = 148°18'.47.912" CELLAR BOX ELEV = 36.5' I HEREBY CERTIFY THAT. I AM PROPERLY REGISTERED AND! LICENSED TO PRACTICE LAND i SURVEYING IN THE STATE OF~ ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY' MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETA~ILS ARE CORRECT, AS OF: ~.~.- . D.S. 17 - CONDUCTORS 7 THRU 11 ~.. ~~ ,, ~,~ m-BUILT LOCATIONS STATE PLANE, LAT S LONG Y: L 7o LONG 148~18' 45. 755" CELLAR BOX ELEV = 37.1' 8. Y = 5,928,284.55 X = ~09,203.60 LAT = 70 12'26.552" LONG = 148018'47. 191'" CELLAR BOX ELEV = 36.5' 11. Y = 5,927,935.32 X = ~o9,287.76 LAT = 70 12'23.095" LONG = 148°18'45.031'' CELLAR BOX ELEV = 36.9' 9. Y = 5,928,167.69 X = ~09,231.69 LAT 70 12'25.395" .LONG = 148o18, 46.471" CELLAR BOX ELEV = 37.0' I I I I II I II II I Illl 12..~. :[."7W~I.~5 q' - t :~ .__ MAY 2 8 1~ Alaska Oil & Gas Cons [CotJ~-, ~JJJ. J,~ } Anch0rag~~ I I IIIII ~ AtlanticRichfieldCompany' DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION 6.~,~I-~ ~q-~,~- ALASKA DISTRICT--PRUDHOE BAY . iiii iii iii i iiii i i i i i i iiiii I lull L I I I II 13-5/3" SC? STACK giAG,qA,'.! Accu..-.ulat:r Caoaci tv .'ess . RNNUL~q~ PREVE:ITER . BLINO'RRMS . PIPE RRMS l· DR I'LL ! NG SPOOL PIPE RRHS -. 4.. o 12. Check and fi.~l, accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 15CO ps'-i, downstream of the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. Record on IADC report. (The acceptable lo~ler limit is 45 seconds closing time and 1200 psi remaining pressure. ) 13-5/8" BOP Stack Test Fill BOP st~ck and manifold with a non- freezing liquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark runni,ng-joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. Close annular preventer and chokes and ~yPass valves on 'manifold. In each of the followi'ng tests, first hold ~- 250 psi low pressure test for a minimum of 3 minutes, then test at the high preS'sure. Increase.":p'ressure to 3000 psi a~d hold for a min.$~m--.oi~ D-.---minutes. Bleed presstJre to zero. Open annular preventer and close top set of pi[ "tams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. Cl'ose valves directly upstream of chokes & oper chokes, increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. Open top 'S.'~f- of pipe rams then close bottom sel of-pipe rams. Increase press, to 5000 psi bel¢ the bottom set of pipe rams & hold for at leasi 3 minutes]. Test remaining untested manifold valves (i.f any) with 5000 psi upstream of valve and zero pressure downstream. · -' .... '.-.. Bleed presisure to zero. Open'bottom set Of pipe rams·l Back off running joint and pull ou~ o'f hole. Close blind rams and test to 5000 psi for at least 3 minutes. Bleed pressure off all equipment'. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. · Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump· · Check operation of De Gasser. Record test information on Blowout preventer test form. Sign and send to Drilling Super. '.. ~P.e.~r~f?_.m.._c~omplete BO_P~E~.tes, t.?nce ~ 'w~ek and .. 14. 15. Anchorage 17. CHECK LIST FOR NEW WELL PERMITS Company ~~ Lease & Well No. ITEM APPROVE DATE thru 8). -(~' thru 11) (4) Casg~~-~~f2 thru (5). BOPE~~ a'~-"~/ (6) Add:~ . . 3. 4. 5. 6. 7. 8. 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached .......................... , .... Is well to be located in a defined pool ...... · ............ Is well located proper distance from property line ....... Is well located proper distance from other we%ls ........ Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included .... IS operator the only affected party ..................... Can permit be approved before ten-day wait , ...... ...... · Does operator have a bond in force ..................... Is a conservation order needed ......... , ......... · ...... Is administrative approval needed ........ · .............. Is conductor string provided ...................................... . Is enough cement used to Circulate on conductor and surface ....... , Will cement tie in surface and intermediate or production strings .. Will bement cOver all known productive horizons ...,. ............ ... will surface casing protect fresh water zones. ............ ,...',... Will all c~asing give adequate safety in collapse, 'tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............. ~/~ Is adequate well bore separation proposed ........................... Is a diverter system required ............. Are necessary diagrams of diverter ~'BO~ ;qul;~;~;'~;;~;~';::: [sim Does BOPE have sUfficient pressUre rating - Test to _~~ .. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: RE,MARKS Geology: Engineering: JAL~_,. -/ rev: 03/10/81 INITIAL GEO. UNIT ON/OFF' POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. *' .* ;:: 5 8 2 6','0 ':::.':.:;. '3 · :..-.?~ *"'"'~': 5~2~ ;'o'''~'':''' .... i,. '"~'"':":~'"":'" 5~ ';~ ~-'.-..5 83 0,0' :.: ?..:~ 2,4'.... :.' :'.,::. 5 6' {".~}~ *. :",:: 5 8 3 8,0".'.':': "%2,5'.:' :~:"; ,"':::":,'. 7 0 ::::":'.,'~?,:",:.:'~ . ...... c_,., ~ ..... , ~ ~ ................................. ~ ................................. , ...... ~ ..................... ~ .................... ~ ............................. ~. · ,,, ....... 1'75 ARCO ALASKA I'C,, . D. 6. 17-8 ' ' PAGE '2 ILE 2 ,...:, , ~'DEPTH ." 5 g g 2.0 o. 5 5 . o 6006 02 2,0 ,..~ . .,, '60~2.0' 2.6 7o ' :. ARCO ASASKA INC. D.S. 17-8 PAGE':'4'FILg '2 . -,-.-...-,-.,,,,-..,,-.-.....----...--.........-.......,.,,,,,,,, ..., .... ,. 7:; ,-:" ~ ' .:"' ..-'< ' lZI .' '~ ".' -.<.: ..~:: ': :.: lZl'"'< 1 ,. ".:.:::::A 1-3 ~:'..<~' ::;--2..4::~ .~,0 " 69 . 5.5 94 4,4 '119 1.5 .51' ~. 9 ....-'. ",~ 319 · 0 .....305 ::!~;'* ''''''~ ~ o $'4', o ~ :~,3' '~ '"": ',-~': '~ :<': ~'3°293'i ,,. h,>:?::~,~:: ~'o~ . ~,"~ :'~; *:<::.: 6 086 · 0 '7'. ,'": :': :;, 312" -' 1o '?"?" :, s ..... :" 31 ~ * ~ ~ ": '6 ~ 06., 0 ? ':.' ,:., ::::,? :: ':', '::'.. :t? ' ', :,.: ,. '.: ?:..?; "'::~"~:':;::;?~, '?~;~2:0 ,, '7 ~,~ ............ ..... ~.,,:~7 -~,: 612 6'i 0'.:???~0,7 ';, ?.:r:.:,.,: "l 5 ~ ,, .'< f::~ :~?;:~t ~ ~"'* "~132.0 '::'::"'-3.; ~ ' :: ::"314 ~' * ""613 8; 0 ':~:': ;:'6 :', 0 .......... 3 t'i 20'; . 18.6 ::,:~::~:~::??::.,~,~:~:1'~1,,. .?~..~:; :61'42,0 ? .:::3,6 ,' ~..34 :L~ ************************** ... -., L. - ~ , ~ i~ ,: .: .~, :,., .~ ' ,¸4 .'2 11:,'1' A * ,0 * ~ *'... <6266, '" '" .... *' 6276.0 ~: .*' '.':6 2 90. i 0 ~, ...... 6292'0 ":?* ,'6302,0 ********************************************** :%1 i,!i!73 % · ALASKA INC,~ D. ~, { 7'm8 '- 'PAGK' -7-FI~E 2 ~= .. :,: ~';;~* '63~2.0 7.~ 328 20,6 ' 360 ;4 * 6386,0 *' · ~.-.:~ · :.,?6390.0 '"~}~' * 6392 0 '~i£~, · .*:~ * 6396,0 PAGZ 8-FIT,E 2 ,. ARCO AT~ASKA INC. '- '-' D~PTH '~'~ DIP DIP *** ~.******... -. _ .... Azx .. *************************************************************** ...~::!. {--. . 4 . *. ARCO ALASKA INC. 0 ~ 0 2. 0 0 0 "' ,2 o 0': , '.;1, 0 0 "2 5 "... 45 4 75 9 "' 17 0 19 .5" t52 .3 .0 ........ :131 .9 329 '7-.-' 21 .0 70 20.9 20,9 '20', 20; 16. 16'8 A ASKA ~C. 17-8 ..... PA~E I~-FILE . ARC~ ALASKA INC, D, -;~:~ ~ ' DEPTH ~ DIP DIP .5 It.6 · ";:~, "6 7'2 8,0 .... ' ::1 1,7" "~:" ':::~' *' ' 6'7 46,0 '":~ ~, 0 ~,'I5 ... .... :'.:6 ! 50,0 :::..": :. ?6,9 .'.'.;.' "/.~: ~.": ;:4 '"~::'6', 52 ;'0 :~"':"~'~'~:20 "8' 6756,'0":':'::'~":' 1,: 3' "?'~':"' '38 7 6 2 ', O' ', ?'";"-6 .'8 .': 5 ",:" s :~ . .677 0 ,'0. :/...". 5,6- '~:,? ,' .2 3 .~ '"'"6772,0 '"":':'7,6 'v'..:,:~: ..... "20 ~.. '-...,677A,0., ?..;. 5,2.. .:*;:~.* ':.:6778, O. '; ·-'."' .'"' ..... ",¢ * . 6782, O...'' ;..:, 2,2 :', · ************************************ :*******: ************************* A,RC3 ALASKA D, .,~ 0 Oo 0:" 0 0 .-: 5 32 .. 0 109 7 3 . ? 9 ,275" . 7 . .-.,..,,' 50 ,:.,,? 6 353 ~ ARCO ALASKA INC. D, $. 17-8 PAGE 14-FIbE 2 · . ,. ,.....;,.,..,.,....,....:,~..,..,....,,;~,.........,..,,,~~....,~.:,..:~ ... ********************************************************************************** ...... ..:~ ~,:' -~ ~.~.:~ ,?:,v:'~.:~ ~'~ '.. : .~ ',',.?.,. -: :'. :Y:~:' -. ~':~:7~'~7.:,~:~? ?~'~'~ ~ .: .~: "L~ ~'? .. ': :,?,~ ' -,~-~ , ~95'6.0 5.9 1~4 ...... ...?, 6960.0 172 ' ' ~J~":*-"":,.' :.697 8.0 ?'?'~"?"3 '1 ," .... ~9'BO,O "'"t.,3 .......... ' ....... lSO :::':::~::"*' ..... 699'6,0 ......' 4:.'9' "'::'":" 296 21, ,0 ARCO A~,ASKA INC, D, $, 17-8 PAGE '16-FILE 2' ~,.3 8 ,: 0 ', 6 6 5 · ..J~ · · * 7186',0 -' ..* ' 7~.88,0 .-i-?~: * 7 ! g 2,0 · . ~ 'z:: .** '..~,7202,0 ..... · "7204,0 ARCO ALASKA I.~:;C. D. 6. t7-8 PA~E 18-FILE ":::::::::::::::::::::::::::::::::::::::::::::::::::::::::INDEX' 'DEPTH "* DIP DIP * DEV, D ',.'-" ' "*..', '.:.'":, .".' AZI,, , ' '- AZZ,.,- '. '. 1'-3 :.~'::"':,:::,~::2~ :,~,:' *.. '::;..~A .. ..., .. ,, ,. , ..~ ~: 2.4 3,2 3.6 5,2 3,9 3.5 !88 178 172 161 154 182 190 213 203 3.4 3.2 8,7 183 _'i71 200 7249 0 ' 2' 3 ::::.7250,0 -? '1,9. .'102 7252,0 ' :'?::':4,9 :15~ · ~'*' '7255,0 ....... 4.1 i81 ,0 2:2 :':":18 '~' .0- ;..':'.'4,1' 162:, 2 . . . ARCO ALASKA INC. ~ '-'.,,:.,.:.':.~c~ 7264.0 3.8 7268.0" 2.7' : ' -?;7270.0 8.6 190 ""7272.0 0.7 ~75 ~"7276'0 4.2 ~82 '--~;~", ' ~'7~8o, 0 2.6 :~ ~.;~,.::7282,0 ~,. 9'~', :,:-':.~ 193 ?~"*?"~'~¥'~ 2 ~ ~. o ....... o.~ ssa 20,2 6~ i6.~' "20. 1~" ':2'0,2...:: 20.2' ..... I5.1 20 :':20 20 20 20',2 PAGE ASASKA Ir:C. D. S. 17-8 * '. *-----~,-----------,---~--------------.-.----'----.---, x-~x., *' :DEPTH * ' DI DIP' '* EV', ":DE'V~ ~'DIA~ DIA'M *.BEST 0 2,5" 186 0 '2.6.,,._!-.'? 180 0 "2,5 "" 185 0 -'3.5 149 O' " 2.6: 1'23 0 O, 0 - '0,3 -" - 56 i'75 _ , 7344, *-,7346. * '73A8. *-.7350. * 7352. , 7356~ , ;7358. , '7360,0 ARCO ASASKA $. 17-8 _..,------------------,----,---'-------------------- .. ..... ..INDEX DIP ~ DEV. 'DEV, ~I'A~ DIA~ *'BEST ~% DEPTH "~' D . . . _::.:" ~ 7424,0 ":' '~ ~:~7426.0 2 ~a, .... 7-32,0 1.8 ~'~. *:::%'7 ~ 4 ~. o,,:,., :~ 2.7 ~:,~*' "7444.o '" 3'8 4.6 77 1.27 ..... 92 -" -6t ~7 I5:, 2 D. $. 17-g ...... PAGE '22.,FZruE' "2' : .... ~:: ~ '''''''''''''''''''''''''''''''''''''''''''''''''''-'''" INDSX -~- . ~ D H * DI~ DI~. "*' 'DEV.' 'DEV. DIAN DIA'~ ..... ~- BES~' ~'*- ..... -;: ~ __ .* -.. AZI. : *,'" :.. ~,'-,',:',-:.- *************************************************************************** ~*.,.,.. 7586,0',.~:-., 19~6: ?,~'*'.'"":7590 · 0 .?.? 20" 0 '..:' ..:..' : 60 ~'*' '"7592,0 '""~' "4,0 "" ' 83 i8'2 "~ FORMATION * 7664,0~ * ~7~68.0 * ,:76?0.0 , 7572.0 ~* '7676.0 ~ ".:'7678 0 4.6 12' ARCO ALASKA INC. D. S. 17-2 PAGE 25-FII~E 2 D. $. !7-8 0 16.8 ' ":'":" " 251, 262 2, ::: :,; :,.<~'<:i:' 0 .~.~ : 8 9 0,0.. ~.~ :.0.8 ~' ,: ~. :, :::'.: 2 6 4' ..:.?.: , ..... '7896' 0 "~'":: :~'0'; 9 "" ............. 15 ~ ,:;:.?, ::::~"r.7898' 0 .:"~:, "~: 0. 8:. -:?;; * ':7 ~00' 0~: '"': ' O. 7' :::' '" ": 3 ::>: ************************* ~:~ ARCO ASASKA I.~C. D. S, 17-8 PAGE 27'FIL "77~," ' .... ~' ""F~RMATION ~- ' ............... BoREHoL~''~ ;~'"'~<~'/'~'>~"$' ~* DEPTH' * OI~ 'OIP ~" DEV, D~V, DIA~ DIA~ "~ a~$~'" ~ ,".c.7906,0 :' ...~, 2' ~.2 :. g5~' '> .'".~;:~..:. ?~6. l · 79~4 .....~ ' 7998 .. -"/,% * 7992 ;~ *- -:7994 ;';* 7996 /'.?~ * :,:7998 --:':~ * 80 00 .?~ ~.:,:? 0002 · ..~, ..... 8004 ~,0 o 6 00~ :8022.0, ~..:. ,:2. ~024'0 ;'"~ % :y~ ~S~'a' ", ~i~'~ .... "~ ::~ ,,----'---'-------.-.-----.---.---,-,::~-~lx ,.:...~ :::.:..: ************************************************************************** . o ....... , .'o ': '" ' z 6'3 ':", 5,9 ~:""'; '"':";'6' :'"~"': ~?' ~':" ~2. e ':::~,,:~:.-::-l:~,.6...:,~,,~.::..-?:A::<::::, :::*::'::'':~,'.:~: o ~ s ~7 .... -is' · '<'1'2,": 5 ' o :'-'"?:"i ,7 1' 4'1 ,r,,, 2' ":?::: '~'''' 3 ~ 4 'i~ S'.:~'':r':'<':';~:~:::~:::~ ~<:':~:~:~':~ :~: '~:': 3 .............. 6 3:''':'::;/~::;::'' :~7 4. :., '.:.,.: ~ 52 0''''''' ''''''~ "'PAGE 29'FILE~ ~* .... DEPTH: .... * D p'<:' DIP '":':" * DEV'- '""':DEV~ .... '";D'ZA'M'' ":':'DiA'M':' *'BEST · 15,5 1:5~ ARCO' ~LASKA INC. D.S. 17-8' ' ""~' PAGE *************************************************************************** . . , ' ...... .', ,------------------,----.---..--.---------------------,, ...-., .. ~. · ..... . ~ ~ ~ . .' .... , *************************************************************************** ARCo ALASKA I:,iC. D. $. 17-8 ' PAGE *31-FILE ~'2 ************************************************************************* . ~..-...........-...~........~.-.mn..........-........~,~ZNDEx ~,, m .... DEPTH ~ DiP DIP .... ':'~ ~ ' - ' ~'.:" ~ ": ~'.:' _-'AZI. ::.:.~... :,.:,.'::',."-. ..... :.,'AZZ:,~ .':-:~'..':71~3' :,".',~ .... '- ........ ' '. {:L. ": " ' ' '; ':'-~":':: ;'; ...... ' ;'; ..... '; ";'''~ .... '":' ;'":"' ::'""' 14,7 1'55 · D. 5~ 17-8 PAGE 32'FILE 2 OR~ATION "* ...... ~''"" BOREHOSE ...... '" .... '''''''''''''''-'''-'-'''''-'''''-'-'''''-'''---' INDEX:* P DIP * D~,~. . · . 168 · 151 164 165 'i41 ,~ 4'" I4, · ' 83 ""~"><:.:::?: < 14.2 ...... 97 ' 14'2 ,,.:.~i!':;: 78 ~' .'~:;:'i;:'!..?,:',,,,,,",i, :,.. 1:ti4·.2, 2 4 ARCQ ALASKA INC.. D'. $. 17-8 -' ' -' .;';*====='===''='==='=*'='======''===''=''='='='''''''-''*'"INDEX DEPTH * DIP DIP ....'~ D~V, DEV. DIA~ 'DIAM "*-BEST -"- ~ :"'.": :.:.~--. '.. ~:.'." ~ ~. AZI,:: ':::::'~. -' - AZI' ;1.-3 ~:' :'.?.~..2,4 ::::'.~:: F='A ', 8386,0 '"... 2 · 4 ~ :': ...:: .~ ~ 8' ...' ';'..'..:.:.:'::~;~.: ':'1. 3 · 9 ..,~-: ~.i'2'. 5 4"':'~'"~"~?¥?':'A 0 :':'I 16 104 ' . ,3 ,D $. I7-~ * "~:' FOR;4ATIOi'~i '* ........... ,50REHOLE "'" ....... ":" :": ' *' (;IUAr,,: * '" *'''''='='''====''=~='''=''''=''=''=======-''='-===-.-~,-INDEX ~.-": -,,'- * DEPTH ~ "' DIP DIP * 'DEV'"'". ' DEV. DIAN "DIAM .... ~"BEST '~'.':':"~":"'"-' * " '. * ' .., AZI. '- ' ~,.~ . .AZt.,.-' :I-3 '":." ..":~"~..2~4'~~ -:*?';.mA' .-:,=:,$-...'~',:~:.~.~::': ***************************************************************************************** :.. * -8474,0 3,4 :'.:: '"?~:~24.: ....... '~"?::":~. ~ ,0...~::.;..: . ', ..... '~soo.o :~" '"~".2'::'':':'?':~ '.: ~: ": 8506.0 ", 3.1 ' ,15 ::.,:'::: :-; :~: !:3 i 2 'ARCO ALASKA INC. D. S. 17-9 ........ '-' " ..... ' PAGE 35-FIr;E- * ...... '~ '""F~::A~o.~' ~ '""""~'~'~"~"'?'"' .... '::~0~Z~O~.~ '""~:~" ....... ":~"~':~""-'?~""' * DEPTH '"*' " , ......... D~V D ~': D~~ ...."~':'"BEB~ ~..7~.'~ .'-'r... ' - ~ .... ';:/.-:': - :' ." ~ZX~'~ *. '"'-' -" ~AZ~, ................ '- ~ ..... , '-:':~S~8.0''~ -'2,~'"'"'" ........ "--~0 ....... ~'~'-' ..... 'i-S: ~ '. . ARCO ASASKA INC, 'D, S, 17-8 ~, ~6~4.o ~* '..8626,0 ~'*' '"8628.0 .o :%;. · '." ,0 :&~, 863 ,0 '..- "'=:::~' % 8644,0 ,,:,~... 8646,0 ~'"% "rSSS~" 0 5 * '.." 8658,'0 '?:~*' 8664.0 ~ ~:~"~8 6,7 O, ~ *' ~:'s~o "o · ~... ..,:~ * "8690,0 ~:~ * '8692. ARCO A6ASKA INC. DEPTH * DIP D . @?04.0. i.9 103 8706,0..,'i-~ :1.~8 .... :.'. ....~78 8710.0 · 1,6 ..$44 · ''8712.0 4.4 i68' · ., :B7'~4.0 ','.:::7,3 '.,.:"~ .$58 871'6.0 4.5 151: B7.18.011..'. .... 2,6':' . . B720.0 '0,8 8724.C 3,2 i23- · :'":::8726'i0':',i~':..:' ~. 'S.. 17-8 ' ' ' ' PAGE' 37'FILE IP * ....DEV, DEV. DIA~ >":'DIAM ~ BEST ZI,: .~. ~ ;AZI, :".:'!~:lm3'.":',:'Li::.:'.'::'~:2,4 ARCO AL~$KA INC. D.S. 17-8 ~ PAGE *' ..' -- $''''''''''''''''''~'''''''''''''''''''''''''''''''---~- . : :. . ~_.,. -.. ,. ... . - . DEPTH' ~ DIP DIP ""~ 'DEV',- '-DEV. ..... ,DIAX' DIAl4 ..... , . "8788.0 8790,O 8792.0"' '.:8794.0',-~':"~2':~ .8798~0. 8800.0 8804.0 ::8786 .0 '.' 81 3.6 "'" EO 227 D. S. 17-8 PAGE 39-FILE' '2"' ... ARCC ALASKA INC. D. S. [7-8 ' '"~ ' PAGE ._ . .... .. ,....,,....,,,,....,..,.,,,,.,.,.....,...,.,...,.........,.,,,, ****************************************************************************************** t"5:, 4 ARCO- ALASKA INC, D. .-"~" ' - ' '"", '-~;','..r~~z~;,~-.'''.-.~ ..... . , ,. -, ~ . ~ . ~' ,. · ., . , ~ ~ . ~ ~-. ..... DEPTH "*'"' DIP DIP ,-:V~ ~":;':..:.:.':.::~:.;,' ':'. -- ' - "" 'AZI,. -..~_ -,- :~ . :".:: 'aZ$,~ .~ ..... 71 ... <: : :2.4 -'..--*.".~,,A' :~ "'i~ * ..... 59'80.0 ~'* ,'?,:5 9 [~ 2 ::~:,.~ * '"":'"'~S9 ~ 4 996'.0 04,0 ~:.,~.?. ~"'6'0'[ 0, · '60i6'0 4' 0 ::'::: ,: ~.7 "~ '.:: ':': 1, !'!~ *"-: ~ '::.6 0 3'8,0 :..:'. :6,'5 ? ... : :.::: 13 ********************************** ... ....o4 :=~ ARCD ALASKA INC. D. $. i7'~ PAGE ~3'FISE ~'~..~ ~ ~'< ~' ......... ~' 'DEPTH ' ' DiP Di~ '~ "*' : DEV'. "D~V;' DIA~ m DIAM "' BE'T m' .-'<':. ~- 6050,0 5, :.;--.~;~:* '6052.0 8.5 '" 170 20.0 20 .... '"'"Z?,5:"' '~""~ 11,2 :.::;; 4, 2. 20 '~ LIBRARY TAPE CURVE SPECIFICATIONS Company Well Arco Alaska, Inc. Drill Site 17, Well 8 Prudhoe Bay Field County, State North Slope, Alaska Date 7/16/81 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CN .~ . ComPensated Neutron .... CN-mult. ispaced 60-0 GR ~.. Gamma Ray. CN-multispaced , 0-100 ..... 1007200 CCL Cas.in~. :Colla..r' L0cator .C_N_-multispac..ed 0-10 LS Long Spaced .... CN-muit.ispaced 0-1000 ..... .SS' ~. ~ Short Spaced ...... CN-multispaced 0-1000 .... '. · ,, , ,,, . , ,. , ,, ,,, · .... GR.' eCL ss LS CN FROR 8'~50"00"~ TO'' 9700.00 LEVEL SPACING 0.5000 D,S, ...17-.8 NORTH SLOPE PRUDHOE BAY D. ATtL..EVERY ............ : ............. 1 SAMP..L.E S ......................... GR 8350.00 99,61 8350,50 99,95 8351.00 105,77 83,51,',5.r0 .... 1,05,'95 8352,00 103.66 8352.50 10~o'7'8 83.53.00 i:03'92 8353.50 99.5~ 835~.00 97.06 835~,50 96,88 8355.00 8355.50 86'21 8356.00 7~.88 8356.50 7~.18 8357.00 73,~8 835?'50 72.15 8358.00 70.30 8358.50 69.03 82559.50 6~.96 8360,50 6~.,09 8361,00 63,61 8361.50 63.92 8362,00 63.63 8362.50 6~.13 8363.00 70.58 8363.50 75,38 836~.00 79.8~ 836~.50 81.2~ 8365.00 82,05 8365.50 82.93 8366.00 86.30 8366.50 86.31 8367.00 85.~9 8367,50 82,95 8368,'00 82.9~ 8368,50 83,5~ 8369.00 82.36 8369,5.0 80,12 8370,00 78,05 8370,50 77.68 8371.00 78.13 8371,50 77,8~ 8372.00 7~,2~ 8372,50 70,55 8373,00 68,56 8373.50 69.82 837~.00 73.86 837~,50 76,0~ 8375.00 77.~7 CCL SS LS CN 8.~5 0,00 185,63 ~3,97 8,~7 207.9! 185,67 ~,28 8.~9 211.73 182.95 ~5.86 8.,.~ 21~,65 179,88 ~7,~0 8.~9 215,29 176.18 ~7,51 8.~9 210,71 173,59 ~8,02 8,~9 201,96 171,1~ 8.~9 195'70 167,~8 ~7,67 8.~9 192,70 162,56 ~9,23 8,~9 192.93 16~,~- 51.85 8.~9 192.56 168.0~ 50.50 8,~6 191.17 167.7~ 8..~7 189,78 16~,~6 51,1~ 8.50 189.75 160.~8 52,66 8.50 189.~3 163,88 5~,22 8.50 1.88.~8 165.7~ 50,96 8.52 187.87 166.26 51,29 8-53 187,91 16~.~0 5M,73 8.5~ .18~;~'95 160,70 8.51 187,~3 158,88 52.56 8.50 18.6...~7 .160.20 5~.08 8.50 1.85.37 162,90 52,26 8.50 18~,16 166,71 51,66 8.50 189,03 168,52 52,65 8.50 190.17 169,~8 ~9,63 8.50 185,93 170,59 ~6,01 8.50 18~,31 169.77 ~5,36 8,~9 181,88 167,31 ~6,33 8.~7 180.36 165.~8 ~5,16 8.~7 180.~0 16~.08 8.~7 180,06 162.87 ~6,15 8.~7 ~79,10 16~.82 8.~7 177.89 16~,~3 8.~7 176.~7 163.22 ~.07 8o~7 176.61 16~.07 ~5.77 8,~7 175.01 158,99 ~6,16 8.~6 173.13 159.0~ 8,~6 171.17 163,85 ~,19 8,~5 169,81 165,08 ~2,78 8.~ ~69.{§ 16~.72 ~3,7! 8,~ 170,87 160,27 8.~5 17§,9~ ~60,62 ~7.38 8.~6 179.63 161.2~ ~6.50 8,~8 182.50 16~,71 ~5,85 8.~7 185.02 161,~5 53,86 8.~6 186.73 156,09 56,9~ 8,~5 18~,85 ~53o33 58,~6 8.~ 179.38 1§9.~3 8,~5 175.87 159,~7 ~9,36 8,~6 176.80 157,21 ~9,99 8.~8 175.20 155.59 ~8.12 PAGE 2 ARCO ALASKA INC, D,S, o17-8 NORTH SLOPE PRUDHOE BAY . .OAT, A~ E~ER¥ . ,1, ,S,A~,P~_ES GR .8~75,50 ...... 76,20 8376,00 71,55 8376,50 68,02 8~77,,0.0 66,70 8377,50 66.81 8578°00 7~o50 8378.'50 7~,52 8579,00 75,7~ 8579,50 76,07 858.0.,00 75,7~ 8580.50 75.09 8381,0.0 8~81,50 77,21 8582,00 80,15 8582,50 79,87 838,5°00 ,81,0~ 8385°50 85,59 838~,00 8~,58 8385,00 81,61 8585.50 81,02. 8386,.00 82.86 8586,50 85,~2 8587,00 82,9~ 8587,50 85.,0~ 8588,00 8.2,52 8388°50 82.02 8589,00 85,62 8589,50 8590,00 8~,99 8590.50 87,8~ 839Z.00 88,05 8591,50 88,79 8392°00 88,48 8392°50 8~,20 8393,00 79,48 8395°50 76°26 859~,00 70,52 839~,50 69o~7 8395,00 67.,86 8595,50 65,56 8396,00 65,08 8596.50 6~,8~ 8397,00 65,75 8397,50 66.67 8398,00 65,52 8398,50 $2,22 8599,00 58,75 8399,50 53.88 8~00,00 ~6.98 8400,50 ~4,17 CCL SS LS CN 8,~8 175,99 .158,87 ~6.93 8.~8 173.32 159,62 46,37 8.~9 172,97 159,~1 48.37 8.~8 17,1,5~ !58,20 ~6.17 8,4:6 169.73 156,75 ~5,58 8.~ 170,89 15~,48 8.~2 172,55 150,88 ~9,5I 8,~1 175,65 1~5,9~ 52,00 8,~Z 175,55 1~8°37 52,2~ 8,~1 177,51 152,58 51o77 8,58 175.89 159,0~ 50,69 8.~1 175"~0 161,98 8o~6 169.12 16~.0~ 8,~7 !66°67 160,66 8,~9 16~,2~ 156o15 ~7o06 8o~8 165,E8 156°18 47,87 8,~7 162.52 157,25 ~.7~ 8.~6 16.2:.03 158.83 ~3.00 8.~6 162o07 161.02 8,~,6 .,162.10 161.12 8,~6 161.~2 158.36 ~.98 8,~6 160.62 159o21 ~5.07 8.~6 160.23 162.59 .8,~5 160,27 165.99 40.79 8.~ 160.65 166.50 58.72 8,43 161°40 163.25 38.52 8.~2 162.16 158,33 ~0,02 8.~2 161.55 153.80 8,~2 160,54 150,~ ~5,9~ 8,39 162,28 1~8,71 ~9.65 8,39 162,57 1~7,75 51,29 8,~1 165,88 149,96 50.99 8,~3 166,~3 15~,18 50,77 8.$~ 171,50 159,15 ~8,90 8,06 178,29 162.52 ~9.~2 8.37 185.88 165.09 8.12 195.52 166.81 52.66 8.47 211.17 168,52 ~8.71 8,~6 216,18 178,05 ~5.69 8,~3 223,27 187,75 ~8,59 8,~ 225.81 187e~5 51,81 8,~7 25~,57 188.08 55°~0 8.~ 2~7,98 19~,89 5~.21 8,18 256.51 ~01.65 52.7~ 8.55 263.58 205,21 50~57 8,36 260,85 200,~0 51,25 8,17 2~8,2~ 195.67 52,50 8,~9 251,56 183,85 55,05 8,58 210,55 170,~5 ~9,79 PAGE ,5 ARCO ALASKA );NC. O.S, -17-8 NORTH SLOPE PRUDHOE BAY ) ) ) GR 6~0:1..50 45,68 8,2.0 84,02.00 52.52 8.34 B~03.00 84,03.50 ,8 Q ,O0 84,04..50 9~,08 84,05,00 98.60 84,05,50 98..82 84,06.00 98.58 84,06,50 98,63 84,.07-00 98,89 84,07.50 62,60 67,10 8.4'3. · 83,, 05 ....... C'CL ss LS 8.30 .... 164,,85 183.,31 159,92 170.Z2 154,.99 157,4,8 150.01 157.52 150,57 1.59,98 151,86 8.~5 161.31 153.15 8,~5 160,63 155,55 8,45 159,96 157.8a 8.4,5 159,22 156,07 8.44, 158,4.3 153.,~0 8.4,2 I57,79 153,94 8.41 ~57.83 3.53,97 84,08,00 99.3.0 84,08,50 98 . 70 84,09,00 96.94, 84,09.50 97,4,3 84,3.0,50 98,9~ 11.00 8.95 8.4.1 157,67 154,-4'8 8'4.3. 156.71 157.88 8.4,1 156,20 162,07 8.4,1 157,48 162,11 8, ~2 159 ,,.5~ .... 163,76 8.4,2 162,08 164,,18 8.42 16~,.96 160.5.3 84,12,00 96.54, 8.~2 84,12,50 92.33 8,4,3 8 13 ,0.0 87',51 . 8,4.5 84,14,.oo 90.52 8.4,3 8q1~,50 98.60 8,4,2 84,15.00 98.61 8.4,4, 84,~5.50 98,62 8.4,2 843.6,.00 98,~8 8,~1 8416.50 98,01 8.50 84,17.00 94,.51 8.4,3 8417.,50 91,57 8,43 84.18,50 9~.60 8.4,3 84,19.00 93.60 8.4,3 84,19,50 92.99 8,4,$ 84,20,00 91,86 8.4,3 84,20.50 89.32 8.4,3 84,21.00 86.95 8.43 84.21,50 86.4.6 8.4,3 84,.22.00 85.07 8,4,2 84,22,50 83.25 8.41 84,23.00 81.30 8.~0 84,23.50 81.13 8.4,0 84,24,.00 82.86 8.4,2 84.24,,50 85.68 8,4,4, 84,25,00 .90..30 8,4,6 84,25,50 91.99 8,48 84,26.00 92,20 8°4,7 169., 03 !60,19 172,93 162.74, 175,97 165,29 172,71 1.66,~6 168,10 165,09 164.,82 159,68 160,4,6 152,6! 16~.00 3.4.7.10 163,87 150,50 162,65 158,88 159,69 161.63 159.37 161.66 160,77 3.52,83 164,,15 166.09 159,4,7 167,80 158.33 168,72 160,84, 168.76 159.88 167,33 158,~6 1&5o70 160.67 164,.89 162.37 164,92 165,14, 164,.96 169,28 164,,28 170,29 I63,87 [65,57 166,05 167.3.1 163.09 1.67,15 159,81 167.19 166,92 CN 39.05 4.0.,86 4,3.85 4,3.23. ~1.56 ~,20 ~2,29 59~18 57.80 58 '! 8 ~0,51 ~6,92 ~9,97 ~8,~? 50.~ 5~,3~ 4a,96 4~,8~ ~?,~ ~9.Z5 ~7,~ ~4,79 ~.~0 ~.29 ~2.27 ~9.~5 ~6.05 ~7.55 38,S3 45,09 ~5.07 P AGE q* ....... ARC'O "ALA'SKA INC, p.S. -17-8 NORTH SLOPE PRUDHOE BAY 8~29,00 87.62 8~29,50 86.~8 8~30,00 8~,86 8~30.50 85.98 8~31,00 89,76 8~31.50 90.35 8~32o0.0 91.50 8~32.50 88.72 8~33.00 86.96 8~33.50 86,9.3 8~3~,00 8~.,!~ 8~!3~,50 81,32 8.~$5o00 80,60 8~36,00 85,93 8~.~6,.50 85,35 8~37,00 86,67 8~37.50 87,70 8~38o00 86.02 8~)8,50 8~39.00 81.12 8~39,50 83,62 6~0,00 8~0o50 83.78 8~Z.00 81.Z0 8~Z.50 8~2o00 80,22 8~2o50 75.72 8~3o50 71o25 8~,00 68,96 8~,50 69.3~ 8~5.00 69,96 8~5,50 68o19 8~6,00 8~6,50 67.65 8~7,00 67.99 8~?.50 66o85 8~8.00 65.25 8~8.50 6~,82 8~,00 CCL SS LS ..8.,.~5 165,96 167,55 8,~ 165,31 170,95 8:,~ 169-99 173,q3 8.VV 171.99 170.88 8.~V 172.65 167,92 8,~,~ 173,31 160,~2 8.~2 172.03 155.~6 8.~1 170.08 153.69 8..~ 16.8,13 155,37 8.~8 166.17 158.11 8.51 16V.22 163.18 8.52 1.62,26 163.~1 8.51 16~.55 158,~8 8.50 163,57 157,90 8,.~9 163,2~ 159,99 8.V8 162.VV 165.05 8.~6 ~61.9V 16V.00 8.~3 160.76 161,3~ .... 8..~2 .159o1~ 158.88 8,~ 157.76 156,~3 8,~6 156,80 15~.21 8,~9 156.20 15q,2~ 8.50 156.,2~ 15~.28 8.50 156,89 15q.32 8.50 158,60 15~,35 8,50 160,31 15~.63 8.51 161.78 151~18 8.52 163.25 1~7.38 8.53 16~.19 150.78 8.5~ 162.98 152,5~ 8.5~ 161.92 150.02 8.5~ 160.97 1~5.10 8.5~ 160.61 1~3.16 8,55 160,65 1~5,36 8,55 160.69 I~9,3~ 8.55 160,72 155.86 8.5~ 160.76 157.02 8,52 160,77 158,7~ 8,51 158,82 15~,53 8,51 156.89 152,91 8,51 156.93 152,95 8,51 158,00 15~,2~ 8.51 159.00 155,02 8,51 158.51 155.06 8.51 157.30 151.10 CN VO,06 39,00 37,80 38,~3 ~0.37 ~3,~0 ~6,79 ~6,89 ~8.20 ~6.25 ~.3,07 ~1.3~ ~3,25 V5,28 ~,2~ ~o0~ ~0,01 38,~8 ~8,3~ 38,55 ~0,05 ~0,83 ~0,e5 ~5.55 ~6,0~ ~8,36 51,18 ~,50 ~6,12 53.80 51.13 ~6o~ %5.60 %8.10 ~5.%8 %2.98 %1~61 ~0o60 %3~72 ~6.15 ~5o51 ) ECC NURBER 1,00 ~mmmmmmmmmmm~#mmmmmm~ ~mJmm..mmmmmmmmmmm..m~ 5I$ TAPE VERIFICATION LISTING LYP 009.H03 VERIFICATION LISTING PAGE m, REEL HEADER SERVICE NA~tE :SERVIC DATE :81/07/ 7 ORIGIN : REEL ~A~E :REEL ID CONTINUATIQN # :01 PREVIOUS REEL COMMENTS :REEL COMMENTS *~ TAPE HEADER SERVICE NAmE :SERVIC DATE :81107/ 7 ORIGIN :6174 TAPE NAME CONTINUATION ~ :01 PREVIOUS TAPE COM~EN?$ :TAPE COMMENTS ** FILE HEADER ~* FILE i~A~E :$ERVIC.O01 SERVICE NAME : VERSION # : DATE : MAXI~U~ LENGTH : 1024 FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS CN : ATLANTIC RICHFIELD WN : DRILL SITE 17-B FN : PRUDHOE BAY RANG: RA,..GE TOWN: SECT: SLCTION COUN: NORTH SLOPE S~AT: ALASKA CTRY: USA ~NE~ CO~ENTS PRES: DILOO1F RECORD TYPE 047 RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 020 065 000 000 015 065 000 000 015 065 000 000 005 065 000 000 008 065 000 000 007 065 000 000 015 065 000 000 010 065 000 000 005 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP 009.H03 VERIFICATION 5ISTING PAGE ** RECORO TYPE 047 ** COMMENTS ** DIL R~N ~ 2, LOGGED 26-JUN-81-81 CASING DRILLER 9.625 IN. g 8896 FT. CAS I,~b LOGGER 8894 FLUIO IN TME HOLE = LIG~O DENS VISC PH FLUID LOSS R~ 0 ~EAS TEMP, RMF " '? RMC " " R~ ~ ~MT 9.9 11.5 6.6 1.46 1.2i ~ 66 F. 1.69 @ F. .5B ~ ~63 F. PDRUSI?¥ ~TRIX = SANDSTONE ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SiZE REPR CODE ENTRY B 4 73 60 9 4 ~5 .I!N 0 1 66 0 DATUS SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNIT API API AP1 AP1 FILE SIZE PROCESS SAMPLE REPR ID ORDER # ~OG TYPE CLASS MOD NO, LEVEL CODE DEP~ F~ 0 0 0 0 0 4 0 1 68 LVP 009.H03 VERIFICATION LISTING PAGE 3 SP FDN MV 0 ILM FU~ OHMM 0 SFLU FUN OHM~ 0 ILD FUN OH~ 0 GR FUN GAPI 0 DT IS8 U$/F 0 RHOB NUC G/C3 0 DRHO MUC/'' G/C3 0 FCNb ~()C 0 NRAT MUC 0 NPHI ~UC ~ PU 0 GR ~bC-" GAPI 0 NCNb MUC 0 CALI MUC / IN 0 ! 0 0 0 4 0 0 0 0 0 4 0 0 0 0 0 4 0 12 46 0 0 4 0 31 32 0 0 4 0 52 32 0 0 4 0 35 1 0 0 4 0 44 0 0 0 4 0 34 93 0 0 4 0 42 I 0 0 4 0 68 2 0 0 4 0 31 32 0 0 4 0 34 92 0 0 4 0 28 3 0 0 4 0 DEBT 9720,500 SP ILD 4.0~7 GR DRHU -999,250 FCNL GR -999,250~ NCNb DEPT 9700,000 SP ILD 5.730 GR DRHO 0.023~ FCNL GR 129,250' NCNb DEBT 9600,000 SP ILD 3,~4~ GR DRHO 0,00 ~ FCNL GR 64,250' NCNb DEBT 9500,000 SB ILO 1,659 GR DRHO 0.005~ FCNL GR .~ 22,1~1f NCNb DEBT 9400,000 SP ILD i.534 GR DRHO -0,001~ FCNL 'GR 22,281- NCNb DEBT 9300,000 ILD 3,924 GR DRHO 0.027- GR 22.438- NCNb DEBT 9200.000 SP ILD 14 2~ GR OR 59,500~ NCNb DEBT (~0~,000 SP ILO 7.613~ GR -15 93 '999 -999 -26 93 876 2580 -51 59 1 -72. 26. 1356. 3346. -68 ~396. 3468, -75, 25. 2238' 4004, -49 35 1~65 3378 -49 42 ,969 ,500 .250 ,250 ,969 ,500 .000 ,000 .625 ,688 000 :000 625 375 000 000 625 984 000 000 063 922 000 000 312 :875 ,000 .OOO .625 ,469 DT NRAT CALI DT NRAT CALI DT NRAT CALl DT CALl DT NRA~ CALI DT NRAT CAbI CALl DT 6,199 SFLU 74,563/ R'HOB '999,250 NPMI '999,250~ 8,367. SFLU 74,563/ REOB 2,902 NPHI 8,758~ 3,354 SFbU 81,750/' RHOB 1,741 ~ SFLU 90,75~' RHOB 2,557 NPHI 8,867c I SFLU 2,559 NPHI 8.891~ 4,266/-SFLU 76,000 RHOB 1,855 NPHI 8,875~- . RBOB. 2.~32 NPHI 8; 75~ 6,016 SFLU 8B,563~ 1 68 ! 68 ! 68 1 68 ! 68 1 68 ! 68 1 68 ! 68 ! 68 1 68 1 68 8.367 -999.250 -999.250 21.203 2.619" 32.129 6.938 2 441- 21:143 2.834 2,203 26.807 3.016 2.2t7 26.807 7.973 2.412 16,260 18.000 2 352 23;438 i8,453 2,336 DR HO GR DEPT DRHO DEPT DRMO GR DEPT DRHO DEPY GR DEPT ILL DRHO GR DEPT DRHO DEP~ DRHO GR DEPT DRHO GR DEPT DRHO DEPT ILD GR DEPT IbD 009.H03 VERIFICATION LISTING 0.005~ FCNL 50.563 ~ NCNb 9000,000 SP 9 96~ GR 0:00 FCNL 68,750~ NCNb 1444,000 3094.000 -30.14! 63 031 ?o:ooo 3162.000 ~900,000 SP ..... !0.398 1,328 GR ' 68,625 -0,011~''' FCNL 303,250 75,500~ NCNb 1306,000 )(800. 000 SP 2 963~ GR -999:25o'~ FCNL -999.250 NCNb ~{700.000 SP 3,352 GR -999,250 ~ FCNL -999,250 NCNb 8bO0.O00 SP 2,832 GR -999,250j FCNL -999.250 NCNb 8500,000 SP 2 248 GR -999:250/ FCNL -999,250 NCNb ~400,000 SP 1,923 GR -999,250w FCNL -999.250 ~CNL ){300.000 SP 1,218 GR -999,250/ FCNL -999,250 NCNb 8200.000 SP 1,774 GR -999,250' FCNL -999,250 NCNb 8100.000 SP I .271 GR 999 250 FCNL '-'999:250 NCNb 8000.000 SP 2,152 GR -16,833 182,125 -999,250 -999,250 -13.247 169.500 -999,250 -999,250 -13,942 134.750 -999.250 -999,250 -13.296 124.688 999,2250 7-999. 50 -14.775 174,375 -999,250 -999.250 6 91,5 -999.250 -999,250 -!6.915 101.438 '999'250 '999.250 -17.578 63.344 -999.250-999. 250 -19.261 94,250 NRAT CALI IbM DT NRAT CALI IbM DT NRAT CALl IbM DT NRAT CALl IbM DT NRAT CALf IbM DT NRAT CALI IL~ DT MRAT CALl IbM DT CALI I/,M DT NRAT CALI IbM DT NRAT CALl IbM DT NRAT CALl · 15 NPHI 9 047,~RFLU 81!188 HOB 2 514 NPHI g.133~ 1 597.,~SFLU 116:000 RHOB 4,609 NPHI 17,391~ 3,410 SFLU -999,250./ RHOB '999'%250 NPHI '999,250/ .21~ SFLU -99 .25 ? RHOB -999.250 NPHI -999,250~ 2 96t, SFbU -999:250~ RHOB -999,250 NPHI -999.25C~ 2,420 SFLU -999.250/ RHOB -99 1,934 SFLU -999,250 RHOB -999,250 NPHI -999.250 1.359 SFLU -999,250 RHOB -999,250 NPHI -999,250 1.811 SFLU -999.250 RHOB -999.250 NPHI -999.250 1,434 SFbU '999.250 RHOB '999,250 NPHI '999.250 2.197 SFbU -999,250 RHOB PAGE 4 20.703 10.766 2.363 25.830 2.250 1,445 57.031 12.719 -999,250 -999,250 4,902 '999,250 '999,250 4,309 '999,250 '999,250 3.631 -999.250 -999.250 2,713 -999,250 -999.250 2 240 -999,250 1,957 -.999.250 999.250 2 850 :999!250 999 250 2,336 -999.250 LVP 009.H03 VERIFICATION LISTING PAGE 5 DRhO DEPT DRHO DEPT DRHO DEPT DRHO GR DEPT ILD DRHO GR DEPT ILD DRHO GR DEPT DRHO GR D£PT DRHD GR DEPT DRHO GR DEPT DRHO DEPT ILD DRH0 GR DEPT M999.250 FCNL -999.250 NCNb 7900.000 1.560 GR -999.250 FCNL -999,250 NCNL 7~00.000 SP 1.734 GR -999.250 FCNL -999,250 NCNb 7700.000 SP 1.736 GR -999.250 -999,250 NCNb 7600.000 1,904 OR -999.250 FCNL -999,250 NCNb 7500.000 SP 2 412 -999~250 FCNL -999'250 NCNL 7400,000 1.360 '999.250 FCNb -999.250 NCNb 7300.000 SP 2 875 GR -999:250 FCNL -999.250 NCNb 7200.000 SP 2.377 GR -999,250 FCNL -999.250 NCNb 7100.000 SP 3.166 GR -999,250 FCNL -999,250 NCNb 7000,000 SP 3.629 GR -999.250 -999.250 NCNb 6900,000 3.145 GR -999.25 -999.25 -20.53 86.37 -999.25-999.25 -22.50 78.00 -999.25-999,25 -25.04 78.00 -999,25-999.25 -26.08 81.31 -999.25-999.25 -28,26 94.37 -999.25-999,25 -26.56 116.56 -999.25 -999.25 -25.53 110,12 -999.25 -999.25 -24.49 99.81 -999.25-999.25 -26.97 107.00 -999.25 -999.25 -25.57 88.12 '99~.25 -99 .25 -48.29 86.00 NRAT CALI IbM DT NRAT CALI IbM DT NRAT CALI IbM DT NRAT CALl IbM DT NRAT CALl DT NRAT CALI IbM DT NRAT CALI IbM DT NRAT CALI DT NRAT CALI ILM DT NRAT CALI DT NRAT CALI DY -999.250 -999.250 1.607 -999.250 -999.250 -999.250 1 789 -999:250 -999,250 -999,250 -9 ~.797 9 .250 -999.250 -999.250 1.963 -999.250 -999,250 -999.250 2.455 -999,250 -999.250 -999.250 1.29i -999,250 -999 250 2,941 -999.250 -999.250 -999,250 ~,432 -99 ,250 -999.250 -999°250 3.145 -999.250 -999,250 -999.250 3.975 -999.250 '999,250 -999.250 3.236 -999.250 NPHI SFLU RHOB NPHI fiFLU RHOB NPHI SFLU RHOB NPHI SFLU RHOB NPHI SFbU RHOB NPHI SFbU RHOB MPH! SFLU RHOB NPHI SFLU RHOB NPHI SFLU RHOB NPHI SFbU RHOB NPHI SFLU RHOS -999,250 I 816 -999:250 -999.250 1.775 -999250 1.816 -999.250 -999,250 .99~"078 .250 -999,250 2,797 '999.250 '999.250 1.264 '999.250 '999.250 3.363 -999,250 -999,250 2 5O -999.250 3.205 -999.250 -999.250 4.074 -999,250 -999,250 4.605 -999,250 5¥P 009.H03 VERIFICATION LISTING DRHO -999.250 FCNL GR -999.250 NCNb DEPT 6800.000 SP IbD 4.180 GR DRHO -999.250. FCNL .GR -999.250 NCNb DEPT 6700.000 ILD 2.902 DRHO -999.250 FCNb GR -999.250 NCNb DEPT 6600,000 SP IbD 4 7 GR DRHO -999:~0 FCNb GR -999.250 NCNb DEPT 6500.000 SP IbD 3.199 GR DRHO -999.250 FCNL GR -999.250 NCNb DEPT 6400.000 SP ILD i 903 GR DRHO -999:250 FCNb GR -999,250 NCNb DEPT 6300.000 SP ILD 2.521 GR DRHO -999.250 FCNE GR -999,250 NCNb DEPT 5200.000 SP ILD 1.532 GR DRMO -999.250 FCNL GR -999.250 NCNb DEPT 6100.000 SP IbD 3.059 GR DRHO -999,250 FCNb GR -999.250 NCNb DEPT 6000.000 SP IbD 2,507 GR DRMO -999.250 FCNb GR -999,250 NCNb DEPT 5900.000 SP ILD i .O41 GR DRH0 -999.250 FCNL GR -999.250 NCNb DEPT 5800.000 SP IbD 1.35i GR -999.250 -999.250 -39.339 44.@13 -999.250-999.250 63. 4 -999,250 '999.250 -43.603 96.750 -999.250-999.250 -84.920 56,8!3 -999.250-999.250 -105.723 46.063 -999.250-999.250 -92.527 44.594 '999 ~50 -102.027 57.844 '999.250 -999.250 -75.277 52,219 -999.250-999.250 -89.098 54.813 -999.250-999.250 -42,580 32.438 '999 250 '999:250 -30.333 39,656 NRAT CALI IbM DT NRAT CALI IbM DT NRAT CALI IbM DT NRAT CAbI DT NRAT CAbI IbM DT NRAT CALI IbM DT NRAT CALI IbM DT NRAT CAGI IbM DT NRAT CALI IbM DT NRAT CAbI NRAT CALl IbM DT :99g.250 999.250 4.1B4 -999.250 -999.250 -999,250 3.158 -999.250 -999,250 -999.250 4.316 -999.250 -999.250 -999,250 3.777 -999.250 -999,250 '999,250 2,574 -999.250 -999.250 -999,250 3.244 -999,250 -999.250 -999.250 1.985 999,250 -999.25O 4.195 -999.250 -999.250 -999.250 3.330 -999,250 -999,250 -g99,250 1,342 -999.250 -999,250 -999.250 i.819 -999.250 NPHI SFLU RHOB NPHI SFbU RHOB NPHI RHOB NPHI SFLU RHOB NPHI SFbU RHOB NPHI SFLU RHOB NPHI SFbU RHOB NPHI SFbU RHOB NPHI SFLU RHOB NPHI SFDU RHOB SFLU RHOB PAGE -999.250 3,125 -999,250 -999,250 3.814 -999,250 -99g.250 3,998 999.250 5.953 -999,250 -999.250 6.4B0 -999.250 -999.250 5.508 -999,250 -999,250 5.004 -999.250 -999.250 6.348 -999,250 -999.250 6,602 -999.250 -999.250 5,301 -999,250 -999,250 5.477 -999.250 bVP 009,H03 VERIFICATION LISTING DRHO -999.250 FCNb GR -999.250 NCNb DEPT 5700.000 IbD 2,982 GR DRHO -999.250 FCNb GR -999,250 NCNb DEPT 5600,000 ILO 1.910 DRHO -999,250 FCNb GR -999.250 NCNb DEPT 5500.000 IbD i 173 DRHO -999: 250 GR -999.250 DEPT 5400.000 IbD 2.424 DRHO -999.250 GR -999.250 DEPT 5300.000 IbD i.552 DRMO -999,250 GR -999.250 DEPT 5200.000 ILD 4,719 DRHO -999.250 GR -999.250 DEPT 5100.000 IbD 2 766 DRH(] -999~250 GR -999.250 DEPT 5000.000 ILD 2.301 DRHO -999.250 GR -999.250 DEPT 4900,000 IbD 1.241 DRHO -999.250 GR -999.250 DEPT 4800.000 ILD 1.723 DRHO -999,250 GR -999.250 DEPT 4700.000 IbD 5.000 SP GR FCNb NCNb SP GR FCNb NCNb SP FCNb NCNb SP GR FCN5 NCNb SP GR FCNL NCNb SP GR FCNL NCNb SP GR FCNb NCNb SP GR FCNL NCNb SP GR -999.250 -999.250 37.304 57,t25 '999.250 -999.250 -10.027 52.688 '999.250 '999.250 -35,750 45.281 '999.250 '999.250 5.400 68.625 '999.250 -999,250 -37,424 47.188 -999,250-999,250 21,20! 69.875 -999.250 -999,250 12,638 56.844 '999,250 -999.250 -999.250 -999.250 -48.237 30.203 -999.250-999,250 -38,161 32~875 '999i250 -999 250 26.864 75.125 NRAT CALI IbM DT NRAT CALl IbM DT NRAT CALI IbM DT NRAT CALI IbM DT NRAT CAbI IbM DT NRAT CAbI IbM DT NRAT CAbI IbM DT NRAT CAbI IbM DT NRAT CALI DT NRAT CALI DT NRAT CAbI -999.250 -999.250 2,951 -999.250 -999.250 -999.250 2,189 -999.250 -999,250 -999.250 i.442 999'250 -999.250 2 54 -999.250 =999,250 ,984 -99 .250 -999.250 -999.250 4.414 -999'250 -999,250 -999'250 3.092 -999.250 -999.250 -999,250 2.600 -999,250 -999,250 -999,250 1.569 -999,250 -999.250 -999,250 2,182 -999.250 -999 250 -999~250 4,414 -999,250 NPHI SFbU RHOB $FLU R~OB NPHI RHOB NPHI SFbU RHOB NPHI SFbU RHOB NPHI SFbU RHOB NPHI SFLU RHOB NPHI SFbU RHOB NPHI SFLU RMOB NPHI SFLU RHOB NPHI SFLU RHOB PAGE -999.250 3,018 :999,250 999.250 3.070 :999,250 999,250 3.061 2999,250 999.250 2.609 -999.250 -999.250 3.205 -999.250 -999,250 3.828 -999.250 -999.250 3.523 :999 250 2.900 -999,250 -999.250 4.105 -999.250 -999.250 4.395 -999.250 -999,250 4.793 -999.250 5VP 009.H03 V£RIFICATION LISTING DRHO DEPT DRMO GR DEPT DRHO DRHO DEPT DRHO DEPT DRHO DEPT DRHO GR DEPT DRSO GR DEPT DRHO DEPT DRHO DEPT DRHO DEPT -999 -999 ,250 FCN5 .250 NCNb 4600,000 SP 3.369 GR -999.250 FCNL -999.250 NCNL 4500,000 SP 4.500 GR 999,250 FCN5 -'999.250 NCNb 4400,000 SP 4.387 GR -999,250 FCNL -999,250 NCNb 4300.000 SP 4.633 GR -999.250 FCNL -999,250 NCNb 4200.000 SP 4.596 GR -999.250 FCNb -999.250 NCNb 4100. 4. -999 -999: 4000 -999, -999, 3900. 7, -999, -999, 3800. 8. -999. -999. 3700. 5. -999. -999, 3600. 5. O0 16 5O 50 O0 98 5O 5O O0 59 50 50 O0 56 5O 50 O0 8:] 5O 5O O0 43 SP GR FCNL NCNb SP FCN5 NCNb SP GR FCNL NCNb SP FCN5 NCNb SP FCN5 NCNb SP GR -999 -999 5 53 -999 -999 23 62 -999 -gg9 0 58 -999 -999 19 62 -999 -999 43 -999 -999 21 72 -999 -999 3 62 -999 -999 10 64 -999 -999 -0 60 -999 -999 11 '999 -999 -20 58 .250 .2§0 .294 .688 .250 ,250 :650 125 ,250 .250 ,322 .750 '250 .250 .35 .250 .250 ,674 .719 .250 .250 .232 .188 o 0 .653 .094 .250 .250 .085 .938 .250 .250 .572 .563 .250 .250 ,604 .938 ,250 .250 .426 ,125 NRAT CALI IbM DT NRAT CADI IbM DT NRAT CALl IbM DT NRAT CAbI IbM DT NRAT CALI DT NRAT CALI 15M DT NRAT CALI DT N~AT CAbI DT NRAT CALl DT NRAT CALI DT NRAT CALl DT -999,250 -999'250 3 · 129 -999,250 -999.250 -999,250 4,277 -999,250 -999.250 -999.250 4.875 9 9,250 -999,250 4,719 -999'250 -999,250 -999.250 5.309 -999.250 -999.250 -999.250 4,207 -999.250 -999.250 -999.250 7.781 -999,250 -999.250 -999.250 6,867 -999,250 -999.250 -999.250 8.305 -999.250 -999,250 -999.250 5.215 -999.250 -999,250 -999.250 5.605 -999.250 N P PI I RHOB NPHI SFbU RHOB NPHI $FbU RHOB N_HI RHOB NPHI RHOB NPHI SFLU RHOB NPHI SFbU RHOB NPHI SFbU RHOB NPHI SFLU RHOB NPHI SFLU RHOB SFLU RHOB PAGE -999,250 5.016 -999.250 -999.250 4.0~2 -999.250 -999.250 5.805 :999,250 999.250 6,016 '999.250 '999.250 7.406 -999.250 -999.250 4.723 -999.250 -999,250 8.484 -999,250 -999,250 6.141 -999.250 -999.250 8.719 -999.250 -999.250 6,512 -999,250 '999.250 7.633 -999.250 LVP 009,H03 VERIFICATION DRHO -999.250 FCNL GR -999,250 NCNb DEPT 3500.000 SP ILl) 4.738 GR DRHO -999.250 FCNL GR -999,250 NCNb DEPT 3400.000 SP ILD 3.156 GR DRHO 2999,250 FCNh GR 999,250 NCNb D£PT 3300,000 SP ILO 2.758 GR DRHO -999,250 FCNL GR -999,250 NCNb DEPT 3200,000 ILD 2.160 DRO0 -999,250 FCNL GR -999,250 NCNb DEPT 3i00.000 SP ILD 1,248 GR DRHO -999.250 FCNL GR -999,250 NCNb DEPT 3000,000 SP ILD 2,670 GR DRHO -999.250 FCNL GR -999.250 NCNb DEPT 2900.000 5P ILD 1.422 GR DRHO -999.250 FCNL GR -999.250 NCNb DEPT 2800,000 SP ILD 2.508 GR DRHO -999.250 FCNL GR -999.250 NCNb DEP? 2700,000 SP ILD 1.366 GR DRHO -999,250 FCNL GR -999,250 NCNb DEPT 2602,500 8P ILD 2000.000 GR DRHO -999.250 FCNh GR -999,250 NCNL ** FIbE TRAILER 5ISTING -gg9 -999 15 -999 -999 6 62 2999 999 7 77 -999 -999 - 2 -999 -999 -42 -999 -999 -34 47 -999-999 -43 27 -999-999 ,250 ,250 .164 ,500 .250 ,250 .329 .781 ,250 .250 .150 625 .250 728 : oo .250 .250 .848 ,688 ,250 ,250 .924 .500 .250 ,250 .728 .563 .250 ,250 15,862 72,125 -999.250 -999,250 -37. 40, -999.-999, -21. 26. '999. -999. 982 625 250 250 799 859 25O 250 NRAT CALI DT NRAT CALI DT NRA~ CALI IbM DT NRAT CALI IbM DT NRAT CALI DT NRAT CALl IbM DT NRAT CALI IbM DT NRAT CALI DT NRAT CALI IbM DT NRAT CALI DT NRAT CALI -999.250 -999.250 4.402 -999,250 -999.250 -999.250 3.117 -999,250 -999,250 -999.250 2.8i4 -999.250 -999.250 -999.250 .398 -99 .250 -999.250 -999,250 1.424 -999.250 -999.250 -999,250 2.891 -999.250 -999,250 -999.250 1.679 -999.250 -999.250 -999.250 ,99~ '219 .250 -999.250 -999.250 1.583 -999.250 -999.250 -999.250 2000,000 -999.250 '999 250 -909:250 NPHI SFIaU RHOB NPHI RHOB SFSU RHOB NPHI SFLU RHOB NPHI BFLU RHOB NPHI SFbU RHOB NPHI SFbU NPHI SFLU RHOB NPHI RHOB NPHI RHOB NPHI PAGE -999.250 4.875 -999.250 -999.250 3.791 -999.250 -999.250 3.432 -999.250 -999.250 3.686 -999.250 -999.250 1,896 :999.250 999.250 3.814 -999.250 -999.250 3,598 -999.~50 -999. 50 2,312 -999.250 -999.250 3.133 -999.250 -999.250 2000,000 -999.250 -999.2~0 LVP 009.H03 VERIFICATION DISTING PAGE lO FIDE NAME :SERVIC.001 SERVICE NAME : VERSION # : DATE : MAXIM~ LENGTH : 1024 FILE tYPE : NEXT FILE NA~E ** TAPE TRAiDER *~ SERVICE NAME :SERVIC DATE :81/07/ 7 ORIGIN :6174 TAPE NAME : CONTINUATION # :0! NEXT TAPE NAME : CO~ME~TS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE :81/07/ 7 ORIGIN : REEL ~ME :REEL ID CONTINJATfON ~ :01 NEXT REEL NAME COMMENTS :REED COMMENTS EOF
