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199-029
STATE OF ALASKA 1 FEB 2 0 2018 •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSA °'2,.eC 1. Operations Performed ' Abandon 0 Plug Perforations m Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Pull Plug-Set Plug 11 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 199-029 3. Address: P.O.Box 196612 Anchorage, Development IJ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20503-01-00 7. Property Designation(Lease Number): ADL 0028303 8. Well Name and Number: PBU 15-21A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 14720 feet Plugs measured 11107 feet true vertical 8987 feet Junk measured 11538/13045 feet Effective Depth: measured 11107 feet Packer measured 10734 feet true vertical 8297 feet Packer true vertical 7974 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 29-109 29-109 1530 520 Surface 2999 13-3/8" 27-3026 27-2678 5380 2670 Intermediate 10810 9-5/8" 25-10835 25-8062 6870/8150/6870 4760/5080/4760 Liner 847 7" 10517-11364 7783-8514 8160 7020 Liner 2968 4-1/2" 10791-13760 8024-8773 8430 7500 Liner 330 3-1/2"x2-7/8" 13164-14717 8781-8987 10160/10530 10870/11160 Perforation Depth: Measured depth: 10999-11030 feet True vertical depth: 8204-8230 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10789 23-8022 Packers and SSSV(type,measured and 4-1/2"BAKER S-3 PERM PACKER 10734 7974 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: N L w.-, _ j , SCANNED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 32875 60 1440 1313 Subsequent to operation: Shut-In 1240 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil PI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Meixueiro,Paulina Contact Name: Meixueiro,Paulina Authorized Title: Production Engineer- Contact Email: paulina.meixueiro@bp.com Authorized Signature: QGZ.4..,9-....., � x.^n. ,, rI Date: Q 2' fct I ig Contact Phone: +1 907 564 5971 1/ ✓ Form 10-404 Revised 04/2017 Y ' /i R B D M S Lk, F,` , 2 mit Original Only 'Age( • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary February 19, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Pulling of WFD ISO Plug, Setting of a Cast Iron Bridge Plug and Addition of Perforations for Well PBU 15-21A, PTD # 199-029. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 1111/ C) /. s Y g O E O 2 / in \ b / / I, 2 z r < \ 0I _/ � \ co U) U) = / � e 6 » & / 0 Z ® f � ® 1 @o \ ' % I < \ < / / ƒ � U & L \ . ET- Ca U) ƒ E \ El \ f / a k ^ ± O / 0 § ¥ / / \ ƒ / f < w \ _ . / m o ƒ $ O -. - 0 E I \ \ / 7.C ,-- D - / d \ \ E \ _- LI 12 j \ \ CD > C 2 % O EL ® k b o 0 D IX OD O R = & O 0_- ® = t ® > / ® O 9..-_ © - n \ U < I ± = R \ ee ± � R - � � � _1 / i5 OC was \ / SE � � 3 / _ / \ / \ \ (L) '5 / / \ \ / H / \ p � � � � 2 °- N ° bcp co 3: � \ 4-1 03 _1 \ �R � \ cl® � � � / � # mG / ƒ / \ L. / m + * E 2 * f 1 -I / O = ± o * 0. A a ± * L _ 2 O * & „ W o I E ® _ƒ a C ƒ 0 Ce \ v- / L / © cK \ M / » 5r29' (DE- - 6 / / L/ f \ E % / = > / / \ / OC / / % \ / < > \ / / \ O 06 0_ \ -- N - \ / ■ i < E c & t ± o c \ ± b E EE -- x a 2 c_ o R * / o = © k 0 \ / R \ / § / / \ / / / < / k \ a) C) \ \ E 2 \ / \ / \/ ° _ _ f ® \ = o oli o 00II / � / < / \ � \ E - = \ 7 / \ mf ƒ � / / f ƒ / � \ / --0 .cc \ / \ -- f \ \ / / / � - Z 6@ # 2 0@ R 0 i \ / \ - ® O LL Z h O \ = oil _ W 'r = f f W / ® O O \ ® ± ± < a ® 2 R N > O �� k\ Zoo) / < < w * / < / f * * --I E2 - \ f / / f w \ 2 < 0 ° E '.- 2 k / 2 [ \ \ \ 7 f : I c ± : : I ± : : E O : : c I O ± 2 ± 2 : 6 E o c 5 e O L < c o m c c y 8 \ \ \ \ m o C 9 N ^ N N ammo 2 \ CO / - = I N ¥ ,- ,- & N 0 < TRE L � • 15-21A om NANOTES: RE NOT ANGLE POSSIBLE V4B_6.tEAD= GRAY GEN 1 ACTUATOR= BAKER C RSH-(3)IBP RUBBERS(01130/04) KB.a.EV= 67' I BF ELE/= ? 20"CONO, H 110' / II 2085' —I4-1/2"FES X NP,D=3.813" KOP= 1300' 94#,H-40, Max Angle= 95°@ 13108' D=19.124" GAS LFT MANDRELS Datum MD= 14371' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD= 8800'SS 1 4926 3771 51 M10.01G DONE RK 16 01/31/11 'I 2 8449 6116 46 MMG DONE RK 16 12120/15 13-3/8"CSG,72#,N-80 BTRS,D=12.347" —1 3029' y 3 10425 7703 29 NIG MY RK 0 11/20/10 TOP OF 7"LMR —1 10520' - J 10520')-j 9-5/8"X 7"B.O.T.TRACK w/LNR HGR,D=?? Minimum ID =2.370" @ 13449' 0 X 10736' —17"X 4-1/2"BKR S-3 PKR,D=3.875" 3-1/2" X 2-7/8" XO ' 10769' --i4-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.6#,L-80 IBT M, H 10791' \ .0152 bpf,D=3.958" 10791' H 4-112"WLEG,D=3.958" TOP OF 4-112"LNR —� 10793' 10793' — MR 17"X 5"ZXP LTOP PKR,D=5.250" , 9-5/8"CSG,47#,L-80/S00-95 BTIRS, D-8.681" — 10838' I 10807' H7"X 5"WAC Ltd HGR D=3.938" I I L 11107' ,—{4-112"WFD CMP(02/01/18)] 7'LAR,29#,L-80 BTC,.0371 bpf,ID=6.184" H —11377 _ , —FISH: BI H:1/2 RBE2 HJT LEFT DH(070/8/17) I 7" WFSTOCK 11377' ' 7"MLLOUT WIDOW(15-21A) 11365'-11377' I 13-1/2*LNR 9.2#,L-80 STL,.0087 bpf,D=2.972' j--1 13449' I TOP OF 2-7/8"LW --I 13614' 4-1/2"LNR 12.61/,L-80 BT-M 13761' 0 ►Z� 13164' -4-1/2"UPPER KB STRADDLE PKR,D=2.370' .0152 bpf,D=3.958" g I 13449' -3-1/2'X0 TO 2-718",D=2.370" 13484' -4-1/2"KB LOWER STRADDLE PKR,13=2.370" PERFORATION SUMMARY _ -_---- -_ RE=LOG:SWS MEM'CNUGR/CCL ON 06/20/99 C CI -3-1/2'F11LU MS WU CG,D=2.380' ANGLE AT TOP PERF:31"@ 10999' 13514' -3-1/2" DELOY SLV,D=3.00" Note:Refer to Production DB for historical perf data 13518' -3-1/"X 2-7/8"XO,D=2.380" SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10999-11030 0 02/01/18 13551' -4-1/2"RA TAG 2-7/8" 6 11120-11125 C 07/17/17 3-3/8" 6 11225-11230 C 05/02/17 : :� 2-7/8" 6 11991-12214 C 10/03/03 2-7/8' 6 12259-12284 C 10/03/03 2-7/8' 4 12470-12700 C 07/30/01 , 2-7/8" 4 12730-12790 C 07/30/01 2-7/8" 4 12860-12950 C 07/30/01 ' 2-7/8" 6 12990-13015 C 03/11/08 ' 2-7/8' 6 13075-13100 C 03/11/08 2-7/8" 2 13230-13430 C 07/30/01 ' 2" 6 14345-14355 C 03/11/08 ' 2" 12 14355-14380 C 03/11/08 2' 4 14408-14507 C 06/22/99 2" 4 14543-14558 C 06/22/99 ••ll PBTD — 14714' 2' 4 14608-14638 C 06/22/99 � •4 L2-7/8"LNR,6.5#,L-80 FL4S,.0058 bpf,D=2.441' — 14718' DATE REV BY COMMENTS DATE REV BY COMM94TS PRIJDHDE BAY UNIT 01/04181 PKR 176 ORIGINAL COMPLETION 08/09/17 BSE/JMD PULL®FISWCORFECTH)ISO DEPTH WELL: 15-21A 06/06/99 N9ES SIDETRACI03)(15-21A) 09/13/17 PVJMD CORRECTION TO ISO DEPTH(07/17/17) PERIvIfT No:'1990290 06/21/99 N9F'S CTD HORIZ EXT(2-7/8"UVEB) 01/30/18 ZV/JMD PULLED ISO PLUG(01/29/18) API No: 50-029-20503-01 12/21/10 NORDIC 1 CTD PATCH(4-112"LM) 02/05/18 BTN/JMD SET CEP&ADPERFS(02/01/18) SEC 22,711N,R14E,70'FW..&383'FAL 06/03/11 TL/PJC PERF CORRECTION 07/24/17 NXW/JMC SET ISO PLUG/ADPERFSJFlSH BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approves,Program �❑/ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ,�e t I So O/C N1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 199-029 ` 3. Address: P.O.Box 196612 Anchorage, Development d Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20503-01-00 7. Property Designation(Lease Number): ADL 0028303 8. Well Name and Number: PBU 15-21A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 14720 feet Plugs measured 11150 feet true vertical 8987 feet Junk measured 11538/13045 feet SEP ((►►V 6 2017 Effective Depth: measured 11150 feet Packer measured 10734 feet true vertical 8334 feet Packer true vertical 7974 feet A CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2999 13-3/8"72#L-80 27-3026 27-2678 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet 1 No Y Q Q L017, s�Nt4E True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10789 23-8022 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 17 32100 1 1300 1658 Subsequent to operation: Shut-In 1100 1150 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Odom,Kristine Contact Name: Odom,Kristine Authorized Title: DS$6&13 PE Contact Email: Kristine.Odomi bp.com Authorized Signature: e �J'��/ Date: CI Co 20 Contact Phone: (907)564-5365 mr.Form 10-404 Revised 04/2017 Vfi 1 '° 1a /1-7,e/007 I / 07 RBDR11S k-V SEP 7 2017 Submit Original Only • • RECEIVED SEP 0 6 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 6, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations for Well 15-21A, PTD # 199-029. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • d O O O V tg C) CC) ON- tOr- COCC) f0OONM Cc) O O O e- O CM 0 CO OD CO 00 OD OD O 000MN "4- OD QD (0N- N N Ns Is O Co 00 CO 00 00 CO i i i i i 00 el OD QD CD Is UD CA O CO N CO Is C` M N N N T- Ns 1s O Is Ns Ns N Ns C` Ns O co O CO UD O O CA Sr Ns CD NI- co�- 0) 00 — C'MCO VI 0 t 4 I i I i i I I I I i I i 4.11 Q� Qr CL) f� — O M M Cn Ns CO N (A CO Ch � � NNNO000CY) M (Y) N = aCD O O O O O O C) ODO0000000OD CO iA 1tJ _II QJOOJJJJJ y N # OD 4t J p 8 8 N *k N A CA • 600 _TT 600 _ CV - 00 0 cq --- a '-- T- � � N CD lC) C D 4 c [7:2 N 4 CD . r CD In Q0 to vr o UD CD CO C 000 0 0 0 7 0 V N 0 a) N O) O N O J v- UJ W W =o ct www' ) UCCCCcCV 0 u_ CC CC CC CC CC Z Z W W W W W W W W m Q H I- Z Z Z Z Z D (..) 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N a' LL Cn to to to LO to to to to to to to to to LO to to [00_ 0_ 0_ 0 -100W a Q Q m m W U. cn cn a cc • 0 Packers and SSV's Attachment PBU 15-21A SW Name Type MD TVD Depscription 15-21A TBG PACKER 10734.48 7974.28 4-1/2" BAKER S-3 PERM PACKER 15-21A PACKER 10791.33 8023.85 5" Baker ZXP Top Packer 15-21A PACKER 13164 8781.32 3-1/2" Baker 45 KB Packer 15-21A PACKER 13484 8776.18 3-1/2" Baker 45 KB Packer • • Ws 2 ce _ v in aa)) 0 "d N O '� a) N 0 w o O 2 Cl) .- m N J * n .- J M u) + N C • V (O 0 Q Z -1E O Eo J .2 (n r _ a) mm 0 z 0 wN O J a) , O Q * m 1- FY F- ON 0 w W Z �� d ceQ ai 0 O' -1 D oW nQ 0 Q < 020 Wwa_ N M F- N U J m_ cc- - I- a Z � O to 0 2 - '61o O caQ 0- ezi C4 Z a a 0 0 i- W .0 O Q �� . 0 w FT a W O 0 w Q a Co 0 0 - 0 0 2 o a� Z 0 0 W Z cl N N- O ZN Jv ~ Ea Z a) LL cfl J pa NC M ++ Ce D • 0 0 a M d• •C w LL-U 0 O 0 N i 2 = 2 (AJ gW 20 = w Lna (n _ J 000 E a a F- a' LL0 00 a mw w < 0u r Z o • a -1 w O� _ O a w O J W a O �-O -J O (n O a 25 2 N J 0 M 0 L L < J O W j EOw OLL o0 2S Q .� w (nco a aa - ,n ow F- 0 E0 - a I0ctI- m = F- 0 ODQ w o � Q 2a co co- 2 f F- m ' O (j 6O I- cc0ce .N co O n_" I- 00 2w ON J ~ Lu II I.10- b w � 0 * 2 t0 m Om 4. w � � � QN � � Q � QO OV = mow � v, a JF D CCF- 4, J 0 o J (nOcLaw 3 W Q _ in 0 > < - = W * r-- u- J = O ENa � N , N w OWmJ O C 4t di Z J J D E 7 ceDoi F- QN- � W 0 � 01- ca aowr- o p = er -10 nN a �+ QW x Q 1- � Z " Qo � , co 0 OwF- 2 'c4 coZo Ya � 2 _, 0 � F- o �2Z .- Ooj ,_ wd ? 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N. / \ / 2 # q r c N. @ m q \ 03 03 D= GRAY G�, 15-21A N� N HOWN=@ 11734' o s ACTUATOR= BAKER C RSH-(3)IBP RUBBERS(01130/04) KB.R_EV= 6T BF.E.EV= ? 20"COND, H 110' IJ 2085' —14-1/2"HES X NP,D=3.813" KOP= 1300' 94#,1-40, Max Angie= 95"@ 13108' ID=19.124" GAS LFT MANDRELS Dratum ND= 14371' ST NO TVD DEV TYPE VLV LATCH FORT DATE Datum TV D= 8800'SS 1 4926 3771 51 INvIG DOME RK 16 01/31/11 2 8449 6116 46 MMG DOME RK 16 12/20/15 13-3/8"CSG,72#,N-80 BTRS,ID=12.347" H 3029' 3 10425 7703 29 MMG DMY RK 0 11/20/10 TOP OF T LNR H 10520' r— 10520' -19-5/8"X 7"B.O.T.TACK w/LPR HGR,D= 7? Minimum ID =2.370" @ 13449' g10736' BKR3-1/2" X 2-7/8" XO • 10769' H4-1/2"FES X tom?D=3.813" 4-1/2"TBG,12.6#,L-80 IT-ML H 10791' .0152 bpf,ID=3.958" 10791' —I41/2"WLEG,D=3.958" ITOP OF 4-112"LNR H 10793' 10793' —17"X 5"ZXP LNR TOP PKR,D=5.250' 9-5/8"CSG,47#,L-801500-95 BTRS, D=8.681" — 10838' 10807' —17"X 5"HMC LNR HGR ID=3.938" I A .__ 1-. 5u...4NR.__..__RD= 1 J 11173' -I4-1/2"ISO PLUG(07/18/17)CORRECTED ISO 7"LNC 29#,L-80 BTC,.0371 bpf,ID=6.184" . I —11377 �_ PLUG DEPTH 08/08/17 7" WHPSTOCK H 11377' 1., J--{FISH:1/2 ELEMENT LEFT'01-1(070/8/17) , ' 7"MLLOUT WINDOW(15-21A) 11365'-11377' I 3-1/2"LNC 9.2#,L-80 STL,.0087 bpf,ID=2.972" H 13449' I TOP OF 2-7/8"LNR H 13514' ! 13164' -41/2"UPPER KB STRADDLE PKR,D=2.370" CA 0 41/2"LNR 12.6#,L-80 6T-N( H 13761' 13449' -3-1/2"XO TO 2-7/8",D=2.370" .0152 bpf,13=3.958" I 13484' -4-1/2"KB LOWER STRADDLE PKR,D=2.370" PERFORATION SUMAARY ►�� ►moi / 13494' -3-1/2"FULU MS WLEG,D=2.380" REF LOG:SWS MEMVCNJGR/CCL ON 06/20/99 13514' -3-1/2" DEPLOY SLV,D=3.00" ANGLE AT TOP PERE:31"@ 11120' 13518' -3-1/"X 2-7/8"XO,D=2.380" Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 13551' -4-1/2"RA TAG 2-7/8" 6 11120-11125 0 7/17/2017 D — 3-3/8" 6 11225-11230 C 05/02/17 J 2-7/8" 6 11991-12214 C 10/03/03 2-7/8" 6 12259-12284 C 10/03/03 2-7/8" 4 12470-12700 C 07/30/01 ' 2-7/8" 4 12730-12790 C 07/30/01 2-7/8" 4 12860-12950 C 07/30/01 t 2-7/8" 6 12990-13015 C 03/11/08 ' 2-7/8" 6 13075-13100 C 03/11/08 2-7/8" 2 13230-13430 C 07/30/01 ' 2" 6 14345-14355 C 03/11/08 ' 2" 12 14355-14380 C 03/11/08 2" 4 14408-14507 C 06/22/99 2" 4 14543-14558 C 06/22/99 '•'417P610 14714' • 2" 4 14608-14638 C 06/22/99 k•••4 2-7/8"LNR,6.5#,L-80 FL4S, 0058 bpf D=2.441" I--{ 14718' _._] DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 01/04181 PKR 176 ORIGINAL COMPLETION 08/09/17 BSE/JM)1FU.LED FISWCORRECTED ISO DEPTH W8 L: 15-21A 06/06/99 N9E5 SIDETRACKH)(15-21A) FERMI- 06/21/99 N9B5 CTD HORIZ EXT(2-7/8"LM) API No: 50-029-20503-01 12/21/10 NORDIC 1 CTD PATCH(4-1/2"LNR) SEC 22,T11 N,R14E,70'FWL&383'FN. 06/03/11 TU PJC PERF CORRECTION 07/24/17 NXW/JM:SET ISO PLUG/ADPB2FS/FISH BP Exploration(Alaska) STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMIS N - REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations H Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: /3Or7/uG 121 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: / / 1'99-029 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20503-01-00 7. Property Designation(Lease Number): ADL 0028303 8. Well Name and Number: PBU 15-21A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 14720 feet Plugs measured 11338 feet 0 true vertical 8987 feet Junk measured 13045 feet JUN 2 2017 Effective Depth: measured 11338 feet Packer measured 10734 feet true vertical 8492 feet Packer true vertical 7974.28 feet Of"+C() Casing: Length: Size: MD: ND: Burst: AOGCC Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2999 13-3/8"72#L-80 27-3026 27-2678 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10789 23-8022 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 477 38977 7 1100 1140 Subsequent to operation: 712 58546 0 1280 478 14.Attachments:(required per 20 MC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Odom,Kristine Contact Name: Odom,Kristine Authorized Title: D 06&13 PE Contact Email: Kristine.Odom@bp.com Authorized Signature: i ,,7/ 4 / Date: \ / 20‘M Contact Phone: (907)564-5365 Form 10-404 Revised 04/2017 V`7'L e.H 113- , RB D MS l�- 11 N - 2017 /1,6-/47,� Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUN 02 2017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Well Operations Summary June 1, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of Plug for Gas Shut-Off and Adding of Perforations for Well 15-21A, PTD # 199-029. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • a) .o O O O O O O c O CC N r CO cc I�0 Cfl N O r 0 (fl r O CC) l() U Z. 0 0 0 0 0 0 0 x 0 i CO CO I` LO r O CO N CO In C)) CO r CO r d' O CO r CO CO CO CO CO CO O CO CO CO N d' CO r• O r 0) O CO CO N CO r r O LC) C) O rN N- CO CO0000 CO 11111111I I- , 00 co co CO CAr• LUCT) OOONI's M NNNrr• r• ON• N r Nr• 0000 4-0C Cn I ct O N O) a aa00 O co M 'Cr O M r r r r r r o o }.11.0+ C71 11) r• r CO < N co-) r• CO z4-"" N r ()) r CO N N N CO 0 0 0 M N r r r r _ r .Q• MH W O O a' pap O O 00 O 00 � co o O O J 00 J ap Lc) co V (n a 00d� (OSI r - U ON v- M Cf) 00 C7 N N 4 d r CD 0 r Cf) O f� co 'Cr CO C 00 CA 00 O r cc C)) N r• J N (A to 00 N 0 W W W coo QQQ ca 0 N UWWW co D U 0 u_ [ r c c o Z Z W W W W W W pp O H H H Z Z_ Z_ 0 owZZZJ _lJH • a> H m = O N- ao Lo O CO N N ,- O Nt O M a N O O O O M (0 CO '- 6) V' CO Lo a0 a1 O 6) O 6) O d) a0 f- In to CO N V' CO O W co M co co M a) co a) a) a) a) M M M 0 F a O ▪ V r N M N V' M CO N V' M V r CA CO m 6) M O CO Lo r Lo W CO r N r O O V' a N- N O M 6) N V' aO Cfl Cfl r 6) O O O 0 d O 6) O O O O CA a0 N- V' Lo Lo ao M Cfl W 0 co ti a) a) N- a) N- ti N- co a) co co 6) O > O a) a) a) a) a) a) a) a) co 0o a) co ao a) a) O 2 a 0w Z 0 o O w 0 o Y Y mO V V 0 0 O Lo O O Lo O O N- a) a0 O O w ¢ ¢0 0 W W W U) 4-+ a N N N N N 67 O r M M M Lo Lo M ¢ ¢ ¢ w a a Z_ C • r N N N N N M M CM V V V V V V U_ _ Z 0 _0 J W W -� r . . . . . . r r r r Z Q 0 0 _10 _1 2 0 0 0 W Z `C W O Z Q 222O ) c) u¢) c) cQ) � r Q Ni a g C r Lo r 6) O O C) C) Lo O Lo Lo C) ao M Co O ) m N M N V' N M 6) O N M M M M COO c▪ o m r r N N N N N c) M V' V' V' N . . . . . . La ; a20ww wconvww) 0- d O 0 c O u- W W (n (n fn (n (n (n fn W (n W W W roaMaO_ MM (I . aaaaaaa a 0 0 d a 2 co N- N- N- N- ti N- N- N- N- N- N- N- N- N 0 — r r r r r r r r r r r r r r 0 ° C O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N N N NNN N Z1-1. W < 11 w OLL LNNNN NNNNNN N N N N N Z a 0 LLIW W W W a "4-4- 1- ,q ,1—:1-4-4-1M-1- V. ¢ 0 J F- J J D J 0 a a 0 m 0 m W J J ^.l ¢ O W W ¢ ¢ a cn E L ;nLi. cn a a a) E 2 « « « « « « « ‹ r r r r r r r r r . . . . . N N N N N N N N N N N N N N N N i i a a o O a N a LL Lo L� Lo Lo Lo Lo Ln Ln Ln Ln Lo Lo Lo Lo Lo m a g a U J O C1 w a . . . . . r r r r r r r r r r ¢ ¢ m m LL LL (I) Cl) a • ! Packers and SSV's Attachment PBU 15-21A SW Name Type MD TVD Depscription 15-21A TBG PACKER 10734.48 7974.28 4-1/2" BAKER S-3 PERM PACKER 15-21A PACKER 10791.33 8023.85 5" Baker ZXP Top Packer II 40 a) a) II m o O (2 5 M 0 Z 0 w N- _ - _1 J z N. m d ci. J (0 ch O ❑ w u g v � � _ � i u O 000 & a- 'xz wO) m 0 co 0 O x ❑ rn • 8 - - cam' • 0i- 4v � � ❑ co UD < � � 1-.' a o • N U Z N N H d II U O Ln 2 a ;4- ,... c ❑ ON c c _ co @ .4 J H 0 to 0 j E o � ❑ d) M Q' o Z W go x Q > . rl o `- C°tri > E O C7 U i X p Q > o H LL d d C E Q - LuOw C= WN L _ II d 48- OZ 5 O to (n H>' WQ D0 � - WO opF- Ou Hco mOw ❑ N 04:( 0) .-2 ,6 J = c\14= - JN 70 NO 7❑ W2 _ _ _ O II mw !-.L 6 N CL> av0 ° 1 ' LL ro 1— MO LL Q = zwZHui0 °to o2 4U0 0 * ❑ - Z -I < wz m - O ) zww > wwoI- IIOD ac) < * n ' ~ 0 m 0 t m ob 0 -1YUZ � Ck z 9 N 0 - ❑ t- cnc0 0 d L0 f- >� N. ❑ 2 II 0 II O. m > D -) z J -N O J -O d O N l - cc * = O _' c O LL_ 0 O Q 0 M• O H W co N - a) LL A Q - J J O U w Q c) m ° O N ❑W W O Q H Q O —1 ,17 › ZO WaDc/� cn2WQ ? N ' Z >- � HH1O .> 03 N 0 wF- UOUOC� WOUww - o � -INwQow � - 2 < < Q H 22 W Lr- D ❑ Q ,- l 2 w N w' W 0 W a . ci Ow ^ > D ---- >. ZN °w. ❑W ❑ OO II ❑ 0 W W ° U Q (\i — ❑ D aDW - O w HU cn - = Z -Z2cTic?5 � w 2Qcn ° O °Oc(o � U -1 � - ;---- --- 0 nHW _ _iH =_ ❑ EtWO � � 0N WIHL. QZ � � � � OW WaLL -IJ ° 0 � W > > Q N Q cncCWn « 4 * Udj > ZRccnndd < > LLT.. I`- ncUn o w H Q N. r- r . N. a� N ON c O Cl) N NN- fes- CO m - N N N N H v v in in 0 Q TREE= . FARC 0 S NOTES: WELL ANGLE>70"@ 11734'..s yve.11-EAD= GRAY GEN I 15-21A ORIGINAL WELLBORE NOT SHOWN*'*POSSIBLE ACTUATOR= BAKER C RSH-(3)IBP RUBBERS(01/30/04) KB.BEV= 67' I I BF.(iEV= ' 20"CX)ND, H 110' I I 2085' -14-1/2"I-ES X NP,D=3.813" KOP- 1300' 94#,H-40, ArMx Angle= 95"@ 13108' D=19.124" GAS LFT MANDRELS Datum U)= 14371' ST MO TVD r OEV TYPE VLV LATCH FORT DATE DtatumTVD= 8800'SS 1 4926 3771 51 MMG DOME RK 16 01/31/11 2 8449 6116 46 MMG DOME RK 16 12/20/15 13-3/8"CSG,72#,N-80 BTRS,ID=12.347" -{ 3029' 3 10425 7703 29 MMG DMY R 1< 0 11/20/10 TOP OF 7"UV -i 10520' _ L 10520' H9-5/8"X 7"B.O.T.TEBACK w/LIR MGR,D=?? Minimum ID =2.370" @ 13449' 10736' —{7"X4 112"BKRS 3 FKR 1D=3.875" 3-1/2" X 2-7/8" XO S 1 10769' -14-1/2"HES X NF',D=3.813" 4-1/2"TBG,12.6#,L-80 BT--M, H 10791' INi .0152 bpf,ID=3.958" 10791' —14-1/2"WLEG,D=1958" � 10793' —I 7"X 5"ZXP LNR TOP PKR D=5.250" TOP OF 4-1/2"LN? —I 10793' _`� 9-5/8"CSG,47#,L-80/S00-95 BIBS, D=8.681" -1 10838' A _, 10807' 7"X 5"HMC LNR HGR,D=3.938' 7"UR,29#,L-80 BTC,.0371 bpf,D=6.184" H -11377 11338' 4 1/2"ISO PLUG w/JUNK CATCHER (04/27/17) 7" WHIPSTOCK - 11377' 7"IVLLOUT WINDOW(15-21A) 11365'-11377' 3-1/2"LNC 9.2#,L-80 STL,.0087 bpf,D=2.977 H 13449' TOP OF 2-7/8"LM -j 13514' 4-1/2"LM, 12.6#,L-80 BT-A4 -I 13761' z g 13164' -4 1/2"U'PH2 KB STRALE 13=2.370" .'2J 13449' -3 1/2"X0 TO 2-7/8",D DD=2.370" .0152 bpf,ID=3.958" !� 13484' -4-1/2'KB LOWER STRADDLE R<R,13=2.370" PERFORATION SUMMARYC'' 13494' -3-1/2"FULU MS VVLEG,D=2.380" REF LOG:SWS A43V CMJGRFCCL ON 06/20/99 13514' -3 112" DHLOY SLV,13=3.00" ANGLE AT TOP FERF:32'@ 11225' - 13518' -3-ir X 2-7/8"XO,ID=2.380" Note:Refer to Production DB for historical perf data SCE SPF INTERVAL Opn/Sqz DATE ■ 13551' -4-1/2"RA TAG 3-3/8" 6 11225-11230 0 05/02/17 2-7/8" 6 11991-12214 C 10/03/03 2-7/8" 6 12259-12284 C 10/03/03 2-7/8" 4 12470-12700 C 07/30/01 2-7/8" 4 12730-12790 C 07/30/01 ' 2-7/8" 4 12860-12950 C 07/30/01 ' 2-7/8" 6 12990-13015 C 03/11/08 2-7/8" 6 13075-13100 C 03/11/08 ' 2-7/8" 2 13230-13430 C 07/30/01 I 2" 6 14345-14355 C 03/11/08 2" 12 14355-14380 C 03/11/08 ' 2" 4 14408-14507 C 06/22/99 2" 4 14543-14558 C 06/22/99 2" 4 14608- 14638 C 06/22/99 ,V4 PBTD -I 14714' 2-7/8"LAR 6.5#,L-80 FL4S,.0058 bpf,D=2.441" - 14718' DATE REV BY COMfvENfTS DATE REV BY COIVNIENTS FRIDHOE BAY UNIT 01/04181 PKR 176 ORIGINAL COMPLETION 12/22/15 RCT/JMD GLV CJO(12/20/15) WELL: 15-21A 06/06199 N9ES SIDETRACKED(15-21A) 05/04/17 RCB/JM)SET ISO PLUG w/JUNK CATCFER PERMIT No:'1990290 06/21/99 N9ES CTD HORIZ EXT(2-7/8"LPM) 05/04/17 KFS/JM)ADPERFS(05/02/17) AR No: 50-029-20503-01 12121/10 NORCIC 1 CTD PATCH(4-1/2"LAIR) SEC 22,T11N,R14E,70'FW_&383'FML - 02/13/11 ?/AGR GLV C/O(01/31/11) 06/03/11 TU PJC FERF CORRECTION BP Exploration(Alaska) • Wit IS--Zi - 6 l lC1z`1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> '�'9 lZiIS Sent: Thursday, December 24, 2015 5:44 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Meixueiro, Paulina;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers,Jessica; Dickerman, Eric; Pettus, Whitney; Munk, Corey; Regg, James B (DOA) Subject: OPERABLE: Producer 15-21A (PTD #1990290)TIFL Passed All, Producer 15-21A(PTD#1990290) passed a TIFL on December 24, 2015 following gas lift valve work. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • A SSSV is not required Please call with any questions or concerns. Thank you, Kevin Parks BP Alaska Well Integrity Coordinator SEP 1 5 2D16 Ig I Wet Organization scht4t4 Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, December 06, 2015 1:27 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismo Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EO ; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Meixueiro, Paulina; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engi• -er; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; ' erman, Eric; Pettus, Whitney; Munk, Corey; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UPDATE December 06, 2015: UNDER EVALUATION: 'roducer 15-21A (PTD #1990290) Sustained Inner Annulus Casing Pressure over MOASP All, Producer 15-21A(PTD#1990290) was foun• o have sustained inner annulus casing pressure over MOASP on December 05, 2015. The pressures were confirmed • be TBG/IA/OA= 2350/2030/600 psi. The well will remain Under Evaluation 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Sunday, December 06, 2015 1:27 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL;AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Meixueiro, Paulina; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Munk, Corey; Regg, James B (DOA) Subject: UPDATE December 06, 2015: UNDER EVALUATION: Producer 15-21A (PTD #1990290) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer 15-21A (PTD 1990290) TIO Plot.docx All, Producer 15-21A (PTD#1990290)was found to have sustained inner annulus casing pressure over MOASP on December 05, 2015. The pressures were confirmed to be TBG/IA/OA= 2350/2030/600 psi. The well will remain Under Evaluation until diagnostics have been completed. If operationally possible, please place the well on production to manage inner annulus pressure until wireline intervention can be performed. Plan Forward: 1. Downhole Diagnostics: Bleed inner annulus to 200 psi—DONE 12/05/15 2. Operations: If possible, place well on production to manage inner annulus pressure 3. Slickline: Set tubing tail plug 4. Fullbore: MIT-T&CMIT-TxIA 5. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. Thank you, SCANNED MAY 1 1 2016 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, December 04, 2015 7:54 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, 1 • RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Meixueiro, Paulina Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Munk, Corey Subject: UNDER EVALUATION: Producer 15-21A (PTD #1990290) Inner Annulus Repressurization All, Producer 15-21A (PTD#1990290) passed a TIFL on November 24, 2015 but continues to show signs of inner annulus repressurization. The well has been reclassified as Under Evaluation for further diagnostics. As MOASP was not exceeded, no notification to the AOGCC was necessary. If operationally possible,the well should be brought online to help maintain inner annulus pressure below MOASP. Plan Forward: 1. Slickline: Set tubing tail plug 2. Fullbore: MIT-T&CMIT-TxIA 3. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GA/ il?ga• n,tatoi WIC Office: 907.659.5102 2 Producer 15-21A(PTD 1990290) TIO Plot December 05, 2015 Well 15, 1 IV-The 2. 00A 1 • 000A :u / -_.__.- --.._-- - --T - . STATE OF ALASKA ALASK•IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERA O NS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Set tubing patch for GSO 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. IN Development ❑ Exploratory - 199 - 029 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 ■ 50 - 029 - 20503 - 01 - 00 7. Property Designation: 8. Well Name and Number: ADL 028306 & 028303 ". PBU 15 - 21A 9. Field / Pool(s): ■ Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 14720 feet Plugs (measured) None feet true vertical 8987 feet Junk (measured) None Effective depth: measured 14714 feet Packer: (measured) 10736' feet true vertical 8986 feet Packer: (true vertical) 7976 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 3030' 13 -3/8" 3030' 2680' 4930 2670 Intermediate Production 10838' 9-5/8" 10838' 8064' 6870 4760 Liner 845' 7" 10520' - 11365' 7786' - 8515' 8160 7020 Liner 2968' 4-1/2" 10793' - 13761' 8025' - 8773' 8430 7500 Liner 1204' 2 -7/8" 13514' - 14718' 8776' - 8987' 10570 11160 Perforation Depth: Measured Depth: 11991' - 14638' True Vertical Depth: 8793' - 8968' Tubing (size, grade, measured and true vertical depth): 4-112 " 12 L -80 10791' MD 8024' TVD 3 -1/2 ", 9.2# 13494' MD 8776' TVD Packers and SSSV (type, measured and true vertical depth): 7" x 4 BKR S - packer 10736' MD 7976' TVD 45 "KB" Upper Straddle packer 13164' MD 8781' TVD 45 "KB" Lower Straddle packer 13479' MD 8776' TVD 11. Stimulation or cement squeeze summary: ����,�� Intervals treated (measured): y.� I' ED Treatment description including volumes used and final pressure: € p 8 � U MAR 0 3 2.011 Alaska Oil & Gas Cons. Commission 12. Representative Daily Average Production or Injection Data Ant otage Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 2500 20 Subsequent to operation: 800 1256 86 2500 800 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory • IR Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ 9 ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Eli Vazquez, 564-5918 N/A Printed Name Elizabeth Barker Title Drilling Technologist Prepared By Name/Number Signature ire,// � Phone 564 -5674 Date 3 /� // Elizabeth Barker, 564-5674 Form 10-404 Revised 10/20 D MS MAR 0 3 2011 3 .y.1( Submit Original Only 4 M% • • 15-21A Well History (Pre Rig Workover) Date Summary 11/19/2010 T /I /0= 2100/2150/600 temp= si Assist S/L Load IA [CTD Prep ] Rigged up to IA and pumped 5 bbls 60/40 meth, 475 bbls crude down IA to load 11/19/2010 DRIFT BELOW X- NIPPLE @ 10770 W/3.805" CENT /S.BLR TO 10900' SLM (BAILER EMPTY), SET 4 -1/2" X- CATCHER SUB @ 10765' SLM /10770' MD PULL ST.2 RK -OGLV @ 8447 SLM/8449' MD, PULL ST.1 RK -LGLV @ 4925' SLM/4926' MD SET ST.1 RK -DGLV @ 4925' SLM/4926' MD, CURRENTLY LOADING IA WITH CRUDE 11/20/2010 SET ST #2 RK -DGLV @ 8447' SLM/8449' MD. PULL EMPTY X -LOCK C/S @ 10765' SLM /10770' MD 11/21/2010 (MIT IA_3000 psi = PASSED) Pumped 17.4 bbls of Crude to reach test pressure. Initial Test pressures were 2320/3000/580. IA lost 120 psi in the 1st 15 min and 60 psi in the second 15 min for a total loss of 180 psi in the 30 min test. Tbg psi and OAP remained unchanged throughout the test. Bled down IAP to 1000 psi. Pad became too drifted in with snow to continue working. Job postponed. Rig down and Stage unit on edge of pad. 11/23/2010 MIT -OA to 2000 psi (Pre CTD) Unable to perform job due to need for now removal. 11/24/2010 MIT -OA to 2000 psi PASSED Bleed OA psi down to 200 psi (all gas) Pumped 12 bbls of 65 *f crude down OA to reach test pressure. OA lost 70 psi in first 15 min and 30 psi in second 15 min for a total loss of 100 psi in 30 min test. Bleed back approxamatly 4 bbls. FWHP 2300/800/220 Swab, Wing, SSV closed, Master open, IA and OA open to guages 11/26/2010 PPPOT -T: Stung into test port (0 psi). Functioned LDS, all moved freely ( .75 "). Unable to pump through void, single port. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 12/1/2010 CTU #9 1.75" Scope: Venturi cleanout run /drift for tbg patch (pre -rig) MIRU Coil, MU BOT venturi TS. RIH & tag btm @ 13463' CTM, make 8 venturi cycles on btm, flag pipe, POOH. Had no recovery. RIH w/ 3.70" dummy KB packer drift to tag at 13510' CTM. POH. FP wellbore to 2000' w/ McOH. 12/2/2010 CTU #9 w/ 1.75" CT Scope: Venturri /drift for CTD KB packer Fin POH. Thaw surface lines. RDMO to E -05 12/6/2010 Torqued all tree flanges above master valve to API specifications. (see log for details) Pressure tested down on master valve to 300 psi low and 3500 psi high for 5 minutes each. (passed) (charted test are in TRP folder) 12/6/2010 RIG UP SWCP #4516 & STANDBY FOR SURFACE EQUIPMENT. 12/6/2010 WHPs (eval IA & OA psi) Pre -rig. All tree valves closed upon arrival. DSO aware of valve positions. 12/7/2010 SET 4 -1/2" XX -PLUG IN SVLN @ 2064' SLM /2085' MD. LRS PERFORMS PASSING MIT -T TO 3000 #. 12/7/2010 Bleed IAP & OAP to 0 psi (pre -rig). Integral on IA. Replaced bad OA gauge. IAP & OAP decreased 10 psi overnight. IA FL @ surface. OA FL near surface. Bled IAP from 240 psi to 0 psi in 1.25 hrs (slugging). Bled OAP from 170 psi to 40 psi in 1.5 hrs, fluid to surface after 10 minutes. SI for end of shift. During OA bleed IAP increased from 0 psi to 20 psi. SI and monitor for 30 min. OAP increased 20 psi. 12/9/2010 Verified Barriers. Rigged up lubricator and tested to 300 psi low and 3500 psi high. (passed) Set 5" GRAY K BPV @ 115" w/ 1 -2' ext. Torqued THA x MSTR flange to API specifications using Camerons torque wrench. (details in log) Set GRAY Test Dart on top of BPV. Shell tested tree against Test Dart to 300 psi low and 5000 psi high. (passed)(charted test results in TRP folder) Pulled GRAY Test Dart. Rigged up lubricator and tested to 300 psi low and 3500 psi high. (passed) Pulled 5" GRAY K BPV. Reinstalled tree cap and tested to 500 psi.(passed) 12/9/2010 CURRENTLY RIH W/ 4 -1/2" EQ. PRONG TO 4 -1/2" XX PLUG @ 2,085' MD. 12/10/2010 EQUALIZED & PULLED 4 -1/2" XX PLUG BODY FROM 2,065' SLM / 2,085' MD. 12/13/2010 Bleed IA & OA to 0 psi. No AL. IA & OA FL's near surface. Bled OAP from 90 psi to 0 psi in 5.5 hrs (gas /fluid). Bled IAP from 150 psi to 0 psi in 4 hrs (gas /fluid). Monitored both 15 mins. IAP increased 5 psi, OAP increased 10 psi. ** Note: Wellhouse & flowline have been removed. Scaffold & ladder to swab platform still remains. No hydraulics to SSV. IA integral installed. Page 1 of 2 • • 15 -21A Well History (Pre Rig Workover) Date Summary 12/13/2010 Test barriers for companion removal, tie in crew to remove and bolt up companion flange, and test to 5,000 psi, testing as follows , master x wing low 300 psi , pass. high 3500 psi , pass. ssv x wing 300 psi , pass. high 3500 psi , pass. 12/15/2010 Pressure tested companion flange through tree cap x ssv x wing. low 300 psi ( pass) high 5,000 psi ( pass ) 12/16/2010 Load TBG & FP (CTD Prep) Pumped 5 bbls neat meth, 294 bbls 110* 1% KCL and 2 bbls neat meth down TBG. Pumped 40 bbls DSL down TBG for FP. Bleed IAP & OAP to 0 psi. 12/17/2010 (PRE CTD DRY HOLE TREE) Tested barrier to 500 psi against SSV to confirm barriers. Rigged up CIW lubricator with 5 1/8 Gray K BPV #615. Pressure tested lubricator to 500 psi for 5 min.(PASS) Then 3500 psi for 15 min.(PASS) Set 5 1/8 Gray BPV at 125 ". Rigged down lubricator. Removed upper tree and installed dry hole tree. Torqued master to dry hole tree to 1281 ft lbs. Pressure tested dry hole tree to 500 psi for 5 min.(PASS) Then 5000 psi for 15 min.(PASS). Page 2 of 2 , . TREE = FMC SAFETY WS: WELL ANGLE> 70° @ 11734' *** WELLHEAD = ;RAY GENII W 1 5-2/ A ORI GI NAMELLBO RE NOT SHOWN*** POSSIBLE CTUATOR = BAKER C KB. ELEV = 67' BF. ELEV = ? 20" CONDUCTOR, —1 110' ...... .. KOP = 1300' 94# H.,40 rk H-40 ) • 1 2085' 1 FISH - (3) IBP RUBBERS (01130/04) 4-1/2" HES X NIP, ID = 3,813" H [Max Angle = )5 @ 13108 ID= 19.124" GAS LIFT MANDRELS Datum MD = 14371 4 ST 1 MD TVD DEV TYPE' VLV LATCH PORT DATE Datum WO = 8800' SS 1 4926 3771 51 MMG DOME RK 16 01/31/11 13-3/8' CSG, 72#, N-80 BTRS, ID = 12.347" H 3029' l 2 8449 6116 46 MMG SO RK 20 01/31/11 3 10425 7703 29 MMG DMY RK 0 ? TOP OF 7' LNR H 10520' . 1 LC ) 10520' — 9 - 5/8" X 7" B.O.T. TIEBACK w / LNR HGR, ID = ?? Minimum ID = 2.370" @ 13449' . 10736' —17' X4-1/2 BKR S-3 PKR, ID = 3.875" " 3-112 X 2-718" X0 E X I I r - 10769' H4-1/2" HES X NIP, ID = 3.813" ' 4-1/7 TBG, 12.6#, L-80 IBT-M, -I 10791' .0152 bpf , 10 = 3.958" . 10791' — 14 - 1/2" WLEG, ID = 3,958" ■ TOP OF 4-1/2" LNR H 10793' II 10793' H7' X 5" ZXP LNR TOP PKR, D = 5.250" — 1 - 1 10807' — X 5" Hrtsic LNR HGR, ID = 3.938" I 9- /8 " . CSC, 47#, L-80/500 8,68 -95 BTRS, ID = 1" H 1 5 10838' I 7" LNR, 29#, L BTC, 0371 bpf, ID = 6.184' H — 11377 1---- I 7" WHIPSTOCK I 11377' „-' 44 / 4 /' 7" MILLOUT WINDOW (15 11365' - 11377' 1 N.i , 577 P 0 ' ) t e _ 3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.972' H 13449' 1 q co Pe-e- , 1 TOP OF 2-7/8" LNR —1 13514' .■14 2 : 13164' —14-1 /2" UPPER KB STRADDLE PKR, ID = 2.370" 1 4-1/2" LNR 12. L-80 IBT-M —I 13761' 13449' — 3-112" X0 70 2-7/8", ID = 2.370" .0152 bpf, ID — 3.958" 1 k* 13484' -- 4-1/2" KB LOWER STRADDLE PKR, ID = 2.370" 1 ' HLRFURAI1UN SUN/WARY REF LOG SWS MENVCNI,../GP/CCL ON 06/20/99 CI 1 13494' — 3-1/2' FULL/ MS WLEG, ID = 2.380" 1 ANGLE AT TOP PERF: 86* Cg. 11991' 13514' — 3-1/2' DEPLOY SLV, ID = 3.00' 1 Note: Refer to Production DB for historical perf data 1111 13518' j — 3-1 X 2-7/8' X0, ID = 2.380" 1 SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11991 - 12214 0 10/03/03 ' 2-7/8" 6 12259 - 12284 0 10/03/03 1 13551 I RA TAG 1 2-7/8' 4 12470 - 12700 0 07/30/01 *. j 0 0 2-7/8" 4 12730 - 12790 0 07/30/01 2-7/8" 4 12860 - 12950 0 07/30/01 2-7/8' 6 12990 - 13015 0 03/11/08 2-7/8' 6 13075 - 13100 0 03/11/08 1 2-7/8" 2 13230 - 1 • I 0 07/30/* 51 I -r-77 2 6 14345 - 14355 — 0 03111708 2' 12 14355 - 14380 0 03/11/08 1 2" 4 14408 - 14507 0 06/22/99 1 2" 4 14543 - 14558 0 06/22/99 2" 4 14608 - 14638 0 06/22/99 1 PBTD —1 14714' ■••• • • 4 l■-•-•.: 1 2-7/8" LNR, 6.5#, L-80 FL4S„ 0058 bpf, 1D = 2.441" [--- 14718' DATE REV BY COMMENTS DATE REV BY 1 COMMENTS PRUDHOE BAY UNIT 01104181 ROI 176 ORIGINAL COMPLETION 01/11/10 EV/PJC FINAL DRLG CORRECTIONS WELL: 15-21A 06106199 NOES SIDETRACKED (15-21A) 01/12/11 BP/PJC TREE C/O (01/03/11) PERMIT No: n 990290 06/21199 N9ES CTD HORIZ DU (2-718" LNR) 02/13/11 ?/AGR GLV C.10 (01/31/11) API No: 50-029-20503-01 12/21110 NORDIC 1 CTD PATCH (4-1/2" LNR) SEC 22, 711 N, R14E, 70' FWL & 383' FNL 01/01/11 PJC DRLG DRAFT CORRECTIONS 01/10/11 PJC CTD DRLG CORRECTIONS 1 BP Exploration (Alaska) • • Narh Am O IL f s E .. Operation Summery Report 33 Common Well Name: 15 -21A AFE No Event Type: COM- ONSHORE (CON) Start Date: 12/17/2010 End Date: 12/20/2010 APBD15WL21 (740,427.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 5/29/1999 12:00:OOAM Rig Release: 12/20/2010 Rig Contractor: NORDIC CALISTA UWI: 500292050301 Active Datum: 33 : 21 6/9/1999 00:25 @67.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/17/2010 06:00 - 07:00 1.00 RIGD P PRE HELD PRE -TOUR SAFETY MEETING & PREPARE TO BACK RIG OFF WELL. 07:00 - 08:30 1.50 RIGD P PRE PJSM TO BACK RIG OFF WELL. BACK RIG FROM WELL. 08:30 - 10:00 1.50 RIGD P PRE CLEAN WELL AREA. REVIEW ROUTE. LOAD TRAILERS AND SECURE EQUIPMENT AND RIG. 10:00 - 10:30 0.50 RIGD P PRE PJSM TO MOVE RIG. 10:30 - 15:30 5.00 RIGD P PRE MOVE. RIG FROM DS 2 TO DS 15. 15:30 - 18:00 2.50 RIGD P PRE SURVEY AREA. SPOT RIG OFFICE QUARTERS. OBTAIN WELL WORK TRANSFER FROM DS 15 PAD OPERATOR. 18:00 - 18:30 0.50 RIGD P PRE CREW CHANGE OUT. CONTINUE PLACING T -MATS AROUND WELL. 18:30 - 19:15 0.75 RIGD P PRE T -MATS NOT SITTING LEVEL. LEVEL AREA AROUND WELL AND RE -PLACE T -MATS PRIOR TO MOVING RIG OVER. CHECK WELL TO ENSURE IT IS READY TO BACK OVER. 0 PSI ON IA, OA, & WH. ENSURE ALL TREE VALVES ARE CLOSED. 19:15 - 19:45 0.50 RIGD P PRE PJSM FOR MOVING RIG OVER WELL. 19:45 - 23:00 3.25 RIGU P PRE BACK RIG OVER WELL AND ACCEPT RIG @ 21:00. PAD IS NOT LEVEL AND WAIT ON TOOL SERVICES TO BRING OUT PLYWOOD TO LEVEL RIG. PLACE HANDI -BERM AROUND CELLAR AND CONTINUE GENERAL RIG-UP AND SPOTTING OF EQUIPMENT. 23:00 - 00:00 1.00 RIGU P PRE STAB BOPE AND BEGIN N /U. 12/18/2010 00:00 - 01:15 1.25 BOPSUR P PRE CONTINUED FROM CON REPORT DATED 12/17/2010. - CONTINUE N/U BOPE. - STAB AND M/U LUBRICATOR. 01:15 - 02:00 0.75 RIGU P PRE FILL STACK FOR BOPE TEST. 02:00 - 07:00 5.00 BOPSUR P PRE PJSM TO TEST BOPE. WITNESSED WAIVED BY JOHN CRISP W/ AOGCC. PT BOPE AS PER WELLPLAN, AOGCC REGS, AND ADWOP. 07:00 - 10:00 3.00 RIGD P PRE PJSM. P/U INJECTOR TO PUMP OUT DIESEL & PREPARE FOR INNER REEL VALVE TEST. PUMP DIESEL FROM COIL © 1 BPM @ 280 PSI. THREE BBLS FLOWED BACK TO TANK. WARM COIL PRIOR TO TESTING INNER REEL VALVE, PRESSURE BULKHEAD, & BALL DROP VALVE. TEST INNER REEL TO 300/3,500 PSI FOR 5 MINUTES. BLOW BACK COIL WITH AIR TO FREEZE PROTECT (4.4 BBLS). PULL INJECTOR TO SIDE. Printed 3/2/2011 1:11:41 PM e'6 era ti. mina :,, «<< 1 Common Well Name: 15 -21A AFE No Event Type: COM- ONSHORE (CON) Start Date: 12/17/2010 End Date: 12/20/2010 APBD15WL21 (740,427.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 5/29/1999 12:00:OOAM Rig Release: 12/20/2010 Rig Contractor: NORDIC CALISTA UWI: 500292050301 Active Datum: 33 : 21 6/9/1999 00:25 @67.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:30 2.50 BOPSUR P PRE PJSM W/ DSM VALVE CREW. AFTER RIGGING UP & EVALUATING THE "J" SLOT TYPE RUNNING RETRIEVING TOOL; IT WAS DEEMED TO HAVE OPERATIONAL RISKS OF BEING LEFT IN THE HOLE. THE TREE WAS TESTED THE PREVIOUS DAY WITH DSM TO 5,000 PSI BY PRE -WORK WELLS GROUP. 12:30 - 13:30 1.00 BOPSUR P PRE " PJSM. PERFORM DYNAMIC TEST OF TREE TO BODY. OPEN WELL, 0 PSI. PUMP 91 BBLS 2 %KCL, GAINED PRESSURE, PUMPED TOTAL OF 120 BBLS @ 6 BPM, MAX PRESSURE WAS 950 PSI. NO LEAKS SITED AROUND TREE OR WELLHEAD. 13:30 - 15:30 2.00 DHB P OTHCMP R/U DSM LUBRICATOR & TEST TO 250/3,500 PSI. GIH & RETRIEVE GRAY BPV. 0 PSI ON WELL. RD ON LOAD OUT DSM THROUGH PIPE BARN. LOADER WITH STINGER NOT WORKING, LOADER REPLACED, BUT DID NOT HAVE STINGER TO HANDLE LUBRICATOR. 15:30 - 16:00 0.50 RIGU P OTHCMP HELD PRE -JOB WITH BAKER THRU -TBG, MWD, SLB M-I, & NORDIC TO DISCUSS THE WAY FORWARD. DID TABLE -TOP EVACUATION DRILL AFTERWARDS WITH ALL PERSONNEL PRESENT. 16:00 - 18:00 2.00 ZONISO P OTHCMP PJSM. P/U INJECTOR & PREP FOR SLACK MANAGEMENT. PUMP SLACK BACK AND CUT COIL. RE -HEAD CTC. PULL TEST AND PT. 18:00 - 18:15 0.25 ZONISO P OTHCMP CREW CHANGE -OUT. DISCUSS CURRENT OPERATIONS AND PERFORM WALK AROUNDS AND RIG CHECKS. 18:15 - 19:45 1.50 ZONISO P OTHCMP RE -HEAD BAKER INTEQ AND TEST E -LINE. BLOW DOWN COIL. UNSTAB INJ. AND INSTALL DFCV'S AND TEST /CHART TO 250 LOW / 3500 HIGH - GOOD. INSTALL TREE CAP. 19:45 - 20:45 1.00 ZONISO P OTHCMP PJSM FOR BULLHEAD KILLING WELL. LINE UP TO PUMP THRU THE KILL W/ CHOKE CLOSED. OPEN UP MASTER AND SWAB AND WELL IS ON A VAC. BEGIN PUMPING 1.5X TBG. VOL OF 2% KCL. CATCH FLUID AT 20 BBLS IN. 20:45 - FINISH PUMPING TOTAL OF 331 BBLS OF KCL © 6 BPM. CIRC PRESSURE —1400 PSI. SHUT DOWN PUMPS AND BEGIN FLOW CHECK. FINAL WI-VIA/OA: VAC/35/16. 20:45 - 21:30 0.75 ZONISO P OTHCMP MONITOR WELL FOR FLOW FOR 30 MIN - NO FLOW. -TAKES 6 BBLS TO FILL HOLE. - EVALUATE LOSS RATE WHILE FILLING HOLE ACROSS THE TOP. LOSSES ARE — 0.2 BPM. TAKE ON FLUID INTO NON - ACTIVE SYSTEM WHILE MONITORING FOR FLOW. 121:30 - 22:00 0.50 ZONISO P OTHCMP PJSM FOR M/U LOGGING BHA. M/U BOT LINER SLEEVE TEST TOOL AND 3" COILTRAK BHA. Printed 3/2/2011 1:11:41 PM ,orth America - A A KA BP - Of 6 _ 22 4 4 1 ti On Opp = tion Summary Report 0 * Common Well Name: 15 -21A AFE No Event Type: COM- ONSHORE (CON) Start Date: 12/17/2010 End Date: 12/20/2010 APBD15WL21 (740,427.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 5/29/1999 12:00:OOAM Rig Release: 12/20/2010 Rig Contractor: NORDIC CALISTA UWI: 500292050301 Active Datum: 33 : 21 6/9/1999 00:25 @67.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 ZONISO P OTHCMP PRIOR TO RUNNING IN HOLE OPEN EDC AND PUMP COIL VOLUME TO DISTRIBUTE SLACK THRU REEL. TAKES 9 BBL TO FILL HOLE. 22:25 - RIH W/ LOGGING BHA AT 0.4 BPM. LOSING CLOSED IN DISPLACEMENT (5.7 BLU1000') + -0.4 BPM RIH. 12/19/2010 00:00 - 00:30 0.50 ZONISO P ' OTHCMP CONTINUED FROM CON REPORT DATED 12/19/2010. CONTINUE RIH W/ LOGGING/SEAL BHA. 00:30 - 01:30 1.00 ZONISO P - OTHCMP LOG GR TIE -IN FROM 12,575' TO 12,800'. MADE -14' CORRECTION. 01:30 - 02:00 0.50 ZONISO P OTHCMP CONTINUE RIH DOWN TO 13,000' MD. LOG FOR COLLARS FROM 13,000' - 13,475. 02:00 - 02:30 0.50 ZONISO P OTHCMP RIH TO ABOVE DEPLOYMENT SLEEVE. ESTABLISH UP /DOWN WTS. UP WT = 43K, DW WT. = 18K. RIH AT 0.5 BPM AT 80 PSI. STING INTO DEPLOYMENT SLEEVE AND SEE PRESSURE INCREASE TO 300 PSI AT 13,518'. HOLD PRESSURE AND CONFIRM GOOD SEAL INTEGRITY. SET 10K DOWN AT 13,523' AND GO TO P /U. PULL 22K OVER UNSTINGING FROM DEP. SLEEVE. STING BACK INTO LINER W/ PUMPS OFF AND SEE 18K OVER PULLING OUT OF DEPLOYMENT SLEEVE. 02:30 - 03:00 0.50 ZONISO P OTHCMP APPEARS THE DIFFERENTIAL ACROSS THE TOOL IS CAUSING THE ISSUE. DECIDE TO SHEAR OUT BALL SEAT TO EQUALIZE PRESSURE ACROSS TOOL. STING BACK INTO DEPLOYMENT SLEEVE, PRESSURE UP AND SHEAR OUT BALL SEAT. P/U CLEAN TO BREAK -OVER AND ATTEMPT TO PICK UP 1 FT. TO GET SPACE -OUT W/O SUCCESS. DEPLOYMENT SLEEVE APPEARS TO BE TO SHORT TO MAINTAIN SEAL INTEGRITY FOR PROPER SPACE -OUT NEEDED TO SET UPPER PACKER IN TENSION PRIOR TO APPLYING DOWN WT. TO MECHANICALLY SET. 03:00 - 06:30 3.50 ZONISO P OTHCMP POOH W/ LOGGING/SEAL BHA. PUMP 45 BBL BIO PILL ON TRIP OOH. SEE FINE FILL AND SOME SMALL PIECES OF RUBBER COMING OVER SHAKER W/ PILL. LOSSES WHILE POOH ARE 0.1 - 0.25 BPM OVER CALCULATED COIL DISPLACEMENT. 06:30 - 07:30 1.00 ZONISO P OTHCMP PJSM. LD GR /CCL/SEAL UNIT DRIFT 07:30 - 09:00 1.50 RUNCOM P RUNCMP PJSM. PERFORM SLACK MANAGEMENT,PUMP 4 BPM TWICE, 200' OF WIRE RECOVERED. P/U INJECTOR TO M/U BALL CATCHER. LAUNCH 3/4" BALL, BALL HIT @ 57.3 BBLS. RETURN INJECTOR TO BUNG HOLE, CONTINUE CIRCULATING. Printed 3/2/2011 1:11:41 PM �IIfIt N ASA' € °per Lion Summary Report Common Well Name: 15 -21A AFE No Event Type: COM- ONSHORE (CON) Start Date: 12/17/2010 End Date: 12/20/2010 APBD15WL21 (740,427.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 5/29/1999 12:00:00AM Rig Release: 12/20/2010 Rig Contractor: NORDIC CALISTA UWI: 500292050301 Active Datum: 33 : 21 6/9/1999 00:25 @67.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 11:00 2.00 RUNCOM P RUNCMP P/U LOWER STRADDLE PACKER, MS, 2 7/8" PUP, 45 "KB" STRADDLE PKR, DEPLOYMENT SLEEVE, CTLRT, HI -LOAD DISCONNECT, X -O, 4 JTS 2 3/8" PH-6 TBG, X -O, BAKER LOCKABLE SWIVEL, BOT CTC. INSTALL INJECTOR, BLOW DOWN KILL LINE. 11:00 - 15:00 4.00 RUNCOM P RUNCMP RIH "@ 6 - 70 FPM. RUN TO FLAGGED DEPTH OF 13,250', GETTING BACK 4 - 5 BBLS/ 1,000' (CALCUALTED IS 5.4 BBLS/1,000'). MADE -15' CORRECTION. LOWER COIL & TAG BAKER DEPLOYMENT SLEEVE (3" ID) @ 13,518' CTM FOR 2ND CONFIRMATION. 15:00 - 15:45 0.75 RUNCOM P RUNCMP ESTABLISH SO WEIGHT OF 14.5 -K & PU WEIGHT OF 49 -K. DROP 5/8" BALL, PUMP DOWN WITH 2 - .5 BPM @ 840 PSI. BALL LANDED ON SEAT. 15:45 - 16:15 0.50 RUNCOM P RUNCMP PRESSURE UP TO 1,400 PSI TO INIATE PACKER ELEMENTS. SETIQWER STRADDLE PACKER ELEMENT (a7 13,480', EOT (MS) IS aA 13',494'. PRESSURE UP TO 1,400 PSI FOR 2 MINUTES. ATTEMPT TO SET DOWN 10 -K, PIPE MOVING DOWNWARD. PICK BACK UP TO 13,494'. PRESSURE UP TO 2,000 PSI, HELD FOR 2 MINUTES. SLACK OFF 10 -K, PACKER HOLDING. P/U 3 -K OVER STRING WEIGHT OF 49 -K. PRESSURE UP & SHEAR "GI-I" BALL SEAT WITH 2,800 PSI. 16:15 - 18:45 2.50 RUNCOM P RUNCMP PULL OF OF STRADDLE PACKER. TOP OF DEPLOYMENT SLEEVE IS 13,473.21' . BEGIN POOH. SET FLAG ON COIL @ 12,752' EOP POOH. TOTAL LOSSES ON TOH = 9 BBLS. 18:45 - 19:00 0.25 RUNCOM P RUNCMP PJSM FOR UD BHA. DISCUSS PROCEDURES, DROPPED OBJECTS, PERSONAL SAFETY, AND WELL CONTROL. 19:00 - 20:30 1.50 RUNCOM P RUNCMP UD LOWER STRADDLE PACKER SETTING BHA. PREP RIG FLOOR FOR RUNNING SCAB LINER. R/U FARR TONGS. VERIFY LINER TALLY W/ NORDIC DRILLER AND PUSHER. ENSURE JOINTS NOT BEING RUN HAVE THREAD PROTECTORS AND ARE FLAGGED. 20:30 - 20:45 0.25 RUNCOM P RUNCMP PJSM FOR M/U UPPER STRADDLE PACKER ASSEMBLY. 20:45 - 22:00 1.25 RUNCOM P RUNCMP M/U UPPER STRADDI F PA(:KFR RHA CONSISTING OF SEAL ASSEMBLY, LOCATOR SUB, 2 -7/8" PUP, XO, 9 JTS 3 -1/2" L -80 STL, 45 "KB" STRADDLE PACKER, 4" GH RUNNING TOOL, XO, 3/4" HYD DISCONNECT, XO, 2 JTS 2 -3/8" PI-16, XO, BOT LOCKABLE SWIVEL, XO, 2 3/8" BOT CTC. 22:00 - 00:00 2.00 RUNCOM P RUNCMP RIH W/ UPPER STRADDLE PACKER. RIH AT 80 FPM AT 0.45 BPM. BHA OAL = 384.5 FT. HAVE TABLE TOP DISCUSSION WHILE RIH OVER COIL PINHOLE WHEN OPERATING W/O DOWNHOLE CHECK VALVES. DISCUSS WELL CONTROL SCENARIOS AND PROPER PROCEDURES FOR SHEARING COIL. Printed 3/2/2011 1:11:41 PM d rth America AASI BP PRA 4p ation Summary Report ea = Common Well Name: 15 -21A AFE No Event Type: COM- ONSHORE (CON) Start Date: 12/17/2010 End Date: 12/20/2010 APBD15WL21 (740,427.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 5/29/1999 12:00:OOAM Rig Release: 12/20/2010 Rig Contractor: NORDIC CALISTA UWI: 500292050301 Active Datum: 33 : 21 6/9/1999 00:25 @67.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/20/2010 00:00 - 01:00 1.00 RUNCOM P RUNCMP CONTINUED FROM CON REPORT DATED 12/19/2010. CONTINUE RIH W/ UPPER STRADDLE PACKER AT 80 FPM AND 0.45 BPM. RIH TO EOP FLAG AT 13,148.5 AND MAKE -12 FT CORRECTION TO 13,136.5. 01:00 - 02:00 1.00 RUNCOM P RUNCMP RIH AND STING INTO DEPLOYMENT SLEEVE AT 13,485. SEE PRESSURE INCREASE AND CONFIRM POSITIVE SEAL. SET 10K DOWN TO 13,488'. BLEED OFF CT PRESSURE AND P/U TO BALL DROP DEPTH. PUMP 5/8" BALL AT 2 BPM. AT 80% COIL VOLUME (45.8 BBLS) REDUCE RATE TO 0.5 BPM..; BALL ON SEAT AT 54 BBLS (CALCULATED 57.3 BBLS),' 02:00 - 02:15 0.25 RUNCOM P RUNCMP SHUT DOWN PUMPS. OPEN BAKER CHOKE AND BLEED OFF PRESSURE. RIH TO 13,488' AND SET 10K DOWN. P/U TO BREAKOVER +2 FT AT 13,479'. _ PRESSURE UP TO 2000K TO SET SLIPS. BLEED OFF CT PRESSURE. SET 10K DOWN AT 13,485.4' TO CONFIRM SLIPS ARE SET. PRESSURE UP TO 3480 PSI AND BROKE CIRCULATION. P/U FREE AT 46K. PKR ASSY IS SET. BEGIN POOH. 02:15 - 04:30 2.25 RUNCOM P RUNCMP POOH W/ UPPER STRADLE PACKER SETTING BHA. 04:30 - 06:00 1.50 RUNCOM P RUNCMP TAG-UP AND PERFORM FLOW CHECK - GOOD. L/D SETTING BI-IA. LOAD OUT BOT TOOLS, RD FLOOR EQUIPMENT, CUT E -LINE & SEAL. 06:00 - 09:45 3.75 RUNCOM P RUNCMP R/U LITTLE RED & PT. INSERT END OF COIL TUBING THROUGH PACK -OFF. BULLHEAD 38 BBLS DIESEL FOR FREEZE PROTECT. RATE DOWN TO < .3 BPM AFTER PUMPING 15 BBLS. FINISH BULLHEADING 38 BBLS DIESEL @ .14 BPM @ 1,600 PSI. P/U INJECTOR & MOVE OVER BUNG HOLE. 09:45 - 10:30 0.75 WHSUR P RUNCMP PJSM WITH GREASE CREW. GREASE TREE VALVES. 10:30 - 12:00 1.50 WHSUR P RUNCMP PJSM WITH DSM VAVLVE CREW. PLANS WERE TO BRING UP LUBRICATOR ON ELEVATOR INTO PIPE BARN. DSM CREW "STOPPED JOB. THEY WANT TO TAIL IN UP THE BEAVER SLIDE. RIG'S LOADER HAS BEEN DOWN, THERE IS NO STINGER TO PROPERLY LATCH ONTO TOOLS. DSM CALLED FOR LOADER WITH PROPER DEVICE TO TAIL IN TOOLS. PERFORM RIG MAINTENACE & PREPARE PAPER PJSM'S FOR UPCOMING JOBS. 12:00 - 14:30 2.50 WHSUR P RUNCMP PJSM. RU DSM LUBRICATOR, TEST TO 250/3,500 PSI. GIH & RETREIVE BPV. 14:30 - 17:00 2.50 WHSUR P RUNCMP CHECK RAM CAVITIES, BOTTOMS HAD EXCESS DEBRIS, CHECK ALL RAM CAVITIES. CHANGE OUT ACTUATOR SEALS ON BLIND RAMS DRILLER'S SIDE Printed 3/2/2011 1:11:41 PM paw- r hASKA B te E, I . 6 = tllcan t mmalry Rep Common Well Name: 15 -21A AFE No Event Type: COM- ONSHORE (CON) Start Date: 12/17/2010 End Date: 12/20/2010 APBD15WL21 (740,427.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name /No.: NORDIC 2 Spud Date/Time: 5/29/1999 12:00:OOAM Rig Release: 12/20/2010 Rig Contractor: NORDIC CALISTA UWI: 500292050301 Active Datum: 33 : 21 6/9/1999 00:25 @67.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 21:30 4.50 RIGD P RUNCMP CONTINUE N/D BOPE AND PT TREE CAP. CONTINUE RIGGING DOWN AND PREPARE FOR MOVE TO WELL 15 -11 C. 21:30 - 22:00 0.50 RIGD P RUNCMP PJSM FOR BACKING RIG OFF WELL. IDENTIFY HAZARDS AND MITIGATIONS. DISCUSS PROPER COMMUNICATION, SPOTTER POSITIONING AND RESPONSIBILITIES. CHECK TO ENSURE ALL TREE VALVES ARE CLOSED AND IA/OA = 0. 22:00 - RIGD P RUNCMP BACK RIG OFF OF WELL. CLEAN UP AROUND CELLAR AREA. BEGIN MOVE TO WELL 15 -11C. RIG RELEASED AT 22:00. ALL SUBSEQUENT REPORTS ON 15-11C. Printed 3/2/2011 1:11:41PM BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, lgsi°~ 1 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, ~~ _~~ n w Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01B 2042570 50029206960200- NA Sealed NA 15-02B 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-04B 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-OSC 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31 B 2050860 50029222850200 NA 1.2 NA 3.4 11 /11 /2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11 /9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 1118/2009 ® STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~ION f{~(„~CI V GV MAR ~ ~ 2008 REPORT O F SUNDRY WELL O P E RATION S Ala~ca p~ & Gas Cons: Commissions 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0 ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc.. 4. Current Well Class: 5. Permit to Drill Number: Name: Development lv' - Exploratory ~ 199-0290 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20503-01-00 ' 7. KB Elevation (ft): ~ 9. Well Name and Number: / i+ r~ ~ ~~ KB PBU 15-21A - 8. Property Designation: 10. Field/Pool(s): _ ADLO-028303 " PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 14720 feet Plugs (measured) None true vertical 8987.32 feet Junk (measured) 13045 Effective Depth measured 13043 feet ~~NEf~ APR ~ 4 2008 true vertical 8791 feet Casing Length Size MD TVD Burst Collapse Gonductor 82 20" 91.5# H-40 32 - 114 32 - 114 1490 470 Surface 2999 13-3/8"72# N-80 31 - 3030 31 - 2680 4930 2670 Production 10223 9-5/8" 47# L-80 30 - 10253 30 - 7551 6870 4760 Production 585 9-5/8" 47# SOO-95 10253 - 10838 7552 - 8065 8150 5080 Liner 845 7" 29# L-80 10520 - 11365 7786 - 8515 8160 7020 Liner 2968 4-1/2" 12.6# L-80 10793 - 13761 8025 - 8773 8430 7500 Liner 1204 2-7/8" 6.5# L-80 13514 - 14718 8776 - 8987 10570 11160 Perforation depth: Measured depth: See Attached - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 26 - 10793 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 10738 5" Baker ZXP Top Packer 10793 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 564 30942 9 1274 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 1"~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ I~"I 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 Preb Title Data Management Engineer Signature ~( Phone 564-4944 Date 3/12/2008 orm - eves ~ ` ~ u mit ngina n y '~ ~-l l 15-21 A 199-0290 PERFORATION ATTACHMENT ,] MDT MDB TVDSST TVDSSB 3/11/2008 11,991 12,214 8,793.00 8,800.00 12,259 12,284 8,800.00 8,801.00 12,470 12,700 8,804.00 8,799.00 12,730 12,790 8,780.00 8,802.00 12,860 12,950 8,802.00 8,797.00 13,005 13,030 8,794.00 8,792.00 APF 13,090 13,115 8,788.00 8,785.00 APF 13,230 13,430 8,777.00 8,776.00 14,360 14,370 8,854.00 8,859.00 14,370 14,385 8,859.00 8,867.00 14,385 14,395 8,867.00 8,873.00 14,408 14,507 8,880.00 8,926.00 14,543 14,558 8,940.00 8,945.00 14,608 14,638 8,960.00 8,968.00 • • 15-21A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY CTU #8, Add Perf; Cont' from 3/08/08 ... InterACT publishing. MIRU. Pump 5/8" ball for drift of coil. Perform weekly BOP test -Passed. RIH with WFD 2.23" Venturi junk basket to drift 2 7/8" liner and check for lost IBP elements. Dry tagged down just below deepest perfs at 14,638' ctmd. POOH. Found venturi full of clay fines /mud. MU and RIH with SWS memory GR/CCL inside 2.20" carrier. Log from 14500' ctmd to 14100'. Painted coil flag at 14350' ctmd. POOH. Job Cont' on 3/10/08 WSR ... 3/10/2008CTU #8, Add Perf; Cont' from WSR 3/09/08 ... ***InterACT not publishing*"* `POOH with SWS Logging tools. Confirm good data with logging engineer (-18' corr. MU 25', 2.0" 6SPF 2006PJ Omega guns. RIH with Gun #1. Correct depth '!at flag. Perforate 14370' to 14395'. POOH. All shots fired. MU 25', 2.0" 6SPF '2006PJ Omega guns. RIH with Gun #2. Perforate 14360' to 14385'. POOH. 'All shots fired. Cont' on 3/11/08 WSR. 3/11/2008CTU #8, Add Perf; Cont' from 3/10/08 WSR ... InterACT not publishing. RIH :with SWS memory GR/CCL. Log interval 13300' up to 12700', stopping to flag ;pipe at 13000' ctmd. POOH. Data good (-15' corr. MU &RIH with Gun #3; 25' - SWS 2 7/8" HSD-PJ2906 OMEGA HMX - 6 spf. Correct depth at flag. ,Perforate ..,`interval 13090'0 13115'. POOH. '`'`* Job in Progress *** 3/11/20081CTU #8, Add Perf; Cont' from 3/10/08 WSR ... InterACT not publishing. RIH :with SWS memory GR/CCL. Log interval 13300' up to 12700', stopping to flag ;pipe at 13000' ctmd. POOH. Data good (-15' corr. MU &RIH with Gun #3; 25' - SWS 2 7/8" HSD-PJ2906 OMEGA HMX - 6 spf. Correct depth at flag. Perforate `interval 13090' to 13115'. POOH. MU and RIH with Gun #4; 25' - 2 7/8" HSD- PJ2906 OMEGA - 6 spf. *"'`Cont' on 3/12/08 WSR*** • • 3 CTU #8 Add Perf; Cont' from 3/11/08 WSR InterACT publishing RIH with gun #4. Correct to top shot at flag. PUH to perforating depth. Perforate 13005' - ._. 13030'. POOH. Confirm all shots fired. RD gun #4. MU to well for ree blowdown. Blow down reel with N2. Notify DSO of well status. RDMO. ***Job 'Complete*** FLUIDS PUMPED BBLS 38 60/40/METH 6 N2 44 Totai STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI RECEIVED FEB 0 3 2004 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Suspend D Repair Well D Pull TubingD Operation Shutdown D Plug PerforationsŒ] Perforate New PoolD 4. Current Well Class: Perforate ŒJ WaiverD AnchoragetherD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 199-0290 Name: BP Exploration (Alaska), Inc. 67.00 8. Property Designation: ADL-028303 11. Present Well Condition Summary: Development ŒJ Stratigraphic 0 9. Well Name and Number: 15-21 A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool Exploratory D Service D 6. API Number 50-029-20503-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 14720 feet Plugs (measured) Junk (measured) 13043 true vertical 8987.3 feet Effective Depth measured 13043 feet true vertical 8791.2 feet None Casing Length Size MD TVD Burst Collapse Conductor 82 20" 91.5# H-40 32 114 32.0 - 114.0 1490 470 Liner 845 7" 29# L-80 10520 - 11365 7786.3 - 8514.8 8160 7020 Liner 2968 4-1/2" 12.6# L-80 10793 - 13761 8025.3 - 8773.2 8430 7500 Liner 1204 2-7/8" 6.5# L-80 13514 - 14718 8775.7 - 8986.9 10570 11160 Production 10223 9-5/8" 47# L-80 30 - 10253 30.0 - 7551.5 6870 4760 Production 585 9-5/8" 47# 500-95 10253 - 10838 7551.5 - 8064.5 8150 5080 Surface 2999 13-3/8" 72# N-80 31 - 3030 31.0 - 2679.9 4930 2670 Perforation depth: Measured depth: 11991 -12214,12259 -12284,12470 -12700,12730 -12790,12860 -12950 True vertical depth: 8792.91 - 8799.96, 8800.02 - 8800.73, 8803.63 - 8798.86, 8799.52 - 8801.59, 8802.14- 8796.8 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 26 10793 packérs & SSSV (type & measured depth): 4-1/2" Baker 5-3 Perm Packer 5" Baker ZXP Liner Top Packer @ 10738 @ 10793 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 893 35.2 12 600 1081 949 36.8 14 0 782 14. Attachments: 15. Well Class after proposed work: Exploratory D Development Œ] Service D Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ;), Title Production Technical Assistant Signature Phone 564-4657 Date 1/30/04 Form 10-404 Revised 12/2003 '§(;Þ~~~NE[) rES 1 8 2004. ORIGINAL rk1gt:)í~~I~ ~lE[t} (ID 42,iit 15-21 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/24/03 DRIFT W/ 33/8 DUMMY GUN STOPPED @ 11820' WLM DUE TO DEVIATION. 10/02/03 Continued from WSR of 10/1/03. Kill well with 1% KCL. Bleed IA. RIH with memory logging tools and 3.70 drift. Log 13100 - 11700' to cover IBP / Perf interval. RIH with Baker 3 3/8' IBP and set with center of element at 13045' 10/02/03 Set IBP @ 13043' 10/03/03 Perforate 11991'.12214'6 SPF, 12259'.12284' 6 SPF, 12259'.12284' 6 SPF 10/09/03 ***CONTINUED FROM 10-8-03 WSR*** PULLED DGLV'S FROM STA. # 1 & 2 SET LGLV IN STA. # 1 & S/O GLV IN STA. # 2 (GENERIC DESIGN) *** RETURNED WELL TO DSO TO POp*** FLUIDS PUMPED BBLS 249 60/40 Methanal 20 Flo Pro 339 1 % KCL 650 Crude 1258 TOTAL Page 1 WELLHEAD = GRAY A CflJA. TOR = AXELSON KB. B..EV = 67 BF. ELEV = ? KOP= 1300' Max Angle = 95 @ 13108' Datum MD = 14384' DatumTVD = 8800' SS 15-21A SAFETY NOTES: 700@ 11732' AND 90° @ 12200' TREE = GRAY GEN 2 TOP OF 7" LNR, 29# 4-1/2" X NIP, D = 3.813" 13-3/8" CSG, 72#, N-80/L-80, ID = 12.347" ST MD TVD 1 4926 3771 2 8449 6116 3 10425 7703 GAS LIFT rw\NDRB..S DEV TYP VLV LATCH 51 fvtv1G DOtv'E RK 46 fvtv1G S/O RK 29 fvtv1G D"v1Y RK PORT DA. 1E 16 10/09103 20 10/09103 ? 10520' 10736' 4-1/2" X NIP, D = 3.813" Minimum ID = 2.441" @ 13514' TOP 2-7/8" LINER 7" X 4-1/'Z' BAKffi &3 A<R 10770' 4-1/'Z'TBG,12.6#,L-80,.0152bpf,ID=3.958" H 10793' I I TOP OF 4-1/2" LNR 1-1 10793' 4-1/2" WLEG -i 7" X 5" ZXP LNR TOP PKR I 9-5/8" CSG, 47#, L-801S00-95, ID = 8.681" TOP OF WHPSTOCK I 7" WINDOW: 11365' - 11377' I 11377 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" I 13761' PffiFORA TION SUrvMARY REF LOG:SWS MErvYCNL/GRlCCL ON 06120199 ANGLEATTOPÆRF: 93@ 12470' NJte: Refer to A'oduetion DB for historieal perf data SIZE SPF INTffiV AL Opn/Sqz DA1E 2-7/8" 6 11991-12214 0 10/03103 2-7/8" 6 12259 - 12284 0 10/03103 2-7/8" 4 12470 - 12700 0 07/30/01 2-7/8" 4 12730 - 12790 0 07/30/01 2-7/8" 4 12860 - 12950 0 07/30/01 2-7/8" 2 13230 - 13430 0 07/30/01 2" 4 14408 - 14507 0 06/22/99 2" 4 14543 - 14558 0 06122/99 2" 4 14608 - 14638 0 06/22/99 2-7/8" LNR-CT, 6.5#, L-80, .00579 bpf,lD = 2.441" DA1E REV BY COMMENTS DATE REV BY COMMENTS 1980 ORIGINAL COMPLETION 10/09/03 JCrvYTLP GL V C/O 06106199 SIŒTRACKEÐ 06121/99 CTD HORlZ EXTENSION 02/08102 RN/1P CORRECllONS 09/11/03 CMO/lLP PffiF ANGLE CORRECllON 10/03103 JGM/lLP PffiFS CORRECllONS & IBP PRUDHOE BAY lK'J1T WELL: 15-21A PffiMT NJ: 1990290 API NJ: 50-029-20503-01 SEC 22, T11 N, R14E, 5013.32' ÆL & 2606.69' FNL BP Exploration (Alaska) WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To; State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 13S9 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole 1 I 1 Res. Eval. CH I 1 1 DS 15-21A 10-02-03 Mech. CH 1 Caliper Survey Print Name: Date: ProActive Diagnostic Services, Inc., PO Box 1369 Stafford TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog, com Website: www.memorylog.com 09/16/03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2959 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color l~ ,. Well Job # Log Description Date Blueline Prints CD D.S. 15-21A I_~L~ '-(~ 23318 MCNL 05/15/03 D-03A ,~(~l~~ j~'~j ~ ,~ 23404 MCNL ... 06126/03 W-34A ~ ~(~.~ 23347 MCNL 05~22~03 F40B ~~ ~~ 23401 MCNL 06/12/03 F-2OS ~O%-~[,D 2~ MCNL oem~oo D.S. Z-30A~~%~)~ 23420 MCNL 08/08/03 W46A ~~--J~C~ 23426 MCNL 07/19/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 .,~,~ 900 E. Benson Blvd. ,~,~, Anchorage, Alaska 99508 ~,ECE~VED. ~, .. , Date Delivered: SEP Z 0 ,Ar~chomge Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 06~O5~03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2800 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th.Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD W-19AL1 ~ 23099 TIE-IN MGR/CCL 03106103 I 1 , , P2-57A "'--.5 23272 MCNL 03115103 I 1 , . D.S. 12-20 ""J LDL 06/03/03 D.S. 15-2'~A-..~1 PRODUCTION PROFILE 05/i5103 B-04 '--J PRODUCTION PROFILE/GHOST 05117103 1 F-10A -"-J LDL 05/18103 1 ................. ,, D-30A' -"-u ' ' MEM PRODUCTION PROFILE 05~20~03 1 D-22B -..~1 MEM PRODUCTION PROFILE 05/22/03 1 K.01 '--~ LDL 05116103 1' .. , . · , .... ......... . , · . , . ,. ,. ,. ,. . . .. ·., PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2~I 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /O Schlumberger GeoQuest ~ 3940 Arctic Blvd, Suite 300 ,i Anchorage, AK 99503-5711 ATTN: Beth i 199-029-0 PRUDHOE BAY UNIT 15-21A 50- 029-20503-01 BP EXPLORATION Roll #1: Start: Stop Roll #2: Start ~ Stop (ALASKA) INC MD 14720 TVD 08987 Completion Date:~9 Completed Status: 1-OIL Current: T Name Interval C 9374 ~ 1 SCHLUM PEX-AIT/BHC C 9375 2 SCHLUM IMP-CDR D 9510~ 1 BH GR L BHC L-~' FINAL 11372-11952 L GR-MD ~NAL 13760-14686 L GR-TVD ~' 8706-8910 L IMP-GR/RES-MD ~.'~ FINAL 11388.7-13760. L IMP-GR/RES-TVD c~ FINAL 8500-8790 L MCNL f,~AL 10905-14700 6/20/99 PEX-3DD/CN e,,~~t FINAL 11372-11952 L L PEX-AIT ~ FINAL 11372-11952 L PEX-BHCS-TVD FINAL 11372-11952 L PEX-CN j~ L PEX-MCFL J'~ R SRVY LSTNG R SRVY RPT FINAL 11372-11952 FINAL 11372-11952 ~668.35-14720. ~UM 11342.78-13760. Sent Received T/C/D OH 11/18/99 11/30/99 OH 11/23/99 11/30/99 OH 2/29/00 3/8/00 OH 2/5 11/18/99 11/30/99 OH 2/5 2/29/00 3/8/00 OH 2/5 2/29/00 3/8/00 OH 2/5 11/23/99 11/30/99 C OH 2/5 11/23/99 11/30/99 CH 2 11/17/99 11/23/99 OH 2/5 11/18/99 11/30/99 OH 2/5 11/18/99 11/30/99 OH 2/5 11/18/99 11/30/99 OH 2/5 11/18/99 11/30/99 OH 2/5 11/18/99 11/30/99 OH 6/25/99 6/25/99 D OH 6/8/99 6/14/99 D Wednesday, May 02, 2001 Page 1 of 1 ...... STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 67 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 382' FNL, 5209' FEL, Sec. 22, T11N, R14E, UM (asp's 675981, 5961100) 15-21A At top of productive interval 9. Permit number / approval number 4943' FNL, 3411' FWL, Sec. 9, T11 N, R14E,-UM (asp's 672348, 5967015) 199-029 At effective depth 10. APl number 50-029-20503-01 At total depth 11. Field / Pool 2610' FNL, 5022' FEL, Sec. 9, T11 N, R14E, UM (asp's 670685, 5969314) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 14720 feet Plugs (measured) Tagged PBTD @ 14523' CTM on 7/29/2001. true vertical 8987 feet Effective depth: measured 14523 feet Junk (measured) true vertical 8933 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 300 Sx PF 110' 110' Surface 2963' 13-3/8" 3200 Sx Fondu & 900 Sx PF II 3030' 2680' Intermediate 10771' 9-5/8" 700 Sx Class G & 300 Sx PFC 10838' 8065' Production 845' 7" 725 Sx Class G 11365' 8515' Liner 2968' 4-1/2" 314 Sx Class G 13761' 8773' Liner 1204' 2-7/8" 49 Sx Class G 14718' 8987' Perforation depth: measured 12470'- 12700'; 12730'- 12790'; 12860'- 12950'; 13230'- 13430'; 14408'- 14507'; 14543'- 14558'; 14608'- 14678'. true vertical 8804'-8799'; 8800'-8802'; 8802'-8797'; 8777'-8776'; 8880'-8926'; 8940'-8945'; 8960'-8978'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 10791'MD. AUG '~ 3 2001 Packers & SSSV (type & measured depth) 7" X 4-1/2" Baker S-3 Packer @ 10736' MD; 7" x 5" XZP Liner Top Packer ~,~'~ ~.& Gas COns. Co~J'rJJ$sJo~ 4-1/2" x Nipple @ 2086' MD. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 708 6296 0 - 316 Subsequent to operation 4379 5942 100 376 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify t,,hat the foregoing is true and correct to the best of my knowledge. ~~ir Signed .,~t.~ ~,,( ~ (//'-'~ Title: DS 15 Surveillance Engineer Date Au.qust 8, 2001 Preston Evans Prepared by Paul Rauf 564-5799 ORIGINAL. Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 15-21A DESCRIPTION OF WORK COMPLETED EXTENDED CT PERFORATING OPERATIONS Date Event Summary 5/15/2001' 7/28/2001' 7/29/2001- 7/30/2001: Pumped 110 bbls Hot Crude down tubing to clear paraffin. RIH & drifted to 11650' (HAW). MIRU CTU & Work Platfrom. PT'd BOPE. Pumped 235 bbls of Filtered 1% KCI Water down BS to kill well. Completed killing of well. RIH w/Memory GR/CCL & tagged PBTD @ 14523' CTM. Spotted 30 bbl FIo Pro Pill. Logged to 12000'. POOH w/logging tools while displacing well w/Filtered 1% KCI Water. RIH w/CT conveyed perforating guns & did tie-in. Shot 200' of add perforations in the 4-1/2" liner from: 13230' - 13430' MD (Zone 1) Reference Log: SWS Mere Thermal Neutron Log 6/20/1999. For this run, used 2-7/8" PJ carriers & all shots @ 2 SPF, random orientation, 60° phasing, & overbalanced press. POOH w/guns - ASF. RIH w/CT conveyed perf guns (2 runs) & shot an additional 380' of add perforations in the 4- 1/2" liner from: 12470'- 12700' MD (Zone 1) 12730'- 12790' MD (Zone 1) 12860'- 12950' MD (Zone 1) Used 2-7/8" PJ carriers & all shots @ 4 SPF, random orientation, 60° phasing, & overbalanced press. POOH w/guns - ASF. RIH w/CT & jetted 160° F Hot Oil to 5250'. POOH jetting Filtered 1% KCL Water. RD CTU & Work Platform. A total of 580' ofaddperfs were shot in the 4-1/2" liner. Placed well BOL & performed a representative welltest. Page 1 AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99510 Well Reference Data: Well No: 15-21A Field: County: State: Prudhoe Bay Unit North Slope Alaska Date- 02/29/00 API No: 500292050301 BHI Jobg: 105367 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR DPR/MDL/MDP TOTALS: Log T~e Navigamma USMPR ~Dn/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks :1 LIS Verification Report & Listings :1 Depth Shift Monitor Plot Up~, Rece~i~p.t ,. Please sign and fax to: Baker Hughes INTEQ Fax#: (90_73. ~6~6621 Att~ ~~~ ~herland Naska O~i & Bas Cons. Comm~smn Schlumberger NO. 12956 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-I'N: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CD 15-21A 99387 IMPOLSE eR/~.~S ~ ____C-~':~r'l ~"- 990605 1 D.S. 15-21A 99387 ~ IMPULSE GR/~S 990605 1 1 D.S. 15-21A 99387 ~ IMPULSE GR/~S 990605 I 1 SlGNEI~"" '~'~(~~ ~~-~ ~i' DATE: ~il /~eska 0il & Gas Cons. C0~missi0r~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank ~.h0ra§e 11/23/99 11/18/99 Schlumberger NO. 12945 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CD D.S. 15-21A 99386 PEX,AIT, & BHC ~ C1~%~"l c.{ 99060~. 1 D.S. 15-21A 99386 t~EX-A[T 990601 I 1 D.S. 15-21A 99386 [~.X-t~C~'T. 990601 I 1 D.S. 15-21A 99386 P~..x-3 ]:)~..~' ]:)~..~ST?¥ 990601 I 1 D.S. 15-21A 99386 t)~..x- Ct~l~ 990601 I 1 .... D.S. 15-21A 99386 BRC 990601 I 1 D.S. 15-21A 99386 PEX-SSTVD & BHC 990601 I I .... RE( SIGNED . DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you..~J1Ch01'Sg~ i999 Alaska Oil & Gas Cons. Schlumberger NO. 12942 11/17/99 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 I~J' ~,~2. Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 4-21 LEAK DETECTION LOG 991101 I 1 ,, D.S. 4-30 PRODUCTION PROFILE 991031 1 1 D.S. 7-24 PRODUCTION PROFILE W/DEFT 991031 I 1 D.S. 7-33A PR2 GAS LIFT & FBHP SURVEY 991028 I 1 D.S. 14-04A .,~.c~,-~c~-~ 99378 RST BORAX 990920 I I 1 D.S. 15-21A ~C~_~-'u~l ?'.z,~, ~ 99274 MCNL 990620 I I I [ , ./ ,.. C$ i999 SIGNE DATE: I Al~ka Oil & Gas Cons~ Commission .Ancil0rag~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. -~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well [] Oil I~ Gas [~] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 99-029 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612,, __.___ 50-029-20503-01 4. Location of well at surface ~ r~?~L~..3~..7i ~~ 9. Unit or Lease Name 382' SNL, 80' EWL, SEC. 22, T11N, R14E, UM !/,..,,~;;~~ Prudhoe Bay Unit Attop of productive interval ~"~~ l' !10. Well Number 341' NSL, 3414' WEL, SEC. 09, T11N, R14E, UMI ~.,.~k 15-21A At total depth .,' .... .,~! . 11. Field and Pool 2671' NSL, 5022' WEL, SEC. 09, T11N, R14E, UM ..... ¢ ...... ~ ..... '""'.-'*¢'~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool DF = 59.78'I ADL 028303 12. Date Spudded5/29/99 [ 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' water depth' if OffshOre 116' N°' Of COmpletiOnsC/19/99 6/22/99 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVB)I19. Directional Survey 120' Depth where SSSV set 121' Thickness of Permafrost 14720 8987 FTI 14714 8986 FTI [~Yes [--INo (Nipple) 2086' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, CNL, GR, CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO~-rOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 300 sx Permafrost 13-3/8" 72# N-80 Surface 3030' 17-1/2" 3200 sx Fondu, 900 sx Permafrost II 9-5/8" 47# L-80 / S0095 Surface 10838' 12-1/4" 700 sx Class 'G', 300 sx Permafrost 'C' 7" 26# L-80 10520' 11365' 8-1/2" 725 sx Class 'G' 4-1/2" 12.6# L-80 10793' 13761' 6" 314 sx Class 'G' 2-7/8" 6.16# L-80 13514' 14718' 3-3/4" 149 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 125. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10791' 10736' MD TVD MD TVD 14408' - 14507' 8880' - 8926' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14543' - 14558' 8940' - 8945' ., 14608' - 14678' 8960' - 8978' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 25, 1999 I Gas Lift Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO ~)ate of Test Hours TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BEE OIL GRAWTY-API (CORR) ~ress. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . · Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 11002' 8205' Shublik 11050' 8247' Sadlerochit 11128' 8314' Top of Zone 1 11720' 8733' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the forego, g jag is true and correct to the best of my knowledge Signed '~0.~__ ~ Terde Hubble , Title Technical Assistant III Date " 15-2 lA 99-029 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Gas Coils. Cof¢',~si, o~' Facility PB DS 15 Date/Time Duration 17 May 99 21:30-06:00 8-1/2 hr 21:30-01:00 3-1/2 hr 18 May 99 01:00 01:00-03:30 2-1/2 hr 03:30 03:30-06:00 2-1/2 hr 03:30-06:00 2-1/2 hr 06:00-06:00 24 hr 06:00-13:30 7-1/2 hr 13:30 13:30-03:00 13-1/2 hr 19 May 99 03:00 03:00-06:00 3 hr 03:00-06:00 3 hr 06:00-11:00 5 hr 06:00-11:00 5 hr 11:00 11:00-14:00 3 hr 11:00-14:00 3 hr 14:00 14:00-17:30 3-1/2 hr 14:00-15:30 1-1/2 hr 15:30 15:30-17:30 2 hr Progress Report Activity Move rig Rigged down Drillfloor / Derrick R/D floor. Removed top drive from blocks. Bridal up, lower cattle shute. Pull pits away from sub base. Equipment work completed Rig moved 50.00 % Move rig offDS 12-28A. Rig off station Rigged down Drillfloor / Derrick L/D derrick. Work on safety upgrades on monkey board, fingers, stabbing board, etc. Rigged down Drillfloor / Derrick Cont'd work on derrick. Camera mount, crown bell, safety chains, gaitronics, manrider cable, pad eyes for monkey board, visual inspect crown sheaves, derrick climber fall arrestor, etc. Move rig (cont...) Rigged down Drillfloor / Derrick (cont...) Cont'd work on derrick. Camera mount, crown bell, safety chains, gaitronics, manrider cable, pad eyes for monkey board, visual inspect crown sheaves, derrick climber fall arrestor, etc. Equipment work completed Rig moved 100.00 % Moved camp and pits to DS 15. Move shop. Moves sub structure. Sub structure over well at 0300 hrs. At well location - Cellar Rigged up Drillfloor / Derrick Spot pits, camp, berm around rig. Hook up lines. Prepare to raise derrick. Rigged up Drill floor / Derrick Hook up lines, spot cuttings tank, work on berms. Raised derrick. Unbridle derrick. Hook up top drive, R/U rig floor. Move rig (cont...) Rigged up Drillfloor / Derrick (cont...) Hook up lines, spot cuttings tank, work on berms. Raised derrick. Unbridle derrick. Hook up top drive, R/U rig floor. Equipment work completed Rig accepted at 1100 hrs 5/19/99. Fluid system Fill pits with Seawater Fill pits with seawater. Break and inspect XO's on top drive. (Tuboscope) Completed operations Wellhead work Rigged up High pressure lines RFLI to tree for circulating out freeze protect. Equipment work completed Removed Hanger plug R/U drill site maintenance lubricator and pulled BPV. Well 15-21A Page 1 Rig Nabors 9ES Date 12 July 99 Facility Date/Time PB DS 15 Duration 17:30 17:30-18:30 17:30-18:30 lhr lhr 18:30 18:30-19:30 18:30-19:30 1 hr 1 hr 19:30 19:30-22:30 19:30-22:30 22:30 22:30-04:00 22:30-00:00 3 hr 3hr 5-1/2 hr 1-1/2 hr 20 May 99 00:00 00:00-04:00 04:00 04:00-06:00 04:00-06:00 04:00-06:00 06:00-09:00 06:00-08:30 08:30 08:30-09:00 4hr 2 hr 2 hr 2 hr 3 hr 2-1/2 hr 1/2 hr 09:00 09:00-15:30 09:00-13:30 6-1/2 hr 4-1/2 hr 13:30 13:30-14:00 14:00 14:00-15:30 1/2 hr 1-1/2hr Progress Report 15:30 15:30-06:00 15:30-17:00 Well 15-21A Page 2 Rig Nabors 9ES Date 12 July 99 14-1/2 hr 1-1/2 hr Activity Stopped · To hold safety meeting Fluid system Held safety meeting Held pre-spud meeting. Reviewed well plan, went thru pre-spud checklist. Held PJSM hazard analysis. Completed operations Perform integrity test Tested High pressure lines Finish R/U and pressure tested choke and kill lines. Pressure test completed successfully - 3500.000 psi Fluid system Circulated at 10466.0 ft Circ well to seawater sending diesel for recycle atFS 1. Hole displaced with Seawater - 100.00 % displaced Well is dead. Wellhead work Installed Hanger plug Installed BPV and tested below to 500 psi. Eqpt. work completed, running tool retrieved Removed Xmas tree N/D wellhead adapter and tree from well. Function lock down screws. Equipment work completed Nipple up BOP stack Rigged up BOP stack N/U BOP's. Rigged up BOP stack Finish N/U BOP' s. Nipple up BOP stack (cont...) Rigged up BOP stack (cont...) Finish N/U BOP's. Equipment work completed Installed Hanger plug Installed BPV with TWC for BOP test. Eqpt. work completed, running tool retrieved Test well control equipment Tested BOP stack PFU testjt and tested BOP's. Tested pipe rams, blind rams, choke and kill lines, HCR valves,choke, floor & top drive safety valves to 250/5000 psi. Tested annular to 250/3500psi. Ran accumulator test. Test witnessed by L. Gramaldi, AOGCC. Pressure test completed successfully - 5000.000 psi Held safety meeting Held hazzard analysis PJSM for pulling BPV/TWC with lubricator. Completed operations Retrieved Hanger plug Pulled BPV/TWC with lubricator. Equipment work completed Pull Gas lift completion, 3-1/2in O.D. Installed Drillpipe retrieval string Facility PB DS 15 Date/Time 17:00 17:00-19:00 Duration 2hr 19:00 19:00-06:00 llhr 21 May 99 06:00-10:30 06:00-07:00 4-1/2 hr 1 hr 07:00 07:00-08:00 08:00 08:00-10:00 lhr 2 hr 10:00 10:00-10:30 10:30 10:30-11:30 10:30-11:30 11:30 1/2 hr lhr lhr 22 May 99 11:30-06:00 11:30-13:30 18-1/2 hr 2 hr 13:30 13:30-02:30 02:30 02:30-03:00 03:00 03:00-04:30 04:30 04:30-06:00 04:30-06:00 06:00-09:30 06:00-09:30 13hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr 09:30 09:30-10:30 09:30-10:30 Progress Report Well 15-21A Page 3 Rig Nabors 9ES Date 12 July 99 10:30 1 hr 1 hr Activity 5-1/2"pup below hanger. Completed operations Retrieved Tubing hanger Pulled hanger to rig floor. PFU =185K. Observe well static. L/D hanger. Equipment work completed Laid down Tubing of 7300.0 ft L/D tubing. Spooled control line with camco. Recovered 38 ss bands. Pulling completion at report time. Pull Gas lift completion, 3-1/2in O.D. (cont...) Laid down 9200.0 ft of Tubing (cont...) L/D tubing. Spooled control line with camco. Recovered 38 ss bands. Pulling completion at report time. Stopped: To service drilling equipment Serviced Tubing handling equipment Repaired casing tongs. Equipment work completed Laid down 10440.0 ft of Tubing Finished L/D 10,440' ft of tubing. Retrieved 335jts, 14'cutjt, 2 GLM's, SSSV, 38 ss bands. 335 joints laid out Removed Tubing handling equipment Clear floor. Equipment work completed Wellhead work Installed Wear bushing Eqpt. work completed, running tool retrieved BHA run no. 1 Made up BHA no. 1 MFU fishing BHA. BHA no. 1 made up Singled in drill pipe to 10440.0 ft At Top offish: 10440.0 ft Fished at 10440.0 ft Wash over fish. Set grappel. PFU 345K, seals pulled free. Fish came free Circulated at 10490.0 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 8630.0 ft POH w/fish. Pulled out of hole to 8630.0 ft POH @ report time. BHA run no. 1 (cont...) Pulled out of hole to 323.0 ft (cont...) POH @ report time. At BHA Suspend operations Held drill (Spill) Rig crew responded to diesel fuel spill when fuel truck hose burst. Cleaned up two gallons diesel spill. Completed operations Facility Date/Time 23 May 99 PB DS 15 10:30-12:00 10:30-11:00 11:00 11:00-12:00 12:00 12:00-06:00 12:00-14:30 14:30 14:30-18:00 18:00 18:00-18:30 18:30 18:30-22:00 Duration 1-1/2 hr 1/2 hr lhr 18hr 2-1/2 hr 3-1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 3 hr 22:00 22:00-01:30 01:30 01:30-04:30 1-1/2 hr 04:30 04:30-06:00 21-1/2 hr 3hr 06:00-03:30 06:00-09:00 11-1/2 hr 09:00 09:00-20:30 20:30 6 hr 1 hr Progress Report 20:30-02:30 24 May 99 02:30 02:30-03:30 Well 15-21A Page 4 Rig Nabors 9ES Date 12 July 99 03:30 03:30-06:00 03:30-05:00 05:00 05:00-06:00 06:00-23:30 2-1/2 hr 1-1/2 hr 1 hr 17-1/2 hr Activity BHA run no. 1 Pulled BHA L/D jars. BHA Stood back DC stood back. Laid down fish L/D cut it, 2 pup its, seal assembly. Complete fish recovered BHA run no. 2 Made up BHA no. 2 Make up packer milling retrieving BHA. BHA no. 2 made up Singled in drill pipe to 3883.0 ft P/U 15jts HWDP and 99its 4" drill pipe. 114 joints picked up Serviced Block line Line slipped R.I.H. to 10465.0 ft Wash into packer, packer @ 10,465. At Top of packer: 10465.0 ft Milled Permanent packer at 10465.0 ft In 0.10 hr had 5.000 bbl Gain - closed in well Circulated at 10465.0 ft Had 5 bbl pit gain and flow increase. SI well, no pressure on drill pipe or annulus. Circ gas out thru choke, some oil. (Tailpipe assembly 31 jts tbg) Obtained req. fluid properties - 150.00 %, hole vol. Milled Permanent packer at 10465.0 ft Continue to mill on packer. Unable to push down hole. Milling on packer at report time. BHA run no. 2 (cont...) Circulated at 10468.0 ft Had flow increase, SI well. SIDP=0 SICP=220 Circ gas thru choke, max annular pressure 480 psi. Circ B/U after gas bubble to surface. Open well. Influx Out of hole Milled Permanent packer at 10468.0 ft Mill on packer. Vary weight, 5K to 40K. Tried different pump strokes. Drilling off very slowly. Completed operations Able to P/U 10K over string wt. Will not go down. Pulled out of hole to 813.0 ft At BHA Pulled BHA No fish. Mill wore out. Spear grappel catch assembly broke, left part in hole. BHA Stood back BHA run no. 3 Made up BHA no. 3 Change mill and grappel, empty boot baskets. BHA no. 3 made up Serviced Top drive BHA run no. 3 (cont...) Facility Date/Time 25 May 99 Progress Report PB DS 15 Well 15-21A Page 5 Rig Nabors 9ES Date 12 July 99 06:00-10:00 10:00 10:00-11:00 11:00 11:00-11:30 11:30 11:30-15:00 15:00 15:00-20:30 20:30 20:30-21:30 21:30 21:30-23:00 23:00 23:00-23:30 23:30 23:30-06:00 23:30-01:30 01:30 01:30-05:00 05:00 05:00-06:00 Duration 4hr lhr 1/2 hr 3-1/2 hr 5-1/2 hr 1 hr 1-1/2 hr 1/2 hr 6-1/2 hr 2 hr 3-1/2 hr 1 hr Activity R.I.H. to 10150.0 ft Began precautionary measures Serviced Block line Line slipped and cut R.I.H. to 10468.0 ft At Top of packer: 10468.0 ft Milled Permanent packer at 10469.0 ft Tagged top of packer fish. Milled. P/U but will not go down. Pressuring up and torquing. Completed dressing Permanent packer Pulled out of hole to 813.0 ft At BHA Pulled BHA BHA Stood back Laid down fish Recovered seal bore extension and mill out extension to 7"x 3-1/2" crossover. Pin end or crossover milled out by carbide on bullnose. Partial fish recovered Serviced Top drive Equipment work completed BHA run no. 4 Made up BHA no. 4 BHA no. 4 made up R.I.H. to 10492.0 ft RIH and tagged top of fish. At Top of fish: 10492.0 ft Fished at 10492.0 ft Washed over fish @ 10,492'. Circ to clear annulus around fish. Pulled 350K, fish did not come free. Working fish, jarring, no pipe movement at report time. 06:00-23:00 06:00-08:30 08:30 08:30-09:00 09:00 09:00-13:00 13:00 13:00-18:00 18:00 18:00-23:00 23:00 23:00-06:00 17hr 2-1/2 hr 1/2 hr 4hr 5 hr 5hr 7 hr BHA run no. 4 (cont...) Fished at 10492.0 ft Fish came free Workpipe and jar free with 350 K. Came free after jarring up 31 feet in small increments. Pulled out of hole to 10400.0 ft Stopped: To circulate Pulled fish out of liner- 10-15 k drag. Circulated at 10400.0 ft Obtained bottoms up (100% annulus volume) Circulate well @ 7 BPM/1000psi. Nothing significant on bottoms up. Pulled out of hole to 1000.0 ft Fish at surface Laid down fish Complete fish recovered Lay down 31 joints of 3.1/2" tailpipe. Cement on last three connections. Boxes split- tight connections probably from packer milling assembly when bullnose entered tailpipe. BHA run no. 5 Facility PB DS 15 Date/Time 23:00-03:00 26 May 99 03:00 Duration 03:00-06:00 06:00-23:30 06:00-07:00 07:00 4 hr 3 hr 07:00-08:30 08:30 08:30-09:15 09:15 17-1/2 hr 1 hr 1-1/2 hr 09:15-12:15 12:15 3/4 hr 12:15-14:00 14:00 14:00-21:30 21:30 21:30-23:30 23:30 3hr 23:30-06:00 23:30-03:30 27 May 99 03:30 1-3/4 hr 7-1/2 hr 2hr 03:30-06:00 06:00-09:00 06:00-09:00 09:00 6-1/2 hr 4 hr 2-1/2 hr 09:00-09:30 09:00-09:30 09:30 3 hr 3hr Progress Report Well 15-21A Page 6 Rig Nabors 9ES Date 12 July 99 1/2 hr 1/2 hr Activity Made up BHA no. 5 BHA no. 5 made up Make up Cleanout assembly and circulate thru BHA@ 5 BPM/360 psi. R.I.H. to 8209.0 ft RIH breaking circulation every 3000 ft. BHA run no. 5 (cont...) R.I.H. to 10960.0 ft Observed loss of 5.00 klb string weight RIH. Take parameters above 7" liner. 250 klbs up, 150 klbs down. Observe liner top @ 10,490 ft. Tag up at 10,960 ft- perforations. Drilled cement to 10960.0 ft Completed operations Drill cement w/2- 3 klbs WOB, 70 RPM/12 kftlbs. Washed to 11470.0 ft On bottom Wash down - observe cement sheath @ 11,453 ft. Drillsame down to 11,470 ft- harder cement. Circulated at 11470.0 ft Hole displaced with Water based mud - 150.00 % displaced Displace wellbore to 8.9 ppg milling fluid preceeded by 50 bbl hi-vis pill. Some cement on bottoms up. Displace @ 14 BPM/2850 psi. Pulled out of hole to 10450.0 ft At Top of liner: 10450.0 ft Pulled out of hole to 500.0 ft At BHA Pulled BHA BHA Laid out L/D 15 joints HWDP jar, 9 x 6.1/2"DC's. and bumper sub. Clear rigfloor.. Electric wireline work Conducted electric cable operations Completed misrun with Junk basket/gauge ring to 10488.0 ft Run 6.16" Gauge ring, weight bar and GR/CCL. RIH. Unable to get gauge ring/junk basket inside 7" liner @ 10,488 ft. Attempt various speeds- no go. Abort run and POOH. Conducted electric cable operations R/U and run Bridge plug. RIH at report time. Electric wireline work (cont...) Conducted electric cable operations Completed run with Bridge plug from 11377.0 ft to 11377.0 ft RIH with Halliburton EZSV Bridge plug on GR/CCL.Correlate logs and set bridge plug 2.5 ft below collar @ 11,377 ft. Top zone 2 11,334 ft. ( Wireline depths).POOH. R/D Schlumberger Perform integrity test Tested Casing Pressure test completed successfully - 500.000 psi Pressure test well and perforations to 500 pis/ 30minutes- OK. Facility Date/Time PB DS 15 09:30-06:00 09:30-11:30 11:30 Duration 20-1/2 hr 2hr 11:30-17:00 5-1/2 hr 17:00 17:00-17:45 3/4 hr 17:45 17:45-18:45 1 hr 18:45 18:45-19:45 1 hr 19:45 19:45-06:00 10-1/4 hr 28 May 99 06:00-18:45 12-3/4 hr 06:00-07:30 1-1/2 hr 07:30 07:30-10:30 3 hr 10:30 10:30-11:30 1 hr 11:30 11:30-12:30 1 hr 12:30 12:30-17:00 4-1/2 hr 17:00 17:00-18:45 1-3/4 hr 18:45 Progress Report Well 15-21A Page 7 Rig Nabors 9ES Date 12 July 99 18:45-20:30 1-3/4 hr 18:45-20:30 1-3/4 hr 20:30 20:30-23:00 2-1/2 hr 20:30-23:00 2-1/2 hr 23:00 Activity BHA run no. 6 Made up BHA no. 6 BHA no. 6 made up Make up Baker Whipstock assembly with 6-1/16" mills. Check orientation and surface test MWD. R.I.H. to 10450.0 ft Began precautionary measures RIH checking MWD every 3000 ft. Set tool face Completed operations Take parameters and orientate whipstock above 7" liner. 225 klbs up/140 klbs down. R.I.H. to 11350.0 ft Stopped · To correlate depth RIH. Slight restriction @ perforated interval. Functioned downhole tools at 11387.0 ft Equipment work completed Check orientation and set whipstock anchors w/8 klbs WOB @ 11,387ft. Shear out retaining bolt with 45 klbs WOB. Milled Liner at 11383.0 ft Take paremeters- 218 klbs up, 142klbs down. Mill window from 11,365 ft @ 4 ft/hr. Once in open formation ROP @ 1 ft/hr- vary parameters without any improvement. Currently have 5 ft left to mill. BHA run no. 6 (cont...) Milled Liner at 11388.0 ft Completed operations Milled window and new fromation to 11,388 ft.window from 11,365-11,377 ft. Circulated at 11388.0 ft Hole displaced with Water based mud - 130.00 % displaced Displace well to 8.4 ppg Light Flo-pro system @ 7 bpm/1425 psi preceeded by 75 bbl vis sweep. Pulled out of hole to 10450.0 ft Stopped ' To service drilling equipment Window slick. POOH to above 7"liner. Serviced Top drive Equipment work completed Pulled out of hole to 1000.0 ft At BHA Pulled BHA BHA Laid out Lay out drill collars and inspect mills. Bottom mill in gauge with even wear on face (30%). Upper mill 1/32" undergauge, lower mill in gauge. Clear rigfloor. Wellhead work Jet wellhead Completed operations Pull wear bushing. Flush stack and function rams. BOP/riser operations - BOP stack Tested BOP stack Pressure test completed successfully - 5000.000 psi Facility PB DS 15 Date/Time 23:00-00:00 23:00-00:00 29 May 99 00:00 00:00-02:00 00:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00-06:00 06:00-07:00 07:00 07:00-08:30 08:30 08:30-10:00 10:00 10:00-10:45 10:45 10:45-12:00 12:00 12:00-12:30 12:30 12:30-14:30 14:30 14:30-06:00 30 May 99 06:00-06:00 06:00-17:30 17:30 17:30-19:00 19:00 19:00-04:30 31 May 99 04:30 Progress Report Well 15-21A Page 8 Rig Nabors 9ES Date 12 July 99 Duration 1 hr lhr 2 hr 2hr 4 hr 4 hr 24 hr lhr 1-1/2 hr 1-1/2 hr 3/4 hr 1-1/4 hr 1/2 hr 2 hr 15-1/2 hr 24 hr 11-1/2 hr 1-1/2 hr 9-1/2 hr Activity witness. Repair Repaired Brake Equipment work completed Troubleshoot locked parking brake- resolve same. BOP/riser operations - BOP stack Tested Blind / Shear ram Pressure test completed successfully - 5000.000 psi Test Blind Rams. R/D test equipment, pull test plug and install wear ring. BHA run no. 7 Made up BHA no. 7 Pick up Kick-off Assembly. BHA run no. 7 (cont...) R.I.H. to 3000.0 ft Stopped: To service drilling equipment Serviced Block line Line slipped and cut Slip and cut 80 ft drilling line. R.I.H. to 7000.0 ft Stopped: To hold safety meeting Held safety meeting Completed operations Hold Reservoir meeting to discuss drilling stratgey, HSE issues and geological objective. R.I.H. to 10400.0 ft Stopped: To hold safety meeting Held safety meeting Completed operations Repeat Reservoir meeting with oncoming crew. R.I.H. to 11388.0 ft On bottom Orientate assembly and RIH. Noproblems at window. Orientate assembly. Drilled to 11846.0 ft Time drill for 3 hours until good indication ofbeing in new hole. Slide ahead. Assembly building @ 9 deg/100'- probably due to IAB sub. Good hole conditions- tracking ECD. No drag on connections,no losses. BHA run no. 7 (cont...) Drilled to 11219.0 ft Began precautionary measures Directionally drill 6" hole and land well. Observe drags on connection @ 11,960 and 12,112'. All other downhole parmeters normal-some difficulty sliding ( increase lubetex concentration). Circulated at 12219.0 ft Obtained clean returns - 120.00 % hole volume Circulate sweep around and clean up hole while rotating/reciprocating. Increase in cuttings returns- clean up shakers. Drilled to 12378.0 ft Reached planned end of run - Directional objective met Drill ahead tracking trends. No drag, no losses. Facility Date/Time 01 Jun 99 Progress Report PB DS 15 Well 15-21A Page 9 Rig Nabors 9ES Date 12 July 99 04:30-06:00 06:00-00:30 06:00-08:00 08:00 08:00-09:00 09:00 09:00-10:00 10:00 10:00-11:30 11:30 11:30-15:30 15:30 15:30-17:00 17:00 17:00-22:30 22:30 22:30-00:30 00:30 00:30-06:00 00:30-01:00 01:00 01:00-06:00 06:00-04:30 06:00-09:30 09:30 09:30-10:30 10:30 10:30-12:00 12:00 12:00-12:30 12:30 Duration 1-1/2 hr 18-1/2 hr 2 hr 1 hr 1 hr 1-1/2 hr 4 hr 1-1/2 hr 5-1/2 hr 2 hr 5-1/2 hr 1/2 hr 5 hr 22-1/2 hr 3-1/2 hr 1 hr 1-1/2 hr 1/2 hr Activity Circulated at 12378.0 ft Circulate twice bottoms up in preparation for short trip prior to POOH for DPC logs. BHA run no. 7 (cont...) Circulated at 12378.0 ft Obtained clean returns - 200.00 % hole volume Circulate x 2 bottoms up. Some increase in cuttings with sweep. Circulated hole clean while reciprocating/rotating pipe, racking stands every hour. Pulled out of hole to 11340.0 ft At top of check trip interval POOH. Some tugs in intervals with higher doglegs( 11,800 ft). Hole in good shape. Serviced Block line Line slipped PJSM. Slip drilling line. R.I.H. to 12378.0 ft On bottom Circulated at 12378.0 ft Obtained clean returns - 200.00 % hole volume Circulate hole clean. Pulled out of hole to 11340.0 ft At Window: 11340.0 ft POOH strapping drillpipe. Pulled out of hole to 1000.0 ft Strap out of hole and drop 2.375" hollow drift with 100 ft slickline @ window. At BHA Pulled BHA BHA Laid out Lay down BHA. No Correction on Strap. Recover drift. Bit 5/4/I Tubular conveyed wireline work Held safety meeting Completed operations Ran logs on tubulars Pick up DPC Tools and load sources. RIH on drillpipe breaking circulation every 4000 ft. @ 3700' @ report time. Tubular conveyed wireline work (cont...) R.I.H. to 11025.0 ft Stopped: To circulate Circulated at 11025.0 ft Obtained clean returns - 30.00 % hole volume Circulate for 45 minutes @ 3 BPM/430 psi to ensure Connect receptacle clear. Installed Logging/braided cable equipment Equipment work completed R/U and install side entry sub and crossovers. Install sheaves. Held safety meeting Completed operations Hols Safety Meeting with Jim Denny and Dave Herbert. Facility Date/Time 02 Jun 99 03 Jun 99 Progress Report PB DS 15 Well 15-21A Page 10 Rig Nabors 9ES Date 12 July 99 12:30-13:15 13:15 13'15-21:00 21:00 21:00-21:30 21:30 21:30-02:30 02:30 02:30-04:00 04:00 04:00-04:30 04:30 04:30-06:00 04:30-06:00 06:00-06:00 06:00-13:30 13:30 13:30-14:30 14:30 14:30-15:30 15:30 15:30-16:00 16:00 16:00-06:00 Duration 3/4 hr 7-3/4 hr 1/2 hr 5 hr 1-1/2 hr 1/2 hr 1-1/2hr 1-1/2hr 24hr 7-1/2hr 1 hr 1 hr 1/2hr 14hr Activity Conducted electric cable operations On bottom Run Cable connect and latch PDWC ( Pump down wet connect) @ 4 BPM. Confirm successful latch. Ran logs on tubulars Observed loss of 3.00 klb string weight Log down. Hit resistance @ 11,925 ft. Ease logs down with difficulty to 11,975'. Log up to 11,061 ft and repeat section from 11,650'. Pull wet connect free and POOH w/cable.R/D sheaves and x/o's. Serviced Block line Line slipped Pulled out of hole to 0.0 ft At BHA Rigged down sub-surface equipment - Production logging tools Equipment work completed Serviced Top drive Equipment work completed BHA run no. 8 Made up BHA no. 8 BHA run no. 8 (cont...) R.I.H. to 11250.0 ft Stopped: To circulate RIH to above window @ 11,250 ft. Circulated at 11250.0 ft Began precautionary measures Orientate assembly and take readings for Hydualic model @ different flowrates/RPM. R.I.H. to 12235.0 ft RIH. Little resistance @ 11,960 ft. Hole in good shape. Began precautionary measures Washed to 12378.0 ft On bottom Precautionary wash to bottom. No fill. Drilled to 12678.0 ft Drill ahead 6" directional hole. No drag, no losses. ECD steady. 06:00-11:00 06:00-11:00 11:00 11:00-12:00 11:00-12:00 12:00 5 hr 5hr lhr 1 hr 12:00-06:00 12:00-06:00 18hr 18hr Returns from 11,900' showed increase in cuttings suggesting we may have had a small cuttings bed @ 11,900'. Sweep from bottoms up- clean. BHA run no. 8 (cont...) Drilled to 12840.0 ft Main engine failed - Circulate Directionally drill 6" hole. All parameters steady. Repair Repaired Main engine Equipment work completed Loose all power from Hi-line. reciprocate pipe while troubleshooting problem. Switch to rig power. BHA run no. 8 Drilled to 13378.0 ft Facility Date/Time 04 Jun 99 05 Jun 99 Progress Report PB DS 15 Well 15-21A Page 11 Rig Nabors 9ES Date 12 July 99 06:00-06:00 06:00-13:30 13:30 13:30-16:45 16:45 16:45-17:00 17:00 17:00-19:00 19:00 19:00-21:00 21:00 21:00-21:30 21:30 21:30-23:00 23:00 23:00-03:15 03:15 03:15-03:30 03:30 03:30-05:15 05:15 05:15-06:00 06:00 06:00-12:30 06:00-10:30 10:30 10:30-12:30 12:30 12:30-06:00 12:30-14:00 14:00 14:00-18:15 18:15 18:15-19:30 19:30 Duration 24 hr 7-1/2 hr 3-1/4 hr 1/4 hr 2 hr 2 hr 1/2 hr 1-1/2 hr 4-1/4 hr 114 hr 1-3/4hr 3/4hr 6-1/2hr 4-1/2hr 2 hr 17-1/2hr 1-1/2hr 4-1/4 hr 1-1/4 hr Activity steady. BHA run no. 8 (cont...) Drilled to 13760.0 ft Reached planned end of run - Section / well T.D. Drill directional 6" hole to 13,760 ft. All parameters steady, no losses, no drag on connections. Circulated at 13760.0 ft Obtained clean returns - 200.00 % hole volume Sweep hole with lo/hi vis sweep. Work / rotate pipe standing back one stand per 90 minutes. ECD dropped 0.1 ppg. Flow check Observed well static Pulled out of hole to 11340.0 ft At Window · 11340.0 ft Make short trip to window. Hole in good shape, no overpulls. Serviced Block line Line slipped and cut PJSM. Slip and cut 40' drilline. Serviced Top drive Equipment work completed R.I.H. to 13760.0 ft On bottom Circulated at 13760.0 ft Obtained clean returns - 150.00 % hole volume Sweep hole with 30 bbl Hi vis pill. Hole clean. Spot liner pill with 5% lubetex. Flow check Observed well static Pulled out of hole to 11340.0 ft At Window · 11340.0 ft No Drag- hole in good shape. Circulated at 11340.0 ft Began precautionary measures Pump dry job. Drop 2.375" hollow rabbit on 120' slickline. BHA run no. 8 (cont...) Pulled out of hole to 1000.0 ft At BHA Pulled BHA BHA Laid out Lay down BHA. Bit in good sape- 3/3/1 seals effective.. Clear rigfloor. Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment Equipment work completed R/U to run 4.1/2" liner. Hold PJSM. Ran Liner to 2897.0 ft (4-1/2in OD) Stopped · At sub-assembly Make up shoetrack- bakerlok same. Test floats.- OK. Install Radioactive tag and run liner. 71 joints, 2 pups, 12.6 lb/fi, IBT, L-80. Installed Liner hanger Equipment work completed Facility Date/Time 06 Jun 99 Progress Report PB DS 15 Well 15-2 lA Page 12 Rig Nabors 9ES Date 12 July 99 19:30-02:00 02:00 02:00-02:30 02:30 02:30-04:30 04:30 04:30-06:00 Duration 6-1/2 hr 1/2 hr 2 hr 1-1/2 hr Activity klbs up/down. Circulate 56 bbls @ 5.6 BPM/200 psi. Ran Liner to 11365.0 ft (4-1/2in OD) At Window: 11365.0 ft Circulated at 11365.0 ft String displaced with Water based mud - 100.00 % displaced Circulate liner contents at window @ 7 BPM/790 psi. Up weight 215 klbs, down 125 klbs. Ran Liner to 13760.0 ft (4-1/2in OD) On bottom Run liner into open hole- no resistance. Tag bottom on depth. PFU 260 klbs, S/O 120 klbs. Circulated at 13760.0 ft Circulate and condition pipe. Pump first 100 bbls @ 3 BPM. Currently circulating @ 5 BPM/1000 psi. 06:00 06:00-12:45 06:00-09:00 09:00 09:00-10:00 10:00 10:00-10:30 10:30 10:30-11:30 11:30 11:30-12:00 12:00 12:00-12:45 12:45 12:45-06:00 12:45-16:00 6-3/4 hr 3 hr 1 hr 1/2 hr lhr 1/2 hr 3/4 hr 17-1/4 hr 3-1/4 hr Pup Joint A = 13,124'- 13,143', pupjt B = 12,492'-12,513'. RA tag @ 13,551' Began precautionary measures Cement: Liner cement Circulated at 13760.0 ft Obtained clean returns - 200.00 % hole volume Circulate and condition wellbore for cementing @ 5 BPM/1150 psi- no losses. Unable to reciprocate- well tending to pack-off. Park pipe. Batch mixed slurry - 67.000 bbl Batch slurry mixed Batch Mix 15.7 ppg slurry- 314 sacks G cement w/2% KCL, 0.34% FL-33, 0.6% CD-32, 0.15% A2, 0.5% Gel, 1.75 ghs BA 86L, 1 gps FP-12L, 0.2% FP-12L and 0.07% R1. Circulate well while batch mxing. Pumped Water based mud spacers - volume 20.000 bbl Required volume of spacer pumped Pump 2 bbls FW w/KCL- test lines to 4500 psi. Pump 3 more bbls and 20 bbls Viscosified Spacer @ 9.3 PPg. Displaced slurry - 148.000 bbl Plug bumped Pump 67 bbls slurry, drop dart - good flag. Displace with 148 bbls seawater- no dart shear seen and plug bumped 6 bbls early on calculation. Full Returns. CIP @ 11.20 am. Displace @ 6 BPM/1400 psi. Functioned Liner hanger Equipment work completed Check hanger set- OK. Pressure up to 4,200 psi and set top packer. Release pressure. Floats held. Rotate r/tool out and with 800 psi pull out liner. Circulate 5 minutes and s/o 70 klbs to ensure packer set- good. Reverse circulated at 10794.0 ft Obtained clean returns - 100.00 % hole volume Reverse circulate well @ 5.2 BPM/1000 psi. Observe approximately 28 bbls of cement contaminated fluid from bottoms up. Circulate until clean. Pull Drillpipe, 4in O.D. Circulated at 10794.0 ft Facility Date/Time 07 Jun 99 08 Jun 99 PB DS 15 16:00 16:00-23:00 23:00 23:00-00:00 00:00 00:00-06:00 06:00-08:30 06:00-08:30 08:30 08:30-14:00 08:30-09:00 09:00 09:00-14:00 14:00 14:00-06:00 14:00-14:15 14:15 14:15-21:30 21:30 21:30-23:00 23:00 23:00-05:00 05:00 05:00-06:00 06:00 06:00-09:00 06:00-08:30 08:30 08:30-09:00 09:00 09:00-14:00 09:00-14:00 Progress Report Well 15-21A Page 13 Rig Nab@rs 9ES Date 12 July 99 Duration 7 hr 1 hr 6hr 2-1/2 hr 2-1/2 hr 5-1/2 hr 1/2 hr 5 hr 16hr 1/4 hr 7-1/4 hr 1-1/2 hr 6 hr 1 hr 3hr 2-1/2 hr 1/2 hr 5 hr 5hr Activity Hole displaced with Seawater - 150.00 % displaced Pull Back one stand and circulate well to seawater @ 7 BPM/500 psi. Returns not clean but seawater plant shutdown. Laid down 6336.0 ft of 4in OD drill pipe Stopped: To pressure test Tested Liner - Via annulus and string Pressure test completed successfully - 3000.000 psi Test well bore to 3000 psi for 30 minutes- 8.2 bbls pumped / returned- good test. Laid down 4430.0 ft of 4in OD drill pipe Continue to lay down all tubulars from derrick ready for rig move. Pull Drillpipe, 4in O.D. (cont...) Laid down 3000.0 ft of 4in OD drill pipe 344 joints laid out Slickline wireline work Serviced Block line Line slipped Conducted slickline operations on Slickline equipment - Tool run Completed run with Junk basket/gauge ring from 0.0 ft to 10800.0 ft R/U and run 6" gauge ring to top of 4.1/2" liner @ 10,800 ft ( slickline depth). Observe top of 7" liner @ 10,512' ( slickline ). POOH and R/D. Run Gas lift completion, 4-1/2in O.D. Held safety meeting Completed operations Ran Tubing to 10793.0 ft (4-1/2in OD) At Top of liner: 10793.0 ft Run 4.1/2", L-80, IBT tubing w/3 x GLM's and tag on depth @ 10,793'. Enter tieback sleeve. Space out tubulars Completed operations Pull back and space out tubulars- prepare for circulating. Reverse circulated at 10793.0 ft Obtained req. fluid properties - 150.00 %, hole vol. Reveerse circulate well to clean, filtered inhibited brine @ 3 BPM/110 psi. Rigged up Tubing hanger Began precautionary measures Make up tubing hanger and landing joint- prepare to land out. Run Gas lift completion, 4-1/2in O.D. (cont...) Tested Tubing hanger Landed tubing hanger and tested. Tubing hanger leaked. Pulled and reran hanger with upper seal installed. Upper seal assembly came off. Suspended pressure test on Seal assembly, observed leak Installed Tubing hanger Landed tubing without seal assembly. Set BPV. Eqpt. work completed, running tool retrieved Nipple down BOP stack Rigged down BOP stack Facility Date/Time 09 Jun 99 PB DS 15 Progress Report Well 15-21A Page 14 Rig Nabors 9ES Date 12 July 99 14:00 14:00-20:00 14:00-14:30 14:30 14:30-16:30 16:30 16:30-17:00 17:00 17:00-18:30 18:30 18:30-19:00 19:00 19:00-20:00 20:00 20:00-22:00 20:00-21:00 21:00 21:00-22:00 22:00 22:00-23:30 22:00-23:30 23:30 23:30-00:00 23:30-00:00 00:00 00:00-06:00 00:00-00:30 00:30 Duration 6 hr 1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 2 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 6 hr 1/2 hr Activity Equipment work completed Wellhead work Installed Seal assembly Equipment work completed Installed Adapter spool Equipment work completed Tested Tubing hanger Pressure test completed successfully - 5000.000 psi Tubing hanger seals tested to 5000 psi, OK. Installed Xmas tree Equipment work completed Tested Xmas tree Pressure test completed successfully - 5000.000 psi Removed Hanger plug Pulled tree test plug and BPV. L/D lubricator. Equipment work completed Run Gas lift completion, 4-1/2in O.D. Set packer at 10735.0 ft with 3500.0 psi Dropped ball. Pressure to 3500 psi to set packer. Hold 3500 psi for 30 min tubing test. Bled tubing pressure to 2000 psi. Packer set at 10735.0 ft Tested Permanent packer Pressure annulus to 3000 psi for packer and casing test for 30 min. Tested OK. Bled off tubing pressure and sheared RP shear. Pressure test completed successfully - 3000.000 psi Fluid system Freeze protect well - 155.000 bbl of Diesel R/U HBR and pumped freeze protect diesel. Completed operations Wellhead work Installed Hanger plug Installed BPV. Eqpt. work completed, running tool retrieved Fluid system Freeze protect well - 155.000 bbl of Diesel U-tube diesel. Completed operations Rig Released for move to DS B-06 at 0030 hrs 6/9/99. DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 6/13/1999: 6/14/1999: 6/15/1999: 6/16/1999: 6/17/1999: 6/18/1999: 6/19/1999: 6/20/1999: 6/21/1999: MIRU CTU. PT'd B OPE. RIH w/BHA & milled Cement stringers f/13445' to 13673.5' MD. to 13686' MD. Reamed/bacla'eamed. Drilled to 13760' & POOH w/BHA. RIH & tagged BTM @ 13761' MD. Drilled to 13780' & PUH to 13600'. Performed LOT to EMW of 9.3 ppg. Drilled ahead to 14125'. Drilled to 14240' MD. Reamed/backreamed f/13970' to 14000'. Drilled to 14445'. Drilled to 14547' MD & POOH. RIH & reamed OH to 13772'. POOH ~v/BHA. RIH & reamed to BTM. Drilled to 14709'. Short trip to 12080'. Drilled to TD @ 14720' MD. Prep'd OH for liner. POOH. RIH w/2-7/8" FL4S liner & landed it @ 14718' in the 3-5/8" OH. TOL = 13514'. Pressured up & unstung f/ liner w/CT. Re-attached. Mixed Cement. Pumped 10 bbls of 15.8 ppg Class G Cement to cement liner in place. Bumped wiper plug. Lost 50% returns while pumping Cement. Contaminated Cement w/Biozan & jetted contaminated Cement f/wellbore. POOH w/CT. RIH w/BHA & conditioned OH. POOH w/BHA. RIH w/Memory CNL/GR/CCL tools & logged well. Displaced liner to new mud. POOH w/logging tools. PT"d liner lap to 2000 psi for 15 min - bled off to 300 psi. RIH w/perforation guns to PBTD @ 14714' MD. Shot 184' of Initial Perforations @ the following intervals: 14408'- 14507' (Zone 1) 14543'- 14558' (Zone 1) 14608' - 14678' (Zone 1) Used 2" carriers. All shots @ 4 SPF & overbalanced press. POOH w/guns. ASF. FP'd well. RD. ND BOPE. NUtree. 6/22/1999: Cont. RDMOL. I V 85OO 8600 8700 8800 89OO 9000 ARCO Alaska, Inc. W~ll : 15-21A, 50-029-2050~-01 Location : North S[ope, A[askc Structure · D.S. 15 Field : Prudhoe Boy <- West (feet) 87oo 8600 s~oo 8400 ~300 ~200 ~00 sooo 49oo 48oo 47oo 4600 4~00 44oo 4300 42oo 4700 ~ ) ~ i ~ i ~ i I ~ , , i , ~ i : ~ i I 8500 15-21ehs ® Projected to TD 8400 ORIGINAL ,RECEIVED , ~i IN 2. 5 1999 A~aska0it&Gas Cons, TD for Rotary Sidetrock Tie on ted to TD _ 15-21 ehs i i i i i i i i ~ i i ~ i ~ i i i i i i i i i i i i i i i , i 7800 7900 8000 81 O0 8200 8300 8400 8500 8600 8700 8800 8900 9000 91 O0 9200 Verficol Section (feet) -> Azimuth 552.00 with reference 0.00 N, 0.00 E from 15-21 Brij Potnis Dote plotted: 2,~-dun-lg99 Pict Reference in 15-21A. ' Coordlnotea ore in felt reference 15-21. True Vertlcol Depths ore reference RKB - MSL = 67.O I't. --- Beker Hughee INTEO --- 8300 8200 8100 8coo 7900 7800 7700 76OO 7500 7400 7300 ARCO Alaska, Inc. D.S. 15 15-21A 15-21 Prudhoe Bay North Slope, Alaska SURVEY L I STING by Baker Hughes INTEQ Your ref : 15-21A Our ref : svy174 License : 50-029-20503-01 Date printed : 23-Jun-1999 Date created : 23-Jun-1999 Last revised : 23-Jun-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 675901.341,5961480.369,999.00000,N Slot location is n70 17 57.556,w148 34 28.882 Slot Grid coordinates are N 5961099.800, E 675980.800 Slot local coordinates are 382.35 S 70.53 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 15,15-21A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 15-21A Last revised : 23-Jun-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 13668.35 89.01 314.19 8705.07 7400.80N 4805.89W 7.71 7997.63 671003.30 5968385.60 13693.30 89.17 314.55 8705.47 7418.25N 4823.73W 1.58 8017.38 670985.06 5968402.62 13700.00 89.21 314.65 8705.56 7422.95N 4828.50W 1.61 8022.71 670980.18 5968407.21 13760.00 89.60 315.52 8706.19 7465.44N 4870.86W 1.59 8070.67 670936.84 5968448.69 13789.00 90.50 319.70 8706.16 ~486.85N 4890.40W 14.74 8094.60 670916.80 5968469.64 13823.00 92.30 324.00 8705.33 7513.57N 4911.39W 13.71 8123.98 670895.19 5968495.86 13861.00 92.30 326.90 8703.81 7544.84N 4932.92W 7.63 8157.94 670872.94 5968526.61 13892.00 91.60 329.70 8702.75 7571.20N 4949.20W 9.31 8186.31 670856.05 5968552.58 13922.00 89.10 334.30 8702.57 7597.68N 4963.28W 17.45 8214.49 670841.35 5968578.72 13956.00 86.80 339.30 8703.78 7628.89N 4976.66W 16.18 8247.27 670827.25 5968609.62 13984.00 88.30 341.30 8704.98 7655.23N 4986.09W 8.92 8274.66 670817.20 5968635.72 14014.00 89.30 344.30 8705.61 7683.88N 4994.96W 10.54 8304.26 670807.67 5968664~15 14055.00 89.80 346.20 8705.93 7723.52N 5005.40W 4.79 8344.98 670796.31 5968703.54 14086.00 86.10 350.60 8707.04 7753.86N 5011.63W 18.54 8375.88 670789.37 5968733.72 14114.00 82.90 355.20 8709.73 7781.50N 5015.07W 19.95 8403.74 670785.28 5968761.27 14146.00 82.90 0.00 8713.68 7813.22N 5016.40W 14.88 8435.33 670783.21 5968792.95 14174.00 79.30 0.00 8718.01 7840.88N 5016.40W 12.86 8462.72 670782.56 5968820.60 14203.00 77.40 0.90 8723.87 7869.28N 5016.18W 7.22 8490.81 670782.12 5968848.99 14230.00 72.70 0.60 8730.83 7895.36N 5015.84W 17.44 8516.59 670781.85 5968875.07 14259.00 67.60 359.00 8740.68 7922.62N 5015.93W 18.34 8543.60 670781.12 5968902.33 14291.00 64.20 357.50 8753.74 7951.81N 5016.81W 11.45 8572.63 670779.55 5968931.49 14319.00 61.90 353.10 8766.44 7976.68N 5018.85W 16.24 8597.54 670776.94 5968956.30 14355.00 59.00 350.20 8784.19 8007.66N 5023.38W 10.68 8628.85 670771.68 5968987.16 14382.00 56.10 345.70 8798.68 8029.93N 5028.12W 17.69 8651.57 670766.42 5969009.31 14409.00 57.30 341.70 8813.51 8051.58N 5034.46W 13.15 8673.89 670759.57 5969030.81 14444.00 61.40 345.70 8831.36 8080.48N 5042.89W 15.29 8703.67 670750.48 5969059.49 14474.00 63.20 345.00 8845.30 8106.17N 5049.60W 6.35 8730.05 670743.16 5969085.02 14504.00 65.80 344.50 8858.22 8132.29N 5056.73W 8.80 8756.91 670735.43 5969110.'97 14530.00 68.50 342.40 8868.31 8155.26N 5063.56W 12.78 8780.60 670728.06 5969133.76 14561.00 71.00 343.00 8879.04 8183.02N 5072.20W 8.27 8809.30 670718.77 5969161.32 14587.00 72.10 349.20 8887.28 8206.95N 5078.12W 23.01 8833.82 670712.29 5969185.10 14618.00 74.70 345.00 8896.14 8235.90N 5084.76W 15.46 8863.41 670704.98 5969213.88 14651.00 75.50 347.50 8904.62 8266.87N 5092.33W 7.71 8895.13 670696.68 5969244.67 14687.00 77.80 351.60 8912.94 8301.31N 5098.68W 12.79 8930.12 670689.53 5969278.94 14720.00 76.50 355.40 8920.28 8333.27N 5102.32W 11.90 8962.27 670685.14 5969310.81 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 15-21 and SSTVD from RKB - MSL = 67.0 ft. Bottom hole distance is 9771.23 on azimuth 328.52 degrees from wellhead. Vertical section is from wellhead on azimuth 352.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 15,15-21A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 15-21A Last revised : 23-Jun-1999 Comments in wellpath MD SSTVD Rectangular Coords. Comment 13668.35 8705.07 7400.80N 4805.89W Tie on 14720.00 8920.28 8333.27N 5102.32W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 15-21ehs 670800.000,5969400.000,999.00 8945.00 8419.75N 4985.40W 2-Jun-1999 ~E,.'f'~R mm,m~[~[qi~ Anadrill 05-June- 1999 A summary of Anadrill's performance on DS 15-21A has been compiled. SERVICES PROVIDED: MVO) D&I AIM VPWD IMPulse GR/Resistivity 11338.7 ft to 13760.0 ft 11338.7 ftto 13760.0 ft 11338.7 ft to 13760.0 ft 11338.7 ftto 13760.0 ft OPERATING STATISTICS: MWD operating time (over 180 GPM) for the well was 114.3 hours. MWD footage of 2421.0 ft' was accomplished in 3 MWD runs. LWD time below the rotary for this well was 175.4 hours. LWD pumping time was 114.3 hours. LWD footage of 2421.0 was accomplished in 3 runs. DIRECTIONAL ORIGINAL RECEWED 14 1999 The Directional Driller used a total of 77 MWD surveys. Continuous Inclination was used on the entire well. LESSONS LEARNED: VPWD was run the entire well, it provided real-time updates to ensure that good drilling practices and hole cleaning practices were used. ANADRILL appreciates the opportunity to provide ARCO Alaska / Shared Services Drilling with MWD/LWD services. Nate Rose Cell Manager 9ES Joey LeBlanc Field Service Manager, AK Client ................... : ARCO Alaska Inc. Field .................... : Prudhoe Bay ANADRILL SCHLUMBERGER Survey report Well ..................... : DS 15-21A Spud date ................ : 19 May 1999 API number ............... : 50-029-20503-01 'i!Last survey date ......... : 04-Jun-99 /Engineer ................. : Rose Rig: .................... : Nabors 9ES State: .................. : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller Pipe Tally GL above permanent ....... : 32.20 ft KB above permanent ....... : Top Drive DF above permanent ....... : 59.78 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 314.38 degrees 4-Jun-1999 16:08:39 Page 1 of 4 ORIGINAL Total accepted surveys...: 77 MD of first survey ....... : 11342.78 ft MD of last survey ........ : 13760.00 ft RECEIVSD ,jLIN 'i 4 !999 Geomagnetic data Magnetic model ........... : BGGM version 1998 Magnetic date ............ : 26-May-1999 Magnetic field strength..: 1146.69 HCNT Magnetic dec (+E/W-) ..... : 27.76 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria Reference G .............. : 1002 68 mGal Reference H .............. : 1146 69 HCNT Reference Dip ............ : 80 74 degrees Tolerance of G ........... : (+/-) 2 50 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 45 degrees Corrections Magnetic dec (+E/W-) ..... : 27.76 degrees Grid convergence (+E/W-) .: 0.00 degrees Total az corr (+E/W-) .... : 27.76 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [ (c) 1999 Anadrill IDEAL ID6 OB 70] A_NADRILL SCHLUMBERGER Survey Report 4-Jun-1999 16:21:18 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical # depth angle angle length depth section - (ft) (deg) (deg) (ft) (ft) (ft) 1 11342.78 34.28 3.28 0.00 8495.17 6473.78 2 11365.00 34.25 3.28 22.22 8513.53 6482.01 3 11377.00 36.03 1.66 12.00 8523.35 6486.62 4 11392 . 84 37 . 04 0 . 10 15 . 84 8536 . 07 6493 . 11 5 11422.21 40.00 358.40 29.37 8559.05 6506.08 6 11453.65 42.99 356.80 7 11485.55 45.84 355.20 8 11515.70 48.54 353.50 9 11547.28 51.18 351.90 10 11578.51 54.07 350.28 31.44 31.90 30.15 31.58 31.23 11 11607.03 57.35 349.97 12 11638.60 60.23 349.96 13 11669.71 63.27 349.15 14 11699.96 66.21 347.25 15 11732.18 69.33 347.23 28.52 31.57 31.11 30.25 32.22 16 11763.57 71.79 345.81 17 11794.99 74.11 341.08 18 11826.22 75.96 336.56 19 11856.70 77.79 335.63 20 11888.86 80.01 331.83 31.39 31.42 31.23 30.48 32.16 21 11920.54 81.32 329.53 22 11952.37 82.77 325.29 23 11981.63 85.23 321.50 24 12013.27 86.26 319.17 25 12043.86 86.88 318.28 31.68 31.83 29.26 31.64 30.59 26 12072.20 87.70 317.73 27 12107.72 88.49 313.54 28 12138.87 88.87 312.43 29 12200.39 90.27 312.04 30 12231.14 90.51 310.22 28.34 35.52 31.15 61.52 30.75 8582.60 8605.38 8625.87 8646.23 8665.18 8681.25 8697.60 8712.33 8725.24 8737.42 8747.87 8757.09 8765.16 8772.08 8778.27 8783.41 8787.82 8790.88 8793.23 8795.06 8796.40 8797.58 8798.29 8798.76 8798.55 Displ Displ Total At DLS Srvy +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (deg) 100f) type 5720.84 -3459.48 5733.33 -3458.76 5740.23 -3458.47 5749.66 -3458.33 5767.94 -3458.57 6521.26 6537.95 6554.91 6573.85 6593.75 5788.75 -3459.45 5811.02 -3461.02 5833.02 -3463.20 5856.97 -3466.28 5881.48 -3470.13 6612.87 6634.82 6657.22 6679.95 6705.00 5904.69 -3474.17 5931.27 -3478.87 5958.22 -3483.84 5985.00 -3489.44 6014.08 -3496.03 6730.06 6756.31 6783.77 6811.35 6841.12 6042.86 -3502.93 6071.64 -3511.49 6099.76 -3522.40 6126.90 -3534.43 6155.19 -3548.39 6871.12 6901.83 6930.56 6961.94 6992.39 6182.44 -3563.70 6208.99 -3580.68 6232.35 -3598.03 6256.63 -3618.16 6279.58 -3638.31 7020.64 7056.12 7087.25 7148.73 7179.42 6300.62 -3657.25 6325.99 -3682.06 6347.23 -3704.85 6388.58 -3750.39 6408.80 -3773.55 6685.51 6695.83 6701.58 6709.59 6725.39 6743.70 6763.62 6783.65 6805.82 6828.88 6850.93 6876.23 6902.00 6927.94 6956.39 6984.75 7013.95 7043.75 7073.26 7104.75 7136.00 7167.49 7196.38 7227.49 7257.44 7285.14 7319.55 7349.37 7408.06 7437.23 328.84 328.90 328.93 328.97 329.05 329.14 329.22 329.30 329.38 329.46 329.53 329.61 329.68 329.76 329.83 329.90 329.96 330.00 330.02 330.04 330.04 330.03 330.00 329.96 329.91 329.87 329.80 329.73 329.59 329.51 0.00 0.14 16.74 8.66 10.70 10.09 9.60 9.86 9.21 10.13 11.54 9.12 10.04 11.26 9.68 8.92 16.17 15.18 6.70 13.49 8.27 13.96 15.38 8.03 3.54 3.48 12.00 3.77 2.36 5.97 TIP MWD M MWD M MWD M MWD M MWD M MWD M MWD M MWD M MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type Proj Proj Proj Proj Proj Proj Proj Proj 6 - axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)1999 A~adrill IDEAL ID6 OB 65] -- -- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 12261.68 88.52 308.97 32 12294.07 88.04 307.40 33 12321.36 88.87 307.89 34 12359.59 87.60 307.76 35 12395.04 88.18 308.26 36 12454.03 91.89 309.70 37 12487.62 93.29 310.36 38 12518.98 93.16 311.94 39 12546.56 92.54 312.70 40 12581.05 90.31 316.31 41 12613.00 90.38 316.82 42 12640.14 89.62 317.33 43 12675.16 89.97 315.97 44 12706.10 89.01 315.32 45 12733.34 88.22 313.83 46 12768.49 87.84 316.31 47 12800.21 88.22 315.35 48 12825.88 88.83 315.34 49 12862.30 92.91 314.30 50 12893.77 93.47 315.28 51 12919.61 93.60 315.69 52 12955.91 93.50 314.99 53 12987.16 92.95 314.08 54 13014.44 93.88 314.89 55 13047.13 93.67 314.77 56 13080.73 94.94 314.69 57 13107.71 95.22 315.22 58 13143.02 94.50 314.52 59 13174.66 94.80 315.45 60 13201.95 94.64 316.29 30.54 32.39 27.29 38.23 35.45 58.99 33.59 31.36 27.58 34.49 31.95 27.14 35.02 30.94 27.24 35.15 31.72 25.67 36.42 31.47 25.84 36.30 31.25 27.28 32.69 33.60 26.98 35.31 31.64 27.29 4-Jun-1999 16:21:18 Page 3 of 4 TVD Vertical Displ Displ Total At DLS Srvy depth section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 8798.81 8799.78 8800.51 8801.69 8803.00 8802.96 8801.44 8799.68 8798.31 8797.45 8797.26 8797.26 8797.38 8797.66 8798.32 8799.53 8800.62 8801.28 8800.72 8798.97 7209.85 7242.04 7269.13 7307.09 7342.30 6428.26 -3797.08 6448.28 -3822.53 6464.94 -3844.13 6488.37 -3874.31 6510.19 -3902.22 7401 7434 7465 7493 7527 .02 .47 .73 .26 .73 6547.29 -3948.07 6568.87 -3973.77 6589.47 -3997.34 6608.02 -4017.71 6632.18 -4042.29 7559 7586 7621 7652 7679 .66 .77 .76 .69 .92 6655.38 -4064.26 6675.25 -4082.74 6700.72 -4106.78 6722.84 -4128.41 6741.95 -4147.81 7715 7746 7772 7808 7840 .04 .74 .39 .80 .22 6766.82 -4172.61 6789.56 -4194.70 6807.81 -4212.74 6833.48 -4238.56 6855.61 -4260.86 7866 7902 7933 7960 7993 .01 .23 .43 .66 .28 6874.00 -4278.94 6899.77 -4304.41 6921.66 -4326.65 6940.74 -4346.08 6963.73 -4369.21 8026 8053 8088 8120 8147 .78 .66 .84 .37 .56 6987.31 -4393.02 7006.30 -4412.03 7031.12 -4436.97 7053.42 -4459.27 7072.94 -4478.21 8797.38 8795.13 8793.37 8791.75 8789.60 7465.95 7496.13 7521.49 7557.07 7590.12 329.43 329.34 329.26 329.16 329.06 7645.54 7677.30 7707.13 7733.56 7766.98 328.91 328.83 328.76 328.70 328.64 7798.22 7824.82 7859.09 7889.26 7915.70 328.59 328.55 328.50 328.45 328.40 7949.88 7980.83 8005.84 8041.26 8071.83 328.34 328.29 328.25 328.19 328.14 8096.99 8132.33 8162.67 8189.15 8220.92 328.10 328.04 327.99 327.95 327.89 8253.55 8279.75 8314.04 8344.80 8371.43 327.84 327.80 327.75 327.70 327.66 8787.07 8784.69 8781.69 8779.13 8776.88 7.69 5.07 3.53 3.34 2.16 6.75 4.61 5.05 3.55 12.30 1.61 3.37 4.01 3.75 6.19 7.13 3.25 2.38 11.56 3.58 1.66 1.94 3.40 4.52 0.74 3.79 2.21 2.84 3.08 3.12 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)1999 Anadrill IDEAL ID6 OB 65] ANADRILL SCHLUMBERGER Survey Report 4-Jun-1999 16:21:18 Page 4 of 4 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 61 13236.70 91.03 316.19 62 13267.89 90.76 316.18 63 13296.46 90.58 314.05 64 13329.98 90.41 314.41 65 13361.32 89.28 314.76 Course length (ft) 34.75 31.19 28.57 33 .52 31.34 66 13388.93 89.18 314.20 67 13423.25 89.55 314.67 68 13454.88 89.83 315.63 69 13481.35 90.75 316.26 70 13517.03 91.10 316.72 27.61 34 .32 31.63 26.47 35.68 71 13548.50 91.47 315.30 72 13575.33 91.82 316.00 73 13609.99 92.43 315.50 74 13641.43 90.62 315.50 75 13668.35 89.01 314.19 31.47 26.83 34 .66 31.44 26.92 76 13698 . 00 89.21 315 . 52 Projected to TD 77 13760 . 00 89.60 315 . 52 29.65 62 .00 TVD depth (ft) 8775.16 8774.68 8774.34 8774.05 8774.14 8774.51 8774.89 8775.06 8774.93 8774.35 8773.64 8772.87 8771.59 8770.75 8770.84 8771.30 8771.94 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 8182.24 8213.41 8241.98 8275.50 8306.83 8334.44 8368.76 8400.39 8426.84 8462.50 8493.94 8520.76 8555.38 8586.80 8613.72 8643.37 8705.35 7098.00 -4502.21 8405.44 327.61 7120.50 -4523.80 8436.01 327.57 7140.74 -4543.96 8463.91 327.53 7164.12 -4567.98 8496.53 327.48 7186.12 -4590.30 8527.08 327.43 7205.46 -4609.99 8553.99 327.39 7229.49 -4634.50 8587.44 327.34 7251.91 -4656.81 8618.36 327.29 7270.94 -4675.21 8644.31 327.26 7296.81 -4699.77 8679.36 327.22 7319.45 -4721.62 8710.22 327.17 7338.62 -4740.37 8736.50 327.14 7363.43 -4764.54 8770.46 327.09 7385.85 -4786.57 8801.25 327.05 7404.83 -4805.65 8827.56 327.02 7425.74 -4826.67 8856.54 326.98 7469.98 -4870.11 8917.31 326.90 10.39 0.87 7.48 1.19 3 .77 2.06 1.74 3.16 4 .21 1.62 4.66 2.92 2.28 5.76 7.71 4.54 0.63 MWD MWD MWD MWD . MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Proj [(c) 1999 Anadrill IDEAL ID6 OB 65] MEMORANDUM State of Alaska .~aska Oil and Gas Conservation Commission TO: Bob Christenson~'-/ DATE: May 20, 1999 Chairman THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor 5'-/¢_r Iq ~) FROM: Lou Grimaldi,~¢~. SUBJECT: Petroleum InslSector AESJETGF.DOC BOP Test, Nabors #9ES Arco well #DS 15-21A Prudhoe Bay Unit PTD #99-~ Non-Confidential Thursday, May 20, 1999; I witnessed the initial BOP test on Nabors rig #9ES drilling Arco well #15-21A in the Prudhoe Bay field. The rig was ready to test when I arrived. The BOPE functioned properly and held its respective pressure tests. During the Choke Manifold test I noticed the manual choke was closed, I requested the choke be opened and the valves downstream be retested. All valves on the manifold passed and the test was concluded. The rig and its surrounding area were clean and provided for good access. SUMMARY: I witnessed the weekly BOP test on Nabors 9ES, No failures observed. 2 ½ hours. Attachments: AESJETGF.XLS cc; Shared Services drilling NON-CONFIDENTIAL Nabors 9ES STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Ddg Contractor: Nabors ~ Operator: Arco Well Name: 15-21A Casing Size: Test: Initial X Workover: Rig No. Set @ Weekly Other 9ES PTD# 98-0239 Rep.: John Rail Rig Rep.: Pual Smith Location: Sec. 22 T. DATE: Rig Ph.# 5/2O/99 659-4144 11N R. 14 E Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P Well Sign Dd. Rig Hazard Sec. BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/2500 I 250/5,000 1 1 1 2 2 MUD SYSTEM: Visual Tdp Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P P/F Alarm P P P P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure I 250/5,000 1 1 I Functioned P/F CHOKE MANIFOLD: No. Valves 14 No. Flanges 32 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure 250/5,000 P/F Functioned ACCUMULATOR SYSTEM: System Pressure 2,850 I P Pressure After Closure 1,750 I P 200 psi Attained AfterCIosure min's 22 sec. System Pressure Attained 2 rain's 5 sec. Blind Switch Covers: Master: P Remo----'~ P Nitgn. Btl's: Four Bottles at 2200 TEST RESULTS Number of Failures: 0 ,TestTime: 2,5 Hours, Number of valves teste 21 Repair or replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax NO. 276,7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test. Ensure chokes open during choke manifold test. Distribution: odg-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector I STATE WITNESS REQUIRED? YES __. X ._ NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Nabors 9ES Aesjetgf. xls Lou Grimaldi Revised 3/30/99 by L.G. 5/21/99 TONY KNOWLE$, GOVEFINOI~ ~KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 1, 1999 Dan Stone Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re.' Prudhoe Bay Unit 15-21A ARCO Alaska, Inc. Permit No: 99-029 Sur Loc: 382'SNL, 80'EWL, SEC. 22, T11N, R14E, UM Btmhole Loc. 275YNSL, 4898~NEL, SEC. 09, T1 IN, R14E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. Thc permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '--- STATE OF ALASKA --" ALASKA ,~,t~L AND GAS CONSERVATION COiv,,CllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [~Redrill Ilb. Typeofwell [-] Exploratory I--IStratigraphicTest [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 67.7' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028303 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 382' SNL, 80' EWL, SEC. 22, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 932' NSL, 3944' WEL, SEC. 09, T11N, R14E, UM 15-21A Attotal depth 19. Approximate spud date Amount $200,000.00 2755' NSL, 4898' WEL, SEC. 09, T11N, R14E, UM 04/01/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028304, 382'I No Close Approach 2560 13736' MD / 8745' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11345' Maximum Hole Angle 89.8° Maximum surface 2600 psig, At total depth (TVD) 8249' / 3425 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-M 2950' 10786' 8019' 13736' 8813' 325 sx Class 'G' 3-3/4" 2-7/8" 6.16# L-80 FL4S 1230' 13536' 8812' 14765' 9013' 50 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary FCC to 11750' MD (08/27/95) ' ''' Total depth: measured 11860 feet Plugs (measured) ;' ~. ~ /:.,,.? ,; '" O 'i'3 ~'.'. true vertical 8923 feet Effective depth: measured 11750 feet Junk (measured) true vertical 8832 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 300 sx Permafrost 110' 110' Surface 2963' 13-3/8" 3200 sx Fondu, 900 sx PF II 3030' 2675' Intermediate Production 10771' 9-5/8" 700 sx Class 'G', 300 sx PF 'C' 10838' 8065" Liner 1349' 7" 725 sx Class 'G' 10520' - 11869' 7787' - 8930' Perforation depth: measured 11658' - 11671 ', 11689' - 11691 ', 11694' - 11705' true vertical 8755' - 8765', 8781' - 8782', 8785' - 8794' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Smith, 564-5026 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~__-------~_ ~-'~, ~C~_~~ Dan Stone Title Senior Drilling Engineer Date Commission Use Only Permi~,~mber ] APl Number ] ApprovalDate See cover letter · -- Z ~' 50-029-20503-01 ,~-- .~ .-- ¢ ¢ for other requirements Conditions of Approval: Samples Required I-lYes ~No Mud Log Required []Yes I~No Hydrogen Sulfide Measures I--lYes J~No Directional Survey Required [~Yes []No Required Working Pressure for DOPE I--I 2K; ~ 3K; E] 4K; I-I 5K; I--I 10K; I-'115K Other: by order of Commissioner the commission Approved By Robert N Form 10-401 Rev. 12-01-85 Submit In Triplicate ]Well Name: [DS 15-2IA I Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: Target #1 Start: Total Depth rig 9ES Total Depth CTD Rig 3S 4897' FSL, 5210' FEL, Sec. 22, T1 IN, R14E 932' FSL, 3944' FEL, Sec. 9, TI IN, R14E X = 671800 Y= 5967600 Z = 8740' TVDss 1793' FSL, 4822' FEL, Sec. 9, T1 iN, R14E X = 670900 Y =5968440 Z= 8745' TVDss 2755' FSL, 4898' FEL, Sec. 9, TI IN, R14E X = 670800 Y =5969400 Z= 8945' TVDss ]AFE Number: 14J0410 ]Rig: I Nabors 9ES Estimated Start Date: 1 4/1/99I complete:Operating days to 121 I [MD I 13736' I TVDss: [ 8745' I KBE: 167.7' I Well Design (conventional, slim hole, etc.): Extended Horizontal USH Sidetrack Objective: Rig will sidetrack out of existing 7" liner in Zone 2 formation, directionally drill 6" hole thru (1) Z1 target, TD at 13736' MD. Run, cmt and test 4 1/2" L80 solid liner, complete with 4 V2", L80 tbg, (3) GLM's and EOA tail assy. Post rig Coil Drilling extension of TD in 3-3/4" hole to 14,765'MD, coil will perforate Formation Markers Formation Tops MD TVD(ss) Sag River 8207 Shublik 8182 Top Sad 8235 Top Z3 8374 Top Z2 11335 8422 KOP 11345 8454 Top Whipstock at 11345'MD in 7" Build angle below at 12 deg/100' to horiz. Top Z1 11738 8670 Target 1 12505 8740 angle is 89.8 degrees at target 9ES TD 13736 8745 Total depth for 9ES activity 4-1/2" liner point 13736 8745 mn and cmt 4-1/2" liner at rig TD CTD Total Depth 14765 8945 Coil to mn 2-7/8" liner at their TD Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MDfYVD MDfrVD O.D. 6" 4 1/2" 12.6# L-80 IBT 2950' 10786'/8019' 13736'/8813' liner Mod 3-3/4" 2-7/8" 6.16# L-80 FLAS 1230' 13536'/8812' 14765'/9013' Tubing 4-V2" 12.6# L-80 IBT 10756' 30'/30' 10,786'/8019' Mod Logging Program: I Open Hole Logs: I Cased Hole Logs 9ES Drilling section: MWD/GR from KOP (11345') to 6" hole TD. MADD pass as per Geologist request. Sample catchers and rig site geologist on site before drill out. Open Hole: DPC Platform Express + Sonic will be run after reaching horizontal at 12505'MD. Run log back up to 8138'TVDss to ensure tie in. 3ES Drilling Section: directional only, memory CNL post liner setting Sample catchers and rig site geologist on site before drill out. Coil to run memory CNL post 2-7/8" liner running Mud Program: Special design considerations IDrill from KOP to TD with MI Flo-Pro Polymer system. I The formulation of the brine phase will be 6% KCL. Density LSRV PV Gels Chlorides pH (ppg) (cps) 8.7 55 - 60,000 < 15 10 sec. >18 30,000 9.0-9.5 to to expect to to 8.9 55 - 60,000 8-12 10 min. >20 30,000 9.0-9.5 Record LSRV at 1,2,3 minutes: Make certain they are elevated and flat. Plan to run 3 % Lubetex by volume. Start 6" section at 3 % Lubetex Sweeps (50 bbl min at 150,000 cp), Liner slugs and CBU w/60-80 rpm & reciprocation the full 90'. Ensure LCM materials are on location. Directional: KOP: 1) 11345' MD, drill out of 7 "liner via whipstock window at 1° azimuth, 36° inclination, build and turn angle at 12°/100, to 89.8° inclination, 314.37° azimuth by target gl at 12505' MD, 8740' TVDss', hold to 9ES TD at 13736' MD, 8745' TVDss. 2) CTD will drop angle and turn at 12°/100' from 89.8° and 314°azimuth at 13800'MD to a final angle of 76°and 7°azimuth then hold to TD at 14765'MD, 8945'TVDss. Maximum Hole 89.8°at target gl Angle: Surface Shut-in No wells will need to be shut-in and de-pressurized before rig moves on and off of the well. Close Approach There are no close approach wells to this wellbore Well: identified by Anadrill Wp g7A. Point to point separation Cement Data: Casing/Liner Lead: Tail: Sxs/Wt/Yield Comments Sxs/Wt/Yield P&A of original well 45/15.8/1.15 Class "G", TOC pre-rig coil work in 250' 10,550' 108' above top 7" production liner non-sqz, perfs. 4 V2", 12.6g, L-80 liner 325/15.8/1.15 Class "G", 40% excess Shoe at 13736' MD OH + 200' above liner Liner top@ 10,786'MD top w/DP in hole 2-7/8", 6.16g, L-80 50/15.8/1.15 Class "G", 40% excess liner Shoe at 14765' OH + 200' liner lap MD Liner top@ 13,536'MD Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter and BOPE system schematics on file with AOGCC. The 3500 psi WP CTD BOP stack drawing is attached. Bottom hole pressure is 3,425 psi at 8,249' TVDss (Top SAD) Is 7.9ppg EMW Maximum shut-in casing pressure is 2,600 psi (assumes 0.1 psi/ft gas gradient to surface). NO ANNULAR INJECTION IN THIS WELL. DS 15-21A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Name Contacts Office Home Paqer Jim Smith Drilling Eng. 564 5026 345 8660 275-4015 Tony Bunch Drilling Supt. 564 5219 348 6683 275-3703 Carolina Torres Geologist 265 6486 694 3294 Scott Mattison Pad Engr. 263 4362 338 9320 275 8045 Lowell Crane Asset Drilling Eng. 265 1544 868 7711 275 8644 D. Van Nostrand Geophysicist 265 1178 349 1843 Drilling Discussion Well Obiective Well DS 15-21 is currently a low rate cycle well with an existing value of 200,000 bbl oil. Gas is near the top of Zone 1. In 1990, a combination gas shut off and fracture treatment was done and the well was unable to produce more than 500 BOPD. In 1991, the well was re-frac'd and expanded drainage to the top of Zone 1. A gas shut off was done in 1995 to shut off Zone lB which resulted in dropping production to 500 BOPD. Gas production has now increased to the point of cycling the well. As a result, a new horizontal completion is recommended to restore wellbore integrity, maximize standoff from gas and improve areal drainage. The proposed horizontal sidetrack will target a 1250' horizontal section in the deepest producible Romeo sands. This target is in the northwest portion of the DS 15 area, just south of the midfield graben. An effective net-light-oil column of 60' is prognosed for the horizontal sidetrack in the Romeo (12P/13P/14P) sand intervals. The coil tubing extension will be done immediately after the rig has moved off location. The perforation of the horizontal section is anticipated to be delayed a year, as dictated by the performance of the graben play. This graben location is the deepest graben block in this area. It is estimated to contain 250'NLOC, with an unrisked oil volume of 4.4MMBO. The completion of this portion of the well will be with a convention 2-7/8" cemented and perforated liner, to be placed in the middle of the graben. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is no well that will need to be shut-in during the rig move on and off of the well. The nearest well is well 15-27 which is 58.8' to the north, SSD will waiver shutin of the well so long as the wellhouse remains on the 15-27 well. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move per ASH procedures. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on Anadrill directional well plan Wp #7A due to close approach requirements. PORE PRESSURE: The pore pressure in Zone 2 (KOP) is expected to be near 7.9 ppg EMW. 8.6 - 8.7 ppg mud will be used drilling Zone 2 and Zone 1, the Sag River and Shublik formations will be at similar pressure, the 8.6-8.7 ppg mud will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS The well's design cuts no faults in the 6" hole interval, but be prepared for the possibility of lost circulation by stocking LCM materials at the rigsite since there is potential for a subseismic fault near mid polygon of the 6" horizontal. No major hole problems are expected. H_z_S: DS 15 is not an H2S Pad The highest reported level of H2S on DS 15 is 12ppm on 15-3, all other wells are <10 ppm. There have been incidents of H2S on other pads which involved circulation of almular fluids from the wellbore. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) ° Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; H2S monitors with both audible and visual alarms; Access to 5-minute emergency escape air packs; Personal H2S monitors; Functional wind indicator; Posted evacuation routes (minimum of two); Muster points in designated safe areas;HzS; Functional communications between rig camp and rig floor. .Casing Shoe Kick Tolerance The smallest kick tolerance for the 7" casing (at the KOP of 11345'MD/8508'TVD) is calculated as infinite of influx assuming a swabbed gas influx from Z2 or Z1 formation along the planned directional path. Based on 8.7 ppg MW (7.9 ppg reservoir pore pressure), and min. frac at whipstock of 12.0 ppg. TREE; 7" x 5" Gray Gen II WELLHEAD: Gray Gen II HANGER SIZE: 9 5/8" Mandrel Type 1,1_00'_-_3,5_00' built inclination to 56 de,qrees 13 3/8", 72#, N-80/L-80 I 3,033' _3,5..00.' -..8,..800' Hold 56 - 45 d_eg_ree tangent inclination angle_ .... CMT'd m PROPOSED COMPLETION A KB. ELEV = 62,2' CELLAR BOX ELEV = 32.2' 'X' NIPPLE (OTIS) ( 2.750" ID) 2082' GAS LIFT MANDRELS ( CAMCO N-° MD(BKB) TVDss 1 2 3 4 1/2", 12.6#/ft, L-80 TUBING ID: 3.833" CAPACITY: 0.01522 BBL/FT _8,8_00_' _Dr_oP. Ded inclination angle_to_30_ d_eg_rees to TD 7" x 4 1/2" I 10,520' Liner/Hgr Pkr 9 5/8", 47#, L-80 110,838'1 7", 29#, L-80 Window I 11,345' Whipstock Base @ 11,345 MD (whipstock set on EZSV.) 11,869' x 4 1/2" Production Packer @ 10,700' MD 4-1/2" 'X' Nipple @ 10,750 MD 1/2" Liner Top @ 10,786' MD 4-1/2", 12.6# L-80, IBT-Mod Liner 6" TD @ 13,613' MD .~ 2 7/8" liner top @ 13,5 2 7/8" liner TD @ 14,765 MD Cmt. spotted across perfs during Pre-rig Bottom of cement @ 11,800' DATE 03-16-99 REV. BY JES COMMENTS PROPOSED COMPLETION BP PRUDHOE BAY UNIT WELL: DS 15-21A APl NO: 50-029-20503-01 SEC 22; T 11N; R 14E ,Exploration/AlaskaI .3.3 · 18 · 17 · 16 · 6 · 26 · 5 · DRILL SITE 15 23 · 2 · 1 · 41 .39 ~-.36 34 40 38 37 35 NOTES 1. Date of Survey: November 3, 199.5. 2. Reference Field Book: PB95-11 (pgs. 57-59). ,3. Horizont(]l ond Vertic(]l control is b(]sed on monuments Mon-15C (]nd Mon-15D. 4. Aiosko Store Plone Coordinotes ore Zone 4, Al(]sk(], NAD 27. 5. Drill site 1.5 (]veroge scole f(]ctor is 0.9999.355. · 20 i7 i 8 · 30 · 9 i 25 · lO · 11 I 12 · 13 · 14 · 15 VICINITY MAP N.T.S. o SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER 5, 1995. LEGEND -~- As-Built Wells · Existing Wells LOCATED WITHIN PROTRACTED SECTION 22, T. 11 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLER SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSIqON(D.DD) BOX ELEV. OFFSETS Y= 5,959,856.50 N. 999.90 70'17'45.265" 70.2959069' 33.2' 3,648' FSL 47 X= 676,266.65 E. 199.71 148'34'21.401" 148.5726113' 4,956' FEL I.,IJ KH RAWN: JACOBS :HECKEO: HACKLEMAN OAI~: 11/4//9 S DRAWN(;: DS15AB SCALE: 1 "=400' ARCO Alaska, Inc.' [ I DRILL SITE 15 IsHEET: CONDUCTOR AS-BUILT WELL 47 or ~ Drilling Wellhead Detail ~CT Injector Head Methanol Injection tis 7" WLA Quick onnect I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I _ --- 7" Riser I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/1 6", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual H CR Choke Manifold \ 5") Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16",5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual'over Hydraulic~ 7-1/16" ID with Pipe/Slip Rams Manual Master Valve . 0.458' (5.5") 2" Pump-In ubing Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus A~adrill Schlumberger Alaska Dis~r~ct 3948 Arctic B/vd Anchorage A/{ 99503 (907) 273-1700 Fax 561-8537 DIRECTIO~AL WELL PLAN for SHARED SERVrCEs DRILLIHG Nell ......... : DS15-21A (PTA) Field ........ : Prudhoe Bay Co~uta~ion..; Minimum Curvature Units ........ : FEET Surface I~at..: 70,29932127 N Surface Long.: 148.57468540 W Legal OescriDtion Surface ...... : 469~ F~ 5210 ~E~ ~22 Ti~ R14~ILM Target StarC,~ 932 ~$~ 3944 FEb $09 T11N ~14E UM Target E~d...~ ~793 FSL 4822 FHL S~9 TllN R14E ~ B~ .......... : 2755 ~L 4898 F~L S~9 TllN R14E ~ LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 67518~,92 5961099.90 672387.71 5966709.82 671800.00 5967600.D0 670900.00 5968440.00 670SDO.O0 5969~00.00 PROPOSED WELL PROFILE m:mm m mm:mm:~------=------~------ r. m m m'm mmmmm.m mmm STATIO~ EEASURED IDENT I F~ CAT I0N DEPTH m m mm m m m mm== =.------==:::-~...'~ :~ m m mm mmmmm~m:~:~ SAGR SRU~.IK TSAD TZ3 TI~- IN SURVEY 11300.?0 INCL~ AN~L~ D~RECTION ~ERTICAL-DE~THS AZIMUTR TVD SUB-SEA 8206.7~ 8139.00 8249.70 8302.70 8235.00 8641.70 8374.00 33.78 3.16 8&61.65 8393.95 SECTION DEPART 6455.F8 Prepared ..... : 18 Mar 1999 Ver~ sect az.: 314.38 KB elevation.: 67.70 ft Scale Pactor.: ~.99993518 Convergence..: ~1.3419~472 ANADR!LL AKA-DPC FEAS[¢!L1TY PLAN NOT APPROVED [OR [X[CUTtON PLAN COORDINAT~S-FRO~ ALASKA Zone 4 TOOL Wm.r.L~JU3 X Y FACE m mmmmm~ ~mmmmm~== m~ 5692,91 N 3&61.06 W 672387.71 5966709.82 8R TZ2 11334.51 TOP WHIPSTOCK 11345.00 BASE WI{IPSTOCK 11357.00 KOP/C~VE 12/100 11374.DD 11400,00 34.12 3.24 8489.70 8422.00 34.22 3,27 8498.38 8430.68 35.81 1.03 8508,21 8440,$1 35.~ 1-03 5521,99 845~,29 37,96 357.26 $542,79 8~75,09 l~S00,00 47.10 (AnadriL1 (c]99 152'lAP'7A 3,2C 3:47 PM P) 6467.81 6471.69 6~76.31 6483.14 6694,23 5721.76 N 3460,01 5717.64 N 34~9.68 5724.52 ~ 345~.42 ~734.66 ~ 3459.24 5750.06 N 3459.~9 345.70 8616.52 8548,82 65~8,25 5816.52 1{ 3470.05 672355.33 5266728.69 67238~.52 5966734.58 672388.62 5966741.46 672388.56 5966751.41 672387.95 5966766.9~ 6?2375,$4 5~66833,~8 8R 1.01 401 1,01 ~ 17,00 481 0,00 451 12,00 361 12,00 DS 1S-21A (PTA) m m:amm~ m m mm mt' m mmmm STATION MEASURED I~CLN IDENT[FICATIO~ OEPT}{ ANGLE 11600 . 08 57. L0 11700.0O 67.55 11735.28 1~$00. O0 78.24 CURVE L2/I00 12439.85 85.80 12500.00 89.46 END 12/108 CURVE 12505 . 03 89.77 TARGET STARTS 12505.03 89.7~ 4-~/2" L~ ~ 13736.22 89.77 CURVS 12/'t00 TARGET ~ 13736.22 89,77 13736.22 89.77 13800.00 87.50 13900.00 86.05 3~000.00 80.83 14100.00 78,00 END 12/100 CURVE 24183.82 76.01 2-7/8" L~NR PT 14765.26 76,01 TD ~4765.26 76.01 PROPOSED WELL PROFILE DIRECTION VERTICAL-DEDTHS AZIMUTH T%rD S1/B-gEA m~=m~m= ~mm=mm~ mmmmm~=m 337.26 $677.93 86~0.23 330.58 a724.35 8656.65 325.30 8737.70 8670.00 324.85 8753,74 8686,04 321.11 8763.48 8695.7~ SECTION D~PART 6618.48 6701.84 6736.46 6?94.69 6863.35 L8 Mar 1999 Page 2 COORDINATES-FROM ALASKA Zone ¢ ~ELLH~AD X 5891.00 N 3495.42 W 67~548.73 S966907.0~ 5970.26 N 5534.%9 W 672307.82 5966985.36 6001.14 N 3552,73 W 67~288.86 5967015.80 6050,S3 N 3585,~6 W 672254.$$ 5~67064.71 6106.26 N 5627.38 W 672211.75 5967119.13 321.11 8805.1~' 8737.45 7427.58 6548.$L N 3984.04 314.89 8807.67 8739.97 7487,51 6593.14 N 4024.23 314.37 8807.70 8740.00 7492,54 6596,67 N 4027.81 314.37 S807.70 8740.00 7492.54 6596.67 N 402~.81 314.37 &812.70 8745.00 8723.72 7457.~7 N 4907,94 314,37 $812.70 8745.00 8723.72 7457.57 N 4907,94 W 314.37 $812.70 8745,00 8723.72 7~57.57 N 4907.94 W 321.68 $81&.22 8146.52 8787.31 7504.94 N 4950.56 W 333,9~ $~91,61 875~,91 888~.25 7588.83 N 500~,15 W 344.87 8834.81 8767.11 8974,22 7681,21 N 5039,$$ W 356.74 8853.2~ 8?85.54 9053,15 7778,04 N 5055,30 6.S5 8~72.13 8804.43 9108.29 7859.55 N 5052.7~ 6,S5 9012.70 8945.00 9452.04 8419,72 N 4985.44 6,~5 90L2.70 8945.00 9452,04 8~19,72 N 4985.44 TOOt. DL/ FACE 100 31r, 12.00 28[, 12. O0 2';5 12 .OD 261 12.00 H$ 12 67184~,~$ 596755=.88 6QL 671803.66 5967596.55 59L 12.00 67L800.00 596~600.00 HS 12,00 671800.00 5967600.00 HS 12,00 670900.00 5968440.00 107R 670900,00 5968440.00 107R 0.00 670900,00 5968440.00 IO~R 0.00 670856.29 5968486.35 107R 12.00 670800.75 5968568.96 106R 12.00 670763,17 S968660.48 105R 12,00 670745,18 $968756.91 183R 12.00 670745.80 $968835-~S ~IS 12.00 670800.00 $969400-00 0.00 670800.00 5969400.00 O.O0 ( t 1, Am. adrill (c}99 L521AP7A 3.2C 3:47 ANADR1 AKA. Df-'C ,: FEAStBILt¥¥ o, ^ I I.._,/-,~ :g NOT AP?ROVSQ PLAN ....... ...... ,~ ............... . ........ SR'AREB ...... SE ii i i Marker ~de~i~ica~ion ~0 BKB A) lIE-IN SURVEY i130~ 8462 B) TOP NHIPSIOCK 1t345 8498 C) SASE BqIPSTOCK 11357 8508 D] KOP/CURVE 12/100 11374 8522 E] END i2/tO0 CURVE t1870 8763 F] CURVE t2/108 12440 8805 G] END 12/t00 CURVE ~2505 8808 H) TARGET STARTS 12505 8808 [) 4-1/2' LNR PT ~3735 8813 J) CIt~YE ~2/I00 i373§ 8813 K) TARGET ENDS i3736 8813 L) END 12/tO0 CURVE 14184 8872 M) 8-7/8" :LNR PT '147135 §0i3 N~ TO :~47§5 §0f3 RVIO'ES _ __ iii SECfN [NOL~t 645§ 33.78 6472 34.22 8476 35.8! 6483 35.B~ 8863 85.80 7428 85.80 7493 89.77 7493 89.77 a 724 89.7 ? 8724 89.77 8724 Bg. 77 gt08 713.01 · g452 76.01 9452 76.01 OR I"l'_' L ..... i mllm imm --- .... mill i ___ i mil [[[[ [[[ i Section at: 3J4.38 TVD Scale' I inch = 400 feet Der Scale ' I inch = 400 feet Ora~n - tB Mar 1999 . __ immm ii ~nadrJ l ] SchZumberger _ iii i i mmlml ._ I DS15-21A (P7A) VERTICAL SECTION VIEW _ illn IlII 8401 ..... 8800 6200 5400 6600 6800 7000 720o 74o0 7800 7800 8000 8200 8400 88oo 8800 9000 9200 9400 980o 9800 .... Sect ion Departure .. i ii ..... i ii i i . . il i _ mmlll i I . __ I III I __ II I ~na~'r[)i ic>.~ lii2l~7~, .3,2C 3:5'5 R'4 PI ¢ I- L t. i. L SHARED S'ERVlCbS' DRILLIN ( A) ~ae~ee I~entification ~D N/5 PLAN VIEW "' '' DI KOP/CURVE ~8/~00 ~374 5734 N 3459 W 6LOSURE ' 9785 feet at Azimuth 329.37 El END ~2/~o0 6URVE ~870 8~06 N 3627 W BEBLINATION.' +27 780 (E) Fi CURVE t2/~00 ~2440 85~9 N ' 6J END 12/t00 CURVE ~2505 6597 N 4028 W SCALE ....... ' 1 inch : 500 feet H) TARGET STABTS ~2505 6597 N 4028 w , I) 4-~/2' LNR PT ~3738 7458 N 4908 DRAWN I8 Mar ~999 K) TARGET ENDS ~3736 7458 N 4908 W .... L) END 12/~00 6URVE iii i i 8dO0- - .~ ,., ... I I~ ...... ..... .¢~ _. ~ .... ... ~...._ ...... - 8250- - ' 8000--- ,.. , ~ : i 7750- -- m ..... 7500 ~Tar _ 7ooo-- ! " . 6500 6250 ~.. . ..... ~ 5750 ~ . .~, . , ,. S250- - .~, . ...... 6000 5750 5500 5250 5000 4750 4500 4250 4000 3750 3500 3250 3000 8750 2500 <- WEST ..... , , ............ J' ...... i . ~, ~,m , d .ry[ces nll ng IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED'' will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) x DRILLING PERMIT SUNDRY NOTICE /- P6rmi~D~e~ntation Prepared: ov : Perm~Application Reviewed: SDE/ES:~-')-~_."-'~. ~ Date:~/&3)~q Pe~~pp~cat)~ ~u~ued: Sundry Documentation Prepared: ODE: Date:~ Sundry ApplicationReviewed: SDE/ES: Date: Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW PRE-RIG WORK Reason for Sundry (Check all that apply) Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date:~ Pre-Rig Sundry Documentation Prepared: ODE: Date:~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date:~ Pre-Rig Sundry Application Submitted: TA: Date:~ Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: .rv[ces nll ng The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) x DRILLING PERMIT SUNDRY NOTICE / P6rmi~)~~tion Prepared: .:, / ODE: 'U_zY. e6t,~/ Dat~/o~'/~7 Perrn~Application Revieowed: SDE/ES:~--~-') -~ --,"~. ~ Date: Permit~pph~catjpn ~u,l?,mitted: L.~/__ TA: ~/],]L/J,..~ ,_.~~'~. ~_~_ Date: Sundry Documentation Prepared: ODE: Date: Sundry Application Reviewed: S DE/ES: Date: Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW PRE-RIG WORK Reason for Sundry (Check all that aooly) Pre-Rig Memo Reviewed: S DF_dES: Date:~ Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: S DE/ES: Date:~ Pre-Rig Sundry Application Submitted: TA: Date: Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension Plugging Perforate Pull Tubing Stimulate Variance . . Other(Explain): ,~ i ::':' .; ~i, ".. !'-: '. APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: Alaska hared ervlces rilling IThe attached work cannot commence without obtaining the required signatures in the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) x DRILLING PERMIT SUNDRY NOTICE .! Permi~),~,g~e~mation Prepared: ~ / ODE: ~ Dat~'//o2~/~/q Pern~Application Reviewed: Per~ppl~cat~pn ~u~tted: ~/__ TA: ~A~ ~~ Date: Sundry Documentation Prepared: ODE; Date: Sundry Application Reviewed: SDE/ES: Date: Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW PRE-RIG WORK Reason for Sundry (Check ali that apply) Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date:~ Pre-Rig Sundry Documentation Prepared: ODE: Date:~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date:~ Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): APPROVAL TO PROCEED Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: STATE OF ALASKA ALASKA ....... _L AND GAS CONSERVATION-CO,_ .... IlSSION APPLICATION FOR SUNDRY APPROVAL 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 Plug Back for Sidetrack 2. Name of Operator ARCO Alaska Inc. 3. Address \ P.O. Box 196612, Anchorage, Alaska 9951~6612 4. Location of well at surface ~ 382' SNL, 80' EWL, SEC. 22, T11 N, R14E, U At top of productive interval 85' SNL, 1886' EWL, SEC. 16, T11N, R14E, At effective depth 295' NSL, 1918' EWL, SEC. 09, T11 N, R14E, UM At total depth 328' NSL, 1921' EWL, SEC. 09, T11N, R14E, UM 12. Present well condition summary Total depth: measured 11860 feet Plugs true vertical 8923 feet Effective depth: measured 11750 feet Junk true vertical 8832 feet Type of well: [~ Development I--I Exploratory [--] Stratigraphic I-~Service 6. Datum Elevation (DF or KB) 67' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 15-21 9. Permit Number 80-91 10. APl Number 50-029-20503 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool FCO to 11750' MD (08/27~95) Casing Length Size MD TVD Structural Conductor 80' 20" 300 sx Pe~ 110' 110' Surface 2963' 13-3/8" 3200 sx sx PF II 3030' 2675' Intermediate Production 10771' 9-5/8" 700 sx PF 'C' 10838' 8065" Liner 1349' 7" 725 sx 10520' - 11869' 7787' - 8930' Perforation depth: measured 11658' - 11671 ', 11689' - 11691 ', 11694'~ 11705' true vertical 8755' - 8765', ~781' - 8782', 8785' - 8794' ~, Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80 PCTat 35'; 3-1/2'y.3#, L-80 Plf~l at 11494' 13 Attachments D ~ t~ r · [] escr'p 'on summary of p oposal [] Detailed operations prog~m ~ BOP sketch 14. Estimated date for commencing operation 115. Status'of well classificat~ns as: March 30, 1999 I [~ O~1 I-~ Gas [--~\ uspended Name of approver Date approved Contact Engineer Name/Number: James Smith 564-5026 ' Prepared By Namel~mber: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge S~gned' c.......~.,~,- ..... OanStone · Title Senior Drillin~i Engineer ~, Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance~ Mechanical Integrity Test Subsequent form required 10- \ Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE 50240 I VEN~R ALASKAST14 O0 '" DATE INVOICE / CREDIT MEMO DESCRIPTION "GROSS DISCOUNT NET "' 032"5c~9 CK032599C 100. 00 100. O0 HANDLINg INST: S/~ TERRI HUBBLE X4&28 ~e]llfil ~l ' ' THE ATI'ACHED CHECK IS IN PAYMENT FOR ITEMS DESCRibED ABOVE. ~ ] 100. O0 100. O0 ",~:;:i;:::' ?~"::".':~: ::':~ ;??" ':;;::,':":'." ":~,",'%'"' ::":'::; "' ::? :~:?' :' :: "~ DATE ...... L°3/~s/*'*~/~ ! ~ "°° °°1 , 'TO' .Th ~ .~ ~L~ ST~TE..'.,O~P~.:QF REV~N~E :..~.:~:~:. ,..~"~ j:.~"~:.':¥.., '~,:~ ?: 45059 ~xo~,x~aI ool4uou'~I VENDOR AI,ASKAST 14 GO DATE INVOICE / C EMO DESCRIPTION GROSS DISCOUNT NET 1lO&gE CK110&98I ~ 100. O0 100. O0 HANDLINO INST: ~S/~ KATHY CAMPO~MOR X5122 v~ THE A~ACHED CHECK I~ IH PAY=D~T FOR ~EBS DE~RIBED ABO~ 1 OO. GO 1 OO. O0 PAY T° Th'~I .Order .. ~:::'"ALAS:KA STATEi,'.:D~PT;:':;;.'~F REVENUE NE?DR:' 3001 '[::" PORCUP I ! .,. .: ., ,, .. ANCHORAGE WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION DATE/ COMPANY ~.'~ ~ ENGINEERING D.ATE I GEOLOGY INIT CLASS APPR DATE , WELL NAME ,/~ /"o¢'~ 2__/,,z~ PROGRAM: exp __ ~;;~j~, /-,~,.~' GEOL AREA 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool.' ................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '306;~O . psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N y,yN N N (~N (.~N Y N (....~ N (~N d~N (~N N dev ~<~ redrll ~ serv ~ wellbore seg ann. disposal para req __ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... ~NN ~.,,,~ 32. Seismic analysis of shallow gas zones ............. , 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratoryo_~y] Y N UNIT# /*~("~ ON/OFF SHORE ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain waste in a suita~ving zone; ....... Y N (B) will not contaminate fre~sh~ater; or cause drilling wast,.e.~.: Y N to surface; ~ ~ (C) will not imp?,.ak-l~echanical integrity of the w~Jl-~sed for disposal; Y N (D) will no.9~mage producing formation o.,gr,,rrfi' pair recovery from a Y N pool,"and ' (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLO.,G_Y: ENGINEERING: UIC/Annular /" COMMISSION: WM co co '~/~/e,~ Comments/Instructions: c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS **** REEL HEADER MWD 00/ 2/29 BHI 01 LIS Customer Format Tape ***' TAPE HEADER MWD 00/ 2/28 105367 01 1 3/4" NaviGamma - Gamma Ray data LIS COMMENT RECORD(s): ~23456789~~23456789~~234567890~23456789~~23456789~~23456789~~23456789~~234567890 Remark File Version 1.000 Extract File: Header.las ~Version Information VERS. 1.20: W~%P. NO: -Well Information Block #MNEM.UNIT STRT.F STOP F STEP F NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL REF DATE API O~LS log ASCii Standard -~¢~RSION 1.20 One line per frame Data Type Information 13740.0000: Starting Depth 14715.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMP~Y: A~,CO Alaska, Inc. WELL: i5-21A FIELD: Prudhoe Bay Unit T ~ ~T .'. ~O~A~ON.~ ~N~' ....... ~ Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1 3/4" NaviGamma - Gamma Ray JOB REFERENCE: 105367 LOG DATE: 18 Jun 1999 API NUMBER: 500292050301 ~Parameter Information Block #MNEM. UNiT Value Description =T mn, ~? Field Location SECT. 22 : Section TOP~.N liN : m =h~ ~o¥~ .... p ~NG. i4E : Range PDAT. M.S.L. : Permanent Datum EPD. F 67' : Elevation ~=~ Perm. Datum ~4F . KB : Log Measured From FAPD. F 67 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 67' : Elevation Of Kelly Bushing EDF .F N/A : Elevation Of Derrick Floor EGL F N/A : Elevation ^~ Ground T~ ~ ~=ve~ CASE.F 105367 : Casing Depth OS! . DIRECTiON~ : Other Services Line 1 ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-21A was kicked off @ 13760' MD (8706' SSTVD) from the wellbore originally drilled for Well 15-21. RECEIVED MAR 08 :!000 · Alaska Oil & Gas Cons. Commission Anchorage (5) The interval from 14686' MD (8913' SSTVD) to 14710' MD (8913' SSTVD) was not logged due to sensor to bit offset. (6) Well 15-21A was drilled to 14710' MD (8913' SSTVD). The TD was moved to 14720' MD (8913' SSTVD) after a tie-in. (7) The Gamma Ray log has been depth shifted to match the Schlumberger MCNL Gamma Ray logged on 20 June 1999. (8). A Magnetic Declination correction of 27.74 degrees has been applied to the Directional Surveys. ~Mnemonics -> GRAX = Gamma Ray MWD-API [MWD] (MWD-API units) -> ROPS = Rate of Penetration (ft/hr) -> TVD = Subsea True Vertical Depth (feet ~Sensor Offsets RUN GAMMA DIRECTION 2 24.24' 29.24' 4 23.12' 28.12' Tape Subfi!e: ! 64 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 15-21A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~234567890~23456789~~23456789~~234567890~23456789~~23456789~~23456789~ !!! !!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the Schlumberger's MCNL Gamma Ray data, dated 20 June, 1999. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ! GR GE_AX 0.0 2 ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode( 66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode( 66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode( 66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode( 65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type( 11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a IF ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP ~D 68 i 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 i 4 99 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 24 1014 BYTES * Tape File Start Depth = 13730.000000 Tape File End Depth = 14715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5917 datums Rep Code: 79 2 datums · Tape Subfi!e: 2 31 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes [] Tape Subfile 3 is type: LIS ..- **** FILE HEADER MWD .001 1024 INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 15-21A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i G~X GR~ 0.0 2 ROPS ROPS 0.0 FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode( 66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode( 79 Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode( 66 Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode( 66 optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode( 68 Frame spacing: 0.500000 Entry Type( 9) Size{ 4) Repcode( 65 Frame spacing units: IF ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 8 fndun a IF ] 1.00000000 3 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 i 4 2 ROPS ~7~D 68 i 4 DATA RECORD (TYPE# 0) Total Data Records: 24 1014 BYTES Tape File Start Depth = 13740.000000 Tape File End Depth = 14715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5857 datums Rep Code: 79 2 datums Tape Subfile: 3 31 records... Minimum record length: 54 bytes Maximum record length: 1014 b.vtes Tape Subfile 4 is type: LIS **** TAPE TRAILER MWD 00/ 2/28 105367 01 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 **** REEL TRAILER MWD '~*/ 2/29 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 29 FEB .4 9:53a Elapsed execution time = 1.38 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS [] Tape Subfile 2 is type: LIS DEPTH GR ROP 13730.0000 -999.2500 -999.2500 13730.5000 -999.2500 -999.2500 13800.0000 72.3920 76.5000 13900.0000 39.7500 102.8000 14000.0000 236.9100 44.4000 14100.0000 98.4030 38.1880 14200.0000 125.6100 12.7500 14300.0000 162.1800 50.0000 14400.0000 38.1600 78.2000 14500.0000 153.4350 26.4430 14600.0000 69.0060 16.1000 14700.0000 -999.2500 9.1000 14715.0000 -999.2500 -999.2500 Tape Tape File Start Depth = 13730.000000 Tape File End Depth = 14715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Subfile 3 is type: LIS DEPTH 13740.0000 13740.5000 13800.0000 13900 0000 14000 0000 14100 0000 14200 0000 14300 0000 14400 0000 14500 0000 14600 0000 14700.0000 14715.0000 GRAX ROPS -999.2500 -999.2500 -999.2500 -999.2500 71.5500 87.8000 39.7500 105.8000 221.8050 78.2000 74.7300 50.0000 92.2200 51.4000 162.7100 50.0000 38.1600 78.2000 153.4350 26.4430 107.3250 31.1000 -999.2500 7.2000 -999.2500 -999.2500 Tape File Start Depth = 13740.000000 Tape File End Depth = 14715.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS REC£1VED MAR 08 000 Alaska Oil & Gas Cons. Commission Anchorage
