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200-052
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-07A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-052 50-029-20128-01-00 13260 Conductor Surface Intermediate Liner Liner 9007 79 2667 10077 1878 3063 11060 20" 13-3/8" 9-5/8" 7" 2-3/8" 8452 24 - 99 24 - 2691 22 - 10099 9601 - 11479 10188 - 13251 24 - 99 24 - 2691 22 - 7739 7363 - 8787 7803 - 9007 11845 520 2270 4760 7020 11780 11060, 11600, 11650 1530 4930 6870 8160 11200 10990 - 13201 4-1/2" 12.6# x 3-1/2" 9.2# 13cr80 x L80 20 - 11479 8397 - 9003 Structural 4-1/2" Baker S3 Packer 9404, 7217 9404, 7217 9540, 7317 Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285, 0028305 3-1/2" TIW Packer 20 - 8787 9540, 7317 N/A N/A 36 83 23649 25068 60 33 800 800 635 800 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: No SSSV Installed By Samantha Carlisle at 8:44 am, Oct 14, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.14 08:38:10 -08'00' Stan Golis (880) DSR-10/15/21 RBDMS HEW 10/14/2021 MGR15OCT2021 SFD 10/19/2021 ACTIVITY DATE SUMMARY 10/9/2021 ***WELL FLOWING ON ARRIVAL*** (Pprof) MIRU HES E-LINE. DIVERT WELL INTO TEST SEPARATOR. CHOKED BACK TO ~ 5 MM GAS. RIH W/ 1.69" PPROF LOGGING TOOLS. TAG LTP AT 10180'. ATTEMPT TO GET THRU AND TOOLS SHORTED OUT. POOH. RE-RUN 1.69" PPROF LOGGING TOOLS. TAG LTP AGAIN. SHUT IN WELL. ABLE TO FINALLY GET INTO LINER AFTER MULTIPLE ATTEMPTS. SLOWLY BRING WELL BACK ONLINE. TOOLS BEING LIFTED OUT OF 2-3/8" LINER, PULL BACK UP INTO TBG. TOOLS SHORTED OUT AGAIN. POOH. DISCUSS W/ OE. OE HAS ELECTED TO SET CIBP BELOW UPPER PERFS. LAY DOWN FOR THE NIGHT. ***CONTINUE JOB ON 10/10/21*** 10/10/2021 ***JOB CONTINUES FROM 10/9/21*** (Plug Set) SET NORTHERN SOLUTIONS 2.375" CIBP AT 11060'. MID JOINT BELOW TOP PERF INTERVAL. ***JOB COMPLETE / TURN OVER TO PAD-OP TO POP*** Daily Report of Well Operations PBU C-07A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:200-052 6.50-029-20128-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13260 11600 8917 9404, 9540 11845 11600, 11650 7217, 7317 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20" 24 - 99 24 - 99 1530 520 Surface 2667 13-3/8" 24 - 2691 24 - 2691 4930 2270 Intermediate 10077 9-5/8" 22 - 10099 22 - 7739 6870 4760 Liner 1878 7" 9601 - 11479 7363 - 8787 8160 7020 Perforation Depth: Measured depth: 10990 - 13201 feet True vertical depth:8397 - 9003 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr80 x 3-1/2" 9. 20 - 11479 20 - 8787 9404 7217Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 3063 2-3/8" 10188 - 13251 7803 - 9007 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 72075069527626 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9007 Sundry Number or N/A if C.O. Exempt: N/A 3-1/2" TIW HBBP-R Packer 9540 7317 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028285 PBU C-07A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 36 23649 60 635800 By Samantha Carlisle at 4:04 pm, Jun 15, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.15 13:18:19 -08'00' Stan Golis (880) RBDMS HEW 6/16/2021 SFD 6/18/2021DSR-6/15/21MGR29JUL2021 ACTIVITY DATE SUMMARY 5/26/2021 ***WELL SI ON ARRIVAL*** DRIFT TBG w/ 1.77" CENT & 1.5" SAMPLE BAILER TO CIBP @ 11634' SLM / 11650' MD (bailer empty) ***IN PROGRESS, JOB CONT. ON 5/27/21*** 5/27/2021 ***JOB CONT. FROM 5/26/21*** T-BIRD PUMPED 230 BBLS CRUDE TO LOAD TBG SET 3-1/2" KB PKR TEST TOOL IN KB PKR @ 10180' MD PERFORMED MIT-T TO 1500 PSI **PASS** PULLED 3-1/2" KB PKR TEST TOOL @ 10180' MD DRIFT TBG w/ DMY 2-3/8" CIBP DRIFT TO CIBP @ 11650' MD ***IN PROGRESS, JOB CONT. ON 5/28/21*** 5/27/2021 T/I/O=2400/1150/600 Assist Slickline (Profile mod) Loaded tubing w/ 3 bbl 50/50 methanol spear followed by 230 bbls 90* crude. Pumped 5.6 bbls Crude to achieve test pressure. MIT-T to 1400 psi *PASSED*. IA/OA= OTG Slickline in control upon departure. 5/28/2021 ***JOB CONT. FROM 5/27/21*** SET NORTHERN SOLUTIONS 2-3/8" CIBP @ 11600' MD ***JOB COMPLETE, WELL LEFT SI, DSO NOTIFIED OF STATUS*** Daily Report of Well Operations PBU C-07A * s: M " • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION j( 9 REPORT OF SUNDRY WELL OPERATIONS d �� 2017 1. Operations Performed N_ AOG Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate H 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. 5-c1- C//3d Et." 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 200-052 3. Address: P.O.Box 196612 Anchorage, Development Ef Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20128-01-00 7. Property Designation(Lease Number): ADL 0028285 1 8. Well Name and Number PBU C-07A 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 13260 feet Plugs measured 11650/12260 feet true vertical 9007 feet Junk measured 11845 feet Effective Depth: measured 11650 feet Packer measured See Attachment feet true vertical 8917 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 79 20"94#H-40 26-105 26-105 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 10990-11020 feet 12015-12045 feet 12330-12370 feet 12370-12610 feet 12610-12850 feet Perforation Depth: Measured depth: 13100-13201 feet True vertical depth: 8397-8421 feet feet 8996-8996 feet 8999-9001 feet 9001-9006 feet 9006-9000 feet 8999-9003 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): ss�gp� Nov c� ZO 1 7 scit`lN V 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: 158 20860 10 860 900 Subsequent to operation: 316 13854 21 860 720 14.Attachments:(required per 20 MC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ 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: Glasheen,Brian P Contact Name: Glasheen,Brian P Authorized Title: Produ tion E s'ine f / / Contact Email: Brian.Glasheenr�bp.com Authorized Signature: nor Date: (0/ 9//7 Contact Phone: +1 907 564 5905 Form 10-404 Revised 04/2017 ,.tom T� to /c 7-1 17 p -m.3 A 7 2317 Submit Original Only • • 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 October 6, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the Setting of a Plug and Adding of Perforations Well C-07A, PTD # 200-052. 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 • Packers and SSV's Attachment PBU C-07A SW Name Type MD TVD Depscription C-07A TBG PACKER 9393.71 7209.4 4-1/2" Baker S-3 Perm Packer C-07A TBG PACKER 9536.38 7314.72 3-1/2"TIW Packer C-07A PACKER 10180 7797.36 3-1/2" Baker KB Top Packer • • enN N N- COO COO N O O M — Cf) CO ' CO N- N- O n 0 Lo 0 C) gO cococY) NChNNMOMCO = CC) C)) 0 CA CO CO r N Tr r m r— 't CO CO OO CO .O N- Cn 0) CO V CO O CO000 CO N CO - N- N- O N ti N N N- CO CA N- CO H N NCO N N - M 000 0 CO N N N N- ti N- .60 CAM NO N 0 Cn a) rcp Oc\i N c.4 o (Ni err- i I Q 0.3 0i N N M N N O CD O CO N r" N N 00) a N N C CO o 300000 0 � 0 O I 1 I 0 0 CO CD C3) � ZZZ JZapJchJ . N *k h MCN ti N CO 0000 -0OQON � � N �- Cr) 0 N r C47 s �rnv- rncY) CCNCCCOOCO C O Cn CO 0 v 0) W W _Q _Q = O W W w 0 0 N U U U w W VOuiuiuiCCC:CceceZZ Z W I Q W W W W m m ommDF' I-' ZZDD U cn ci) cA Z Z = H r ! Packers and SSV's Attachment PBU C-07A SW Name Type MD TVD Depscription C-07A TBG PACKER 9393.71 7209.4 4-1/2" Baker S-3 Perm Packer C-07A TBG PACKER . 9536.38 7314.72 3-1/2"TIW Packer C-07A PACKER 10180 7797.36 3-1/2" Baker KB Top Packer II 40 i W U O 0 U- 0) O Y UJ ocn 2 N LL - • O U C cc M Q CO crOj O L (D o rn zI- ( Z Q LU O F- _1 o F- _0 -p o Q m- I- 0 -2 r V w m LU II Q in Q X 2 = cozUJ 0 = co cor3O nc C CC CLw0 0 EL W r 'o a L. d N OLU c? LI-I L~L O0 b 11 - O L -0 m Z a _2 H$ a <( 0 co Wa m 2 -t 0 °. W Uw � � � � p x � � O a ai as Q 0 0 D !n OL d g fn N Z W c 417 -8. N - Ja J 11 U) r rU LLJ 0 OU) Cl) ° Z Q El N) J -Y Ud VZm co ©V Z 0 (.0Ce0 N LL U r2 W C we W ?� - o IZ 0v J 'O . m 2 •• - O C oo0 �, Z 7: E5 O � Q -10 ‘-- 0 .li; 2E y .O 1 U ' °' I- d II Q E ,-- J f/) �` W e V '- 0 I- Q W ? II F- II d ~ W ~ d o Q M O V J o - �r` m F- ao - DCOm JI- I- (z)- W (n c co- .- LL to cc V2 Q Q 0) N. N W = = N - I- ON I- W J 60.6 C M OrcQ 0 Gm ( n2 9 C c *C7 cnoza2 Qa - � a, co �"Q a � °' BOO SU u) o rW aO - Fw- JW F- O 0 I- W Sc * -aC7 _1 JO 0_ CC _ O � F- O W wx 0 • N .SN- owu) mW = O �r J = O0NLF- 0 � m Z Q C � � op � 0 N m : OY r m N .J J II aOQ = = - W * - NO OF- i to O , tiJJ a WCC Z O U L rdQ C � o v W UOcoaW > V m z 0 * ti › mo ,... - - i,..- ne- tea CNww5 Q it C) n � U � O � ?� po 0I— 0 O = , c -- @m1:-.4:. 6V- c1) (90 re r 'a o0 C Ca N 0 (0 � p � � �j � Nu) 00 O O W - 0 � Cl) c *Linm � Mc$ JoO � O F- u) � Q-' W � � CD CC W W II JL- Z I (nrE' m • Tj6LL '- LJJ 11 W Ws- F_ Z pQ0 m IZC5O = tipOLN W tOL . W W F- Lli Z - u - Q CtOO) W O CLW o rnrni- 0CR' CV � W O a& WCC CN C ' Q2F- Q W DO rt = F- ON U �' J � � � �, _ NZ � aQ03 xeij >2 _O m LU °) v � .0Qm 3m v Q2D - 2 3 7 f-- � UQw3 � ZO W 0 F- <C 3 a3cc ,, -OjO � -• > I-- coo F- QF- ;22 - � m ii62 - a W a = 0 W F-. U W 0 = :,C-. � tigt53 * CrptnZ O Z LL MF_ OOQ' 0\007W p52Q > Q (J) J ZF- C NCDco Cr3 fO C HOV W U M = 00 0 -1 w O oNLo N x U oC� 8VapJ N a OOMdNI- � C� • a2 � 200W Oaf (1) ll CO UI bui _ x � OW ``� -I O o * * 2 °° LLULLLI < DL� °° w0 � o awl o � � cz � z � 30 1- � '-'- 1'- --I * oc6u) ndF- oca582aQRi i Oi wLLF- Wi CtHCt 4 'ea' W F- O Ps r N. N- N- Ps Ps Ps ›- O r r r r I_ N O 0 0 O O 5 N N N N 10 I CD CO N N- N N. N. P a) a ~ 0 rn rn 0) Q • N co = 0. Q u) 0 < 0 0 � V o m O a 0 0as 0 c J N O � N �n U 0 -9co to sa co to r- N v- TREE= aw • Ilk VVELLHEAD= MCEVOY -Q 7A SAFETY NOTES: W ELL ANGLE>—70°@ 11772' ,ACTUATOR= OTIS "4-1/2"CHROME TOG" OKB.ELEV= 55.65' BF.ELEV= 36' ( LI �� 1 OP_ 2700' Max Angle= 96'@ 12900 I 2117' —I4-1/2"HES X NP,D=3.813" Datum MD= 11559' Datum ND= 8800'SS , ,r0000,/ 2690' —FULL OPENING CB U'1TER 9-5/8"CSG,47#,L-80 NCSS,D=8.681" H 2107' L GAS LFT MANDRELS 13-318'CSG,68/72#,N-80, — 2691' ST MD ND DEV TYPE VLV LATCH PORT DATE 68#,D=12.415"/72#,D=12.347' I 4 3007 3007 7 WAG DOME RK 16 11/15/06 3 5837 5192 55 MNG DOME RK 16 11/15/06 2 8359 6603 58 MING DMY RK 0 10/14/06 1 9294 7137 44 MAG SO RK 22 11/15/06 Minimum ID =1.81" a@ 10180' 3-1/2" KB LINER TOP PACKER 9373• H4-1/2-HES X Imo,D=3.813• S 9404' —14-1/2"X 9-5/8'BKR S-3 PKR, ID=3.870" I 94.38' --+4-1/2"HES X NP,D=3.813" 4-1/2"TBG, 12.6#,13CR-80 VAN TOP. H 9501' .0152 bpf,D=3.958' �j 9504" H3-1/2"OTIS X NP,D=2.750" TUBING STUB(10/18/06) —{ 9502' IlL 951r H9-5/8"X 3-1/2"U IOt1EOVERSHOT L3-1/2"TBG.9.2#,L-80 IDS,.0087 bpf,D=2.992=1-1 9621' J 9522* —{TANSBR,D=4.0" 9540' I--I9-5/8"TAN HBBP-R PER,ID=4.00" 7"BOT FBR —r 9601' 9601' H7"FBR(40'BOT) TOP OF 7'BOT LW HGR H I 9643' H 9-5/8"CSG,47#,N-80,BTRS,ID=8.681" —j 10099' I-4 , 10180' I 3-1/2"BKR KB PKR,D=1.81'(02/09/15) TOP OF 2-3/8"LNR 10188' 1:3. 10188' BKR DEPLOY SLV,ID=1.969"(00=2.70") 3-1/2""VVHF'STOCK(w/RA TAG @ 11475') H 11470' MLLOU T WINDOW(C-07A) 11479'-11488' 3-1/2"TBG,9.2#,L-80 TDS,.0087 bpf,D=2.992" — —11479 7"LNR,29#,N-80 BTRS,.0371 bpf,D=6.184" -1 —11479 \ 11660' H2-3/8"VVFD CUP(09/07/17) PERFORATION SUMMARY 11846'ELM ASH:2-3/8"CUP(07)05/17) REF LOG: CN-FD ON 09/03173 — ANGLE AT TOP PERF: 39°@ 10990' 12260' --`2-3/8"WFD CUP(12/30/13) Note:Refer to Roduction DB for historical pert data 44'4'�"� .1 SIZE SPF NTERVAL OpNSgz SHOT SQZ 10..01 , 1-9/16" 6 10990-11020 0 07/05/17 , 1-9/16" 6 12015-12045 C 12/30/13 1-11116" 4 12330-12370 C 10109/00 , 13214' —1P81D 1 1-11/16" 6 12370-12610 C 10/09/00 1 . 1-11/16' 4 12610-12850 C 10/09/00 `�`: 1-11/16" 4. 13100-13201 C 10/09/00 2-3/8'LNR,4.4#,L-80 FL4S, —1 13251' .0039 bpf,D=1.992' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 01/30/78 ORIGINAL COMPLETION 02/02/16 CRR/14/3 CORRECTED LNR TYPOS VVELL: C-07A 02/10/90 N1ES R1AtO 07/10/17 BTTKND_SET FISWADPERFS(07/05/17) PERMf No: `2000520 10/08100 CTD SIDETRACK(C-07A) 09/08/17 DG/AU SET CIBP(09/07/17) AR No: 50-029-20128-01 10/14/06 D16 RINO SEC 19,T11 N,R14E 1766'FM.&879'FEL 11/07/06 MJA/PJC DRLG DRAFT CORRECTIONS 01/06/14 JDMJMD SET CUP/ADFERFS(12/30/13) BP Exploration(Alaska) N • 0 P 41115 tAs g cl i 2 moo > E - 3 <� o r ° �a E f� a 2 J Z (I r U N Y > kJ O c ° 1.5 a c o + ° o a) C >, 6 ..--, ( ., ru c N -6 Fµ-1 (, 0 "O a (a C r. C Q Y L O in M N N OC H ZQN -0M p ., r ill O C L 000000 000 C a) p L W J J J J J J J J J OA C 4 7 O y w w w w w w w w w 'N v C U `�' F- LL LL LL LL LL LL LL LL LL Y a) a) a) -0 0 <J J J J J J J J J a 0 > +-LN a a a a a a a a a 0) v) ,- w " ZO01, a Z Z Z Z Z Z Z Z Z u N ° '- Gi p LL LL LL LL LL LL LL LL LL ca L Q C > v 04 0• C) u • , Lh a a U aJ U w _Q C O ,-45,-, (6 Y ^'.. C F- t- > u u L C �" .0 d N I._ > u a) Y ��! '• O G V =i > > j j < CCJ a a C a CaVCo o ct al LL LL 2 Ly, ? _ 0 w a U O O U TI y G m [l m N Ix ix N U F- \. c•-•,‘ d al 8 _y b oZ ea • 0d i� O t,,, 2 6i1 At toW Q L > >., �. S� '"� U a O J O J J O J J J V CI Fi Z a (C - w V d 3 y 3 3 r 1,94P wI 2' m Y m m m m m m m a w n w w w w w w w 2 O Y 0 0 0 0 0 0 0 p 2 a 2 2 2 2 2 2 2 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ i w, aZaaaaaaa 0 W ,re •_C a i` V W co N O N �_ _ O v N X In O O f �',', Q N O O N _ N (O Q1 �V 0 0 0 0 0 0 0 0 (p O O c nonQ 0 o 9 0 0 O, O O O C W LR dao - ❑ a -� a,CO a (' O W ❑ ❑ p ❑ ❑ p ❑ O ❑ x CC CO Q O. laC N 0 •� N O O C n O O O O O O O O O Q V 0 (O M 0 ,-N CO N CO 0) 14, lt N (O 0 (O N M ,- M O) 4-, Fa- r4 O NN r 0 0 0 M O C m N a N N N N NN N N N N C 0 Q N N N N N N N N N c ° Q) 999999999 0 Y C Caa CO C N N N 1O N N (O N N a. -67 CO LriW L Z m E y to o 0 OD tii NGY W C H u 9 ~ 01 al e-( Q a m a 00 a m a r, a N a1 C -0 N 01 _E z bD ()1 Z O •- N , O O N M DJ aJ E H N C a Q O N W p Z , 0 0 0 Z Z H -O U Tv' C.7 u N ?� 03 c (13 C a O `�i a Q F' a a ra m STATE OF ALASKA I KA OIL AND GAS CONSERVATION COME ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforated Other D Pull/ReSet LTP Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other El Re-enter Suspended WE 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 200-052-0 3 Address P O Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-20128-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028285 PBU C-07A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 13260 feet Plugs measured 12260 fe E`�'(}��Qi E I\E D true vertical 900717 feet Junk measured None feet MAR 1 3 2015 Effective Depth measured 12260 feet Packer measured See Attachment feet ��true vertical 8995 74 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20"94#H-40 20 2-99 2 20 2-99 2 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12015-12045 feet 12330-12370 feet 12370-12610 feet 12610-12850 feet 13100-13201 feet True Vertical depth 8995 57-8995 56 feet 8999 32-9000 85 feet 9000 85-9006 feet 9006-9000 33 feet 8999 48-9003 06 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 15 07-9502 01 15 07-7289.23 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary. Intervals treated(measured) Treatment descriptions including volumes used and final pressure. SCANNED MAI,' .1 , ;i '1' 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 130 22922 10 1000 900 Subsequent to operation Well Shut-In 900 0 14 Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development CI Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16 Well Status after work Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron(c>7BP.Com Printed Name Garry Catron Title PDC PE Signature A 4Av�t, Ce d Phone 564-4424 Date 3/13/2015 VTL 3//-7/15 RBDMSJ4 MAR 1 6 2015 r Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription C-07A PACKER 9393.47 7209.22 4-1/2" Baker S-3 Perm Packer C-07A PACKER 9537.17 7315.3 3-1/2"TIW Packer C-07A PACKER 10180 7797.36 3-1/2" Baker KB Top Packer C-07A PACKER 11683.59 8934.21 3-1/2"TIW HBBP Packer m a o 0 0 0 co 0 a 0 0 !a N CO CO N t• N C to r` CO CO CC) N- N N N- C.) • 0 0 0 0 0 0 0 0 cc 0 CO O M N M C'M IC) CO 00 ' N O) O O) ▪ CO CO CO to 't CO CO O) CO N UC) N M N CO O) CO N CD O) N • O) N- CO CC) N O) CN- 0 0N COO N NN- CO O) - N N- ▪ i i I I I i I i H O) U) N- LO O) r, N CO ti CO O O CO 0 N Oj OD O CO O O Cui co co ' CC) N r- N- O) r CD O r` to _ O) M N O M CO N CO LO 01U) N � � r N O) LO 2 N CD d1 Q N ocoo_ o00o — Lr) ta w N NCONCO � N = 0O O O 0 0 Q 0 U o co00 00 Oo , , J Z C J Z Z N # Z N CO N u▪) V 00 � E00\00\00\0 � N "ca, M M M Ch N M co co L +- O CO N- co co Tr N- O O) N- CO '- O) M CO C N N- O) 00 0 Nr J N r` co — -- 0) W C I- 0 5 CO 0000000 V a cecLQ' a' LC LC LE Z Z• H H Z Z rxrxm • ZZJfn (I) Cl) H 2 - 0 7 k \ § » / > a \ k 0 m _ r R 46 e2 2 � /@ \ $ �m § ., -I -0 a f / '&a m g _ 22 --- >- z / \/ woo _1 —p E = w / \ 20_ 2 7 0 0 0 \ / 1- / - / p / p 0 b ' b c / c/ 0 / / z > / o 0 o ±_ g 0 - / % 0 o 0 0 / 2 / 0 a) \ �0_ _Z ƒ / '17, 2 ƒ_ O M, Z 0 0 0 ¢ ma c / 2 0 - q O E >_ 0 E / 0 \ \ / E k OW � 0601-O ® \ 2 ® r ©c \ E � 0 @ _12 y < » 2 \ 6 _0 0 � o < \ 0 0 &/ � / * 02 3 c = g t O 0 L\ / 2 / O m 0 i < _ / wzH ƒ ± ƒ iCC w 0 2 d \ / G I tt @ t 0U) / / CC / \ c \ i Z E c / / / -7 00_ b p_ \c %/ / 0 \ fCC\ O R a R e ƒ °G R < R < / a n < '� mr + E _. _1 < O _1 G& y \ & / & /ƒ / / 2 $ 2 ƒ / $ \ � E \ 2h2 \ \ \ . _/ / m0 „ „ LLI „mf mOr - oI / $ A ± &0 y R _ Lc2y \ r / ' \ / D/ ) b \mE / / / / \ < a / / 0 w 2 2 O -1 ^ T 0 0 ^ I ^ T = 0 m O O 2 u 220 / ƒ / / / f / ƒ / ƒ \ ƒ w ƒ / C) 9 / { E f { E m t i 2 2 cc (7)I m ± t i l t Lc) r r m / \ CN \ \ n $ a CN & R \ WELLHEAD= MCEVOY -0 7A S .Y NOTES: WELL ANGLE>—70°@ 11772' AG"TUATOR= OTIS "4-112"CHROME TBG** OKB.ELEV= 55.65' ) �I I� I BF.ELEV= 36' KOP= 2700' 211T -{4-1/2"HES X NP,D=3.813" Max Angle= 96'@ 12900' I U Datum MD= 11559' Datum TV D= 8800'SS _ — ---I 2690' -j FULL OPENING CBv 1Tl32 9-5/8"CSG,47#,L-80 NCSS,D=8.681" --I 2107' GAS LFT MANDRELS 13-3/8"CSG,68/72#,N-80, H 2691' ST MD ND DEV TYPE VLV LATCH PORT DOTE 68#,D=12.415"/72#,D=12.347' LI 4 3007 3007 7 MMG DOME RK 16 11/15/06 3 5837 5192 55 WAG DOME RK 16 11/15/06 2 8359 6603 58 MAG DMY RK 0 10/14/06 1 9294 7137 44 WAG SO RK 22 11/15/06 Minimum ID = 1.81" @ 10180' 3-1/2" KB LINER TOP PACKER1 I9373' —{4-112"HES X NP,D=3.813" R X J404' H4-1/2"X 9-5/8"BKR S-3 PKR, ID=3.870" I I 9438' H4-1/2"HES X NP,D=3.813" 4-1/T TBG, 12.6#,13CR-80 VAN TOP. —I 9501' .0152 bpf,ID=3.958" C 9504• —I3-1/2"OTIS X IsNa,D=2.750" TUBING STUB(10/18/06) — 9502' 9512' —49-5/8'X 3-1/2"MOQUE OVERSHOT 3-1/2"TBG,9.2#,L-80 IDS,.0087 bpf,ID=2.992" —I 2015' J 9522' —I TNV SBR,13=4.0" X 9540' —I9-5/8"TNV HBBP-R PKR,ID=4.00' 7"BOT PBR H 9601' 9601' -7'FBR(40'BOT) TOP OF 7"BOT LNR HGR -4 9643' I r,• 9-5/8"CSG,47#,N-80,MRS,ID=8.681" -.1 10099' I'-, , 10180' 3-1/2"BKR KB PKR,D=1.81"(02/09/15) TOP OF 2-3/8"LW? H 10188' 71 10188' BKR DEPLOY SLV,D=1.969'(OD=2.70') 3-1/2""WFPSTOCK(w/RA TAG @ 11475') —I 11470' 3-1/2"TBG,9.2#,L-80 TOS,.0087 bpf,ID=2.992" H —11479 MLLOUT WNDOW(C-07A) 11479'-11488' 7'LNR,29#,N-80 BTRS,.0371 bpf,D=6.184" -1 -11479 PEFFORATION SUMMARY RT LOG: CN-FD ON 09/03/73 • % 12260' H2-3/8"WFD CEP(12/30/13) ANGLE AT TOP PERF: 90'@ 12015' I / , Note:Refer to Production DB for historical pert data , SIZE SPT SHERVAL Opn/Sqz SHOT SQZ 1���1�1�1��2 .�.�.�x.1.1.1. 1-9/16" 6 12015-12045 0 12/30/13 , 1-11/16' 4 12330-12370 C 10/09/00 1-11/16" 6 12370-12610 C 10/09/00 12314' H PBTD 1 1-11/16" 4 12610-12850 C 10/09/00 1-11/16" 4 13100-13201 C 10/09/00 4kN 2-3/8"LNR,4.4#,L-80 FL4S, H 12351' .0087 bpf,ID=1.995" DATE REV BY CONTENTS DATE REV BY CONSENTS PRUDHOE BAY UNIT 01/30/78 ORIGINAL COMPLETION 02/10/15 GC/PJC AR NO CORRECTION WELL: C-07A 02/10/90_ N1ES R?JO 02/10/15 PJC 2-7/8"LIR CORRECTIONS PERMT No:"2000520 10/08/00 CTD SIDETRACK(C-07A) 02/09/15 SWC./PJC RJLL/RESET LIP AR No: 50-029-20128-01 10/14/06 D16 RANO SEC 19,T11N,R14E,1766'FNL 8 879'FEL 11/07/06 MMA/PJC DRLG DRAFT CORRECTIONS 01/06/14.JCMJMD SET C18P/ADPERFS(12/30/13) BP Exploration(Alaska) Ima( Project Well History File Cove{ ~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~0 O- O ~,~-~ Well History File Identifier RESCAN DIGITAL DATA J Color items: [] Diskettes, No.P/''/ OVERSIZED (Scannable) [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~WINDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation I x = 3© BY: BEVERLY ROBIN VINCENT SHERYL A~----~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES '"'"'~ DATE:A/-/~ ~_~c;/ ~--~Z:::> BY: BEVER'~..~B.~I~,) VINCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA~_~E FOUND: YES DUE TO QUALITY, GRAYSCALE OR COLOR IMAGE8 ) NO NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Oomments about this file: DATE: IS/ Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF A, :A OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS JAN 2 7 2014 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U `/�. Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver El Time Extension❑ AOGC Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number Name: BP Exploration(Alaska),Inc Development0 Exploratory ❑ ♦ 200-052-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 • 50-029-20128-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028285 Q PBU C-07A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ' PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured s 13260 feet Plugs measured 12260 feet true vertical 9007.17 feet Junk measured None feet Effective Depth measured 12260 feet Packer measured See Attachment feet true vertical 8995.74 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 68 20"94#H-40 30-98 30-98 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12015-12045 feet 12330-12370 feet 12370-12610 feet 12610-12850 feet 13100-13201 feet True Vertical depth 8995.57-8995.56 feet 8999.32-9000.85 feet 9000.85-9006 feet 9006-9000.33 feet 8999.48-9003.06 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 1 RBDM�MAY 17 2014 Treatment descriptions including volumes used and final pressure: SCANNED MAY 2 9 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 355 27210 26 0 900 Subsequent to operation: 236 22797 18 0 900 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ,❑ Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGEI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A — Contact Nita Summerhays Email Nita.Summerhaysabp.com Printed Name Nita Summerh- s Title Data Coordinator Sig,-tur- '�i,/�/1,0051111,_ ` , Phone 564-4035 Date 1/27/2014 3Tz0 /1 7,:._ Form 10-404 Revised 10/2012 ,�%40r Submit Original Only Daily Report of Well Operations ADL0028285 CTO1$-w 1.5"ct:Job objective Drift PPROF w/GHOST/ Borax MCNL/CIBI6 Perforate MIRU/Wittiness Weekly BOP test . 12/26/2013 ***Job continued on WSR 12-27-2013*** ***Job continued on WSR 12-28-2013*** CTU #8 w/ 1.5" ct: Job objective Drift/ PPROF w/GHOST/ Borax MCNL/CIBP/ Perforate SLB: CTC 1.69"x .083', Xover 1.75"x 1.140', Stinger 1.75" x 4', Stinger 1.75" x 4', DJSN 1.75 x .583, (OAL 10.023). RIH w/drift. Tagged @ 13202'Elec.PUH for flag CT yellow/red at 13140' Elec. Mech 13129' . M/U PPROF BHA and began RIH 12/27/2013 ***Job in progress*** ***Job continued from WSR 12-28-2013*** CTU#8 w/ 1.5"ct(28.1 BBL): Job objective Drift/ PPROF w/GHOST/ Borax MCNL/ CIBP/ Perforate Pumped 1.5X wellbore volume, M/U IPROF tool string for Borax MCNL, RIH pumping 1 bpm 12/29/2013 ***Job in progress*** ***Job continued from WSR 12-28-2013*** CTU #8 w/ 1.5" ct(28.1 BBL): Job objective Drift/ PPROF w/GHOST/Borax MCNL/ CIBP/Perforate Pumped 1.5X wellbore volume, M/U IPROF tool string for Borax MCNL, RIH pumping 1 bpm. Perform IPROF logging intervals at from 11600' - 13188' at 60 ft/min. Perform Borax logging at intervals 11600'- 13188' ft. At surface with IPROF, got good data. Recieved call from Town APE to proceed with OPTION 3 go ahead with setting the plug at-12,260' and 30' of perfs. Pumped freeze protect on flowline, made up CIBP: 1.69 CTC, 1.69 MHA(5/8 BALL DISCO), 1.69 XO, 1.69 BALL DIVERTER SUB, 1.69 HST, 1.75 WLAK, 1.75 CIBP. RIH. 12/29/2013 ***Job in progress*** ***Job continued from WSR 12-29-2013*** CTU#8 w/ 1.5" ct(28.1 BBL): Job objective Drift/ PPROF w/GHOST/ Borax MCNL/ CIBP/Perforate Proceeding with OPTION 3, set CIBP @ 12,260' and add 30'of perfs 12015-12045. RIH w/CIBP: 1.69 CTC, 1.69 MHA(5/8 BALL DISCO), 1.69 XO, 1.69 BALL DIVERTER SUB, 1.69 HST, 1.75 WLAK, 1.75 CIBP.Correction: 12240.1 (uncorrected depth) -30.08 (logging tool length) + 15 (correction) = 1225.02 (corrected EOP) + 10.44 (EOP to COE) = 12235.46 COE at flag. CIBP set at 12260, POOH. 1/2" ball recovered from CIBP setting tool. MU perf guns. BHA: PERF GUNS: WFD MHA CTDC 1.69 x .28', DFCV 1.688" x 1.76', SLB Firing head 1.69", x 3.07', 20 ft. Perf gun 1.56" x 20', Perf gun 1.56"x 10'ft. Bottom nose 1.56"x .70' (AOL 35.80'). Tag CIBP at 12260' Elec. Mech 12245', PUH to reconfirm tag 20 k up wt. PUH WT. back at 12253' Elec . Mech 12237' correct depth to 12259.3'. PUH toperforate depth top shot 12,015' bottom shot 12,045' CTM. Freeze protect tubing 38 bbls. At surface w/guns confirmed holes. 1/2" ball recovered. Coil crew conducted drill simulating a substantial flange leak beneath the BOPs and above the SSV. See notes. 12/30/2013 ***Job in progress*** T/I/O = SSV/750/580. Temp = SI. IA FL (eval TxIA). IA Fl @ 8990' (302' above sta#1 S/O, 481 bbls). Job complete. 1/3/2014 SV, WV,SSV= C. MV= O. IA, OA= OTG. NOVP 12:35 Hrs Daily Report of Well Operations ADL0028285 FLUIDS PUMPED BBLS 243 60/40 METH 365 DEAD CRUDE 633 1% SLICK KCL WITH SL 196 BORAX 1437 TOTAL m o (0 co O O O O o co N N O O N O LO L() 0 N- t N N Oa U o' 0 0 0 0 0 0 0 0 0 M O (,)(V) N M O 3 Ln 00 CO 0) 0 V- a m 00 CO CO r 0 00 L1) (O (A I - V 00 L() 0 0) 0) d O O 00 CO (fl a0 Ln O 00 co (3) c000cotoa) coco f� Cr) �- N (O N N- O N N N 00 I r N- CO N- a0 c0 O 0) 0) V O (fl O O N Ln (V 00 co00 N N ate.+ N- I� N C co O) 0) CO _ _ oO I� V O O Ln O O N- o-) O V N O '- O O)N O N O � r V I i I i i i I i a N co N- CO OO 0000) Ln L00 C) (V M CO N '— N N N Ln C c 0) .- N O Ja Q▪ O ▪ a CD c) co co , 00 op CO U CO 1- 09ZZc0 C) NEa000O1- N ON M Lf) Lo M M N 0!) O c M V t ++ N- — 0) N N- Lo CO N- 0)co I— O N- 0) N cf) N- C CO 00 O O 0) N V t 0) CO N f� Z Z p O O w yD 000000 0 ct 00 LL_ Z Z U rYtYFacTo O Z Z CC CC D D DD O J -J0 0 WC/) HH Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription C-07A PACKER 9404 7161.25 4-1/2" Baker S-3 Perm Packer C-07A PACKER 9540 7261.7 3-1/2" TIW Packer C-07A PACKER 10183 7743.8 3-1/2" Baker KB Top Packer C-07A PACKER 10188 7747.37 3-1/2" Baker Liner Top Packer TREE= CM/ 1M3.U-EAD= MCEVOY SAFETY NOTES: WELL ANGLE>—70°@ 11772' ACTUATOR= Og$S' ����� I '"4-1/2"CHROME TBG** OKB ELEV= S BF.ELEV= 36' KOP= 2700' Max Angle= 96'@ 12900' J Datum MD= 11559' Datum TVD= 8800'SS ' ' 2117' —4-1/2"FES XNP,D=3.813' 9-5/8"CSG,47#,L-80 NCSS,ID=8.681" H 2107' 2690' FULL OPENMNG CEME7(TET2 I GAS LFT MANDRELS S4T 3007MD 1 3007l DEV VLV LATCH PORT11L1A TE 13-3/8"CSG,68/72#,N-80, —I 2691' 7 MAC DONE 68#,D=12.415'/72#,D=12.347" H 16 3 5837 5192 55 MCDOME RK 16 11/15/06 2 8359 6603 58 kIMO DMY FE 0 10/14/06 Minimum ID = 1.81" 10183' 1 9294 7137 44 MM3 SO RK 22 11/15/06 3-1/2" KB LINER TOP PACKER I I I 9373' H4-1/2"FES xt ,D=3.813" X I 9404' —14-1/2"X 9-5/8"BKR S-3 PKR, D=3.870" ' Ir 9438' —14-1/2"FES X NIP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, --I 9501' .0152 bpf,D=3.958" __ / TLPNG STUB(10/18106) H 9504' /�I I 95E-15471-13 1/2"OTiS X NP,D=2.750' -I 9512' —3-1/2"X 9-5/8'LAVOIE OVERSHOT, 3-1/2"TBG,9.2#,L-80 TDS,.0087 bpf,D=2.992" D=2.992" 9522' H TNN SBR,D=4.0" Zi ><-1 9540' —19-5/8"11W FEIBP-R PKR,D=4.00" 7'BOT PSR 9601' 9601' H7"PBR(40'BOT) TOP OF 7"BOT LNR HGR —1 9643' 9-5/8"CSG 47#,N-80,BTRS,D=8.681' H 10099' • , 10183' 3-1/2"BKR KB PKR,ID=1.81"(03/25/11) TOP OF 2-3/8"LNR I-- 10188' J 10188' BKR DEPLOY SLV,D=1.969"(OD=2.70") 3-1/2"TBG,9.2#,L-80 TDS,.0087 bpf,ID=2.992" —{ —11478 ' 7"WFPSTOCK(w/RA TAG @ 11476') H 11470' ?? —13-1/2"TBG STUB PERFORATION SUMMARY REF LOG: MR)ON 09/03/73 j M ILLOUT WIM)OW(C-07A) 11478' ANGLE ATTOP FERF: 90"@ 12015' ` __ �—, Nate:Refer to Production DB for historical pert data , —`_' SIZE SPF NTERVAL Opn/Sqz SHOT /SOZ k 12260' --12-3/8"WFD CSP(12/30/13) 1-9/16" 6 12015-12045 0 12/30/13 k/ 1111111 Ar ,, __ 1-11/16' 4 '12330-12370 C 10/09/00 111111 11111111111i1 1-11/16' 6 12370-12610 C 10/09/00 .1.61.1.1.1.1. 1-11/16" 4 12610-12850 C 10/09/00 1-11/16' 4 13100-13201 C 10/09/00 13213' —) PBTD 7'LNR,29#,N-80 BTRS,.0371 bpf,D=6.184' H 11803' 2-3/8'UDR,4.4#,L-80 FL4S,.00387 bpf,D=1.995" 13249' DATE REV BY COM.ENTS T DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/30/78ORIGINAL COMPLETION !) WELL C-07A 02/10/90 141 ES Ff1NO PERMT No:"2000520 10/08/00 CTD SIDETRACK(C-07A) —1 AR No: 50-029-20128-02 10/14/06 D16 RWO SEC 19,T11N,R14E, 1766'FTNL&879'FEL 11/07/06 MMA/PJC DRLG DRAFT CORRECTIONS 01/06/14 JDNJMD SET CSP/ADPERFS(12/30/13) BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 . 7'y'W. .'S' Fr y2 .11 August 22, 2011 ' RECEIVED' Mr. Tom Maunder AUG 31 2O1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Alaska Off & Gas Cos. Gonvnission Anchorage, Alaska 99501 Aactiarage Subject: Corrosion Inhibitor Treatments of GPB C -Pad 2, 0 0 ° Dear Mr. Maunder, C, 0 7ti Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, 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) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C - 20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C - 23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -288 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 STATE OF ALASKA ALASKAIDAND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Ei LINER TOP PACKER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ r 200 -0520 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 1 50- 029 - 20128 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028285 w PBU C -07A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13260 feet Plugs (measured) None feet true vertical 9007.17 feet Junk (measured) None feet Effective Depth measured 13213 feet Packer (measured) 9404, 9540 10183 10188 feet true vertical 9004.09 feet (true vertical) 7217, 7317 7800 7803 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 20" 94# -1-40 30 - 98 30 - 98 1530 520 Surface 13 -3/8" 72# N -80 29 - 1256 29 - 1256 4930 2670 Surface 13- 3/8 "68# N -80 1256 - 2691 1256 - 2691 4930 2270 Production 9 -5/8" 47# L -80 28 - 2107 28 - 2107 6870 4760 Production 9 -5/8" 47# N -80 2107 - 10099 2107 - 7739 6870 4760 Liner 7" 29# N -80 9601 - 11478 7363 - 8787 8160 7020 Liner 2 -3/8" 4.7# L -80 10188 - 13249 7803 - 9007 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 25 - 9501 25 - 7288 3 -1/2" 9.2# L -80 9501 - 11478 7288 - 8787 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 PKR 9404 7217 3 -1/2" TIW Packer 9540 7317 3 -1/2" Baker KB Top Packer 10183 7800 3 -1/2" Baker Liner Top Packer 8 R 10188 803 12. Stimulation or cement squeeze summary: APR R �r © 2 0 1 IVE Intervals treated (measured): mAr',, i Treatment descriptions including volumes used and final pressure: Alaska Ciii & Gas Cons. Commission 13. Representative Daily Average Production or InjectinQ r ge Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 708 241,550 24 860 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 It Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil p 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e Jo- Lastu - I, I Title Data Manager Signatur= Mali Phone 564 -4091 Date 3/28/2011 Form 10-404 Revised 10/2110 % E N S ` MA 3 0 2011 F'-� ,A, y 7 / S mit Original Only C -07A 200 -052 PERF ATTACHMENT Sw Name Operation Date Peri Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -07A 10 /7/00 PER 12,330. 12,370. 8,999.32 9,000.85 C -07A 10/7/00 PER 12,370. 12,610. 9,000.85 9,006. C -07A 10/7/00 PER 12,610. 12,850. 9,006. 9,000.33 C -07A 10/7/00 PER 13,100. 13,201. 8,999.48 9,003.06 C -07A 7/16/06 BPS 10,189. 13,201. 7,803.79 9,003.06 C -07A 10/27/06 BPP 10,189. 13,201. 7,803.79 9,003.06 C -07A 3/7/11 BPS 9,422. 13,201. 7,230.18 9,003.06 C -07A 3/17/11 BPP 9,422. 13,201. 7,230.18 9,003.06 C-07A 3/18/11 BPS 9,422. 13,201. 7,230.18 9,003.06 C -07A 3/24/11 BPS 9,422. 12,330. 7,230.18 8,999.32 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • C -07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/7/2011 ***WELL FLOWING ON ARRIVAL * ** DRIFT TUBING W/ 2.74" SPECIAL CLEARENCE WRP DRIFT, SD @ 10,174' SLM LRS LOADED TUBING W/ 5 BBLS OF METHANOL & 195 BBLS OF CRUDE 'SET LTTP IN LINER TOP @ 10,174' SLM/ 10,188' MD 1 LRS MITxT TO 3000 PSI MIT T FAIL. LRS ESTABLISH LLR OF .35 BBLS/ MIN !SET 4-1/2" XX -PLUG AT 9,422 SLM/9,438 MD. 1 LRS PERFORM PASSING MIT -T TO 3000# * * *RDMO,LEFT WELL SHUT IN,PAD OP NOTIFIED * ** I ' 3/7/2011 T /I /0= 2650/1100/650 Assist SLB Load & MIT T FAILED to 3000 psi (Evaluate for ,liner top packer) (MITx TBG to 3000 Psi Passed After 2nd plug set by S -Line) ( Test 1 #1) Load tbg with 5 bbls neat meth, 190 bbls crude. attempt MIT T to 3000 psi with 110 bbls crude. TP lost 2600 psi in 20 mins. establish LLR @ .35 bpm with 13 bbls Icrude.Standby for S -Line to RIH to reset plug. ( Test # 2) Pump 6.3 bbls dead crude down TBG to achieve a test pressure of 3000 Psi. MITxT / TBG lost 120 psi in 1st 15 !Min and 60 Psi in 2nd 15 Min for a total Toss of 180 Psi in 30 Min test. (MITx TBG to :3000 Psi Passed,) Standby for S -line to Rig down . Rig to IA. PT to 3500 Psi . !Standby for new procedure. WSR continued on 03- 08 -11. 3/7/2011 T /I /O = 500/940/540. Temp = SI. Tbg, IA FL. (FB). Tubing FL @ surface. IA FL @ 9020' (500 bbls). 1 *FB in control of well upon departure* I � 3/8/201f 1T/1/0= 2550/1100/650 ( Load Tx IA / CMIT Tx IA to 3000 Psi PASSED / FP FLowline 1) Pump 480 bbls dead crude @ 5 bpm down IA / Reduce rate to 1 bpm and pump 165 bbls dead crude down IA to load Tx IA. (CMIT Tx IA) Pump 48.8 bbls dead crude to achieve a test pressure fo 3000 Psi. PASSED 3rd attempt. Lost 0 psi 1st 15 =min, 0 psi 2nd 15 min. Freeze protect flowline w/ 5 bbls neat meth, 260 bbls crude, &I 1 5 bbls neat meth. FWHP's= 840/300/620 SV, WV =S /I SSV, WV =O IA, 0A =OTG 'Tags hung Pad Op notified. i j 1 • E _ 3/17/2011 * * * WELL S/I ON ARRIVAL * ** (pkrs / bridge plugs) 1 EQ AND PULL XX PLUG @ 9,435' SLM (9,438' MD) 1 EQ AND PULL CAT STANDING VALVE @ 10,184' SLM (10,188' MD) 1***CONT. WSR ON 3/18/11, PAD -OP NOTIFIED OF STATUS * ** € j i E 3/18/2 10 1 T /I /0= 700/80/440 Temp =SI Assist SL TBG Load / MIT -TBG FAILED to 3000 psi (Evaluate for liner top packer) Pumped 5 bbls neat meth & 180 bbls crude down ITBG to Toad while SL brushed BKR SLV. Continued pumping additional 7 bbls crude @ .5 bpm while SL POOH. Pumped additional 16 bbls crude @ .5 bpm while SL RIH and set Cat Standing Valve. Preeured up to 2000 psi. SD to put test guage on Lube, :TBG fell from 2000 psi to 1100 psi in 3 min. Pumped an additional 20 bbls crude 'down TBG to bring to 3000 psi & establish a -LLR of .65 bpm @ 3000 psi for 10 min -. Slickline in control of well upon departure. FWP= 100/100/440 * *IA & OA =OTG ** 3/18/2011 * ** WSR CONTINUED FROM 3/17/11 * ** (pkrs / bridge plugs) ILRS LOADED TUBING W/180 BBLS CRUDE !BRUSHED DEP. SLV @ 10,188' MD W/2.25" BRAIDED LINE BRUSH !SET CAT STANDING VALVE @ 10,185' SLM (10,188' MD) =UNABLE TO MIT -T, LIQUID LEAK RATE .65 BBLS /MIN @ 3,000 PSI. ** *WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS * ** 1 1 3/24/2011 * ** WELL SHUT IN ON ARRIVAL * ** [ IRAN 3 1/2 GS W/ 2.70 DUMMY DRIFT (125" OAL) SAT DOWN ON TOP OF LNR@ 10,180 SLM,ALL CLEAR,RDFN. I * ** LAY DOWN EQUIP. FOR THE NIGHT. * * * * ** I 3 [ � 3 3/25/20111*** CONT FROM TICKET 3/24/11 * ** !RAN HES DPU W/ BAKER KB PACKER,SET (ti 10,183 SLM.GOOD SET. IRAN 3 1/2 LTTP IN PACKER@ 10,183 SLM.LRS MIT TO 3000 PSI. MIT TO 3000 PSI PASSED, PULLED LTTP @ 10,183 SLM.RDMO. 1 * ** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. * * ** 1 • • 3/25/2011 iT /I /0= 100/60/360 Temp =S /I Assist Slickline, MIT -T PASSED to 3000 psi (Evaluate Ifor liner top packer) Loaded Tbg with 52 bbls crude. MIT -T: Tbg lost 140 psi in 1st 15 mins and 40 psi in 2nd 15 mins for a total Toss of 190 psi in 30 min test. Final WHPs 1200/60/360 Slickline still on well at time of departure 3/27/2011 IT /I /O= 950/1540/600. Temp= Hot. OA FL (Call -in). Temp AL jumper from C -32 online. OA FL @ 440'. SV =C. WV, SSV & MV =O. IA & OA =OTG. 3/27/2011 TWO = 750/1620/950. Temp =48 °. Bleed OAP as needed (Eval high OAP). PBGL is E hardlined from C -32. OA FL @ 440'. Bled OAP,to C -31 flow line, from 950 psi to 3601 psi in 1 hr, fluid to surface. OAP would not bleed below 360 psi. Monitor for 1 hr. l OAP increased 140 psi (0000 hrs). See log for details. Re -bled OAP from 810 psi to 1310 psi in 1 hr, fluid to surface. Monitor for 40 min. OAP increased 150 psi. Job complete. Final WHPs= 820/1530/450. SV= Closed. WV,SSV,MV =Open. IA,OA =OTG. NOVP. FLUIDS PUMPED BBLS 1442 CRUDE 20 NEAT METH 2 DIESEL 1464 TOTAL � _ CM/ • SAFETY.S: "4-1/2" CHROME TBG** WELLHEAD = MCEVOY ACTUATOR = — OTIS C -07A KB. ELEV = 55.65' BF. ELEV = 36 KOP = 2700' Max Angle = 96' © 12900' 1 Datum MD = 11559' ' r —I 2117' H4-1/2" HESXNIP, ID = 3.813" I _ Datum'ND = 8800' SS ID = 8.681" 2107' —1 2690' H FULL OPENING CEMENTER I 19-5/8" CSG, 47 #, L -80 NCSS, H • GAS LIFT MANDRELS 13 -3/8" CSG, 68/72 #, N-80, — I 2691' ST1 MD TVD DEV TYPE VLV LATCH PORT DATE 4 3007 3007 7 MMG DOME RK 16 11/15/06 68 #, ID = 12.415" 172 #, ID = 12.347" 3 5837 5192 55 MMG DOME RK 16 11/15/06 2 8359 6603 58 MMG DMY RK 0 10/14/06 1 9294 7137 _ 44 _ MMG SO RK 22 11/15/06 Minimum ID =1.81" @ 10183' i I 9373' H4 -1/2" HESXNIP, ID= 3.813" 1 3 -1/2" KB LINER TOP PACKER 1 9404' 1--4-1 /2" X 9 -5/8" BKR S -3 PKR, ID = 3.870" I 4 9501 I 9438' H4-1/2" HESXNIP, ID = 3.813" -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" (TUBING STUB (10/18/06) I - 1 9504' 9504' H3-1/2" OTIS X NIP, ID = 2.750" , � 9512' I--I -1/2" X 9 -5/8" UNIQUE OVERSHOT, I3 -1/2" TBG, 9.2 #, L -80 TDS, .0087 bpf, ID = 2.992" I ID = 2.992" I 9522' 1 SBR, ID = 4.0" I pl ,= 9540' H9-5/8" TIW HBBP -R PKR, ID = 4.00" 17" BOT PBR H 9601' 9601' H7" PBR (40' BOT) I 'TOP OF 7" BOT LNR HGR H 9643' 19-5/8" CSG, 47 #, N-80, BTRS, ID = 8.681" H 10099' 10183' I 13 -1/2" BKR KB PKR, ID = 1.81" (03/25/11) I ITOP OF 2 -3/8" LNR I-1 10188' ..111 10188' I I BKR DEPLOY SLV, ID = 1.969" (OD = 2.70 ") 1 I3 -1/2" TBG, 9.2 #, L -80 TDS, .0087 bpf, ID = 2.992" I-1 — 11478 17" WHIPSTOCK (w/ RA TAG @ 11475') H 11470' ?? H3 -1/2" TBG STUB I PERFORATION SUMMARY MILLOUT WINDOW (C -07A) 11478' REF LOG: CN-FD ON 09/03/73 ANGLE AT TOP PERF: 87 @ 12330' Note: Refer to Production DB for historical perf data , SIZE SPF INTERVAL Opn /Sqz DATE ����� 1- 11/16" 4 12330 -12370 0 10/09/00 'MAW 1-11/16" 6 12370 - 12610 0 10/09/00 MYNA 1- 11/16" 4 12610 - 12850 0 10/09/00 1- 11/16" 4 13100- 13201 0 10/09/00 13213' H PBTD •�» 17" LNR, 29 #, N -80 BTRS, .0371 bpf, ID = 6.184" I--I 11803' 1 1 2 -3/8" LNR, 4.4#, L -80 FL4S, .00387 bpf, D= 1.995" H 13249' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/30/78 ORIGINAL COMPLETION 07/30/09 TLH REMOVE LTTP PLUG SYMBOL WELL: C-07A 02/10/90 NI ES RWO 08/08/09 ATD/TLH COMMENT CORRECTIONS (CTD; PERMIT No:'"2000520 10/08/00 CTD SIDETRACK (C -07A) 03/09/11 SWC/PJC SET XX PLUG/ LTTP (03/07/11) API No: 50- 029 - 20128 -02 10/14/06 016 RWO 03/26/11 MBM/PJC PULL XX PLUG/ SET LTP (03/17- 25/11) SEC 24, T11 N, R13E, 1766' SNL & 879' WEL 11/07/06 MJA / PJC DRLG DRAFT CORRECTIONS 03/26/11 JNL /PJC LOCATION CORRECTION 107/27/09 RPH/PJC DELETE SAFETY NOTEANNCOM BP Exploration (Alaska) . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL ()PERATIONSC:T2 7 1. Operations Performed: H{~ '" ¡hi z',: U,;., , " "?¡~,~I'<' . ". ..... ...,."',",, tf".", r:,n AbandonO Repair Well 00 Pluç PerforationsD Stimulate 0 . 1',< "Qth~r ".,,,',., Alter Casing 0 Pull TubingOO Perforate New PoolO WaiverD Ti~~ 'Ext~~~¡~nD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended wellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD # 200..0520 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519·6612 StratigraphicO ServiceD 50-029-20128-01-00 7. KB Elevation (ft): 9. Well Name and Number: 55.70 C·07 A 8. Property Designation: 10. Field/Pool(s): ADL·028285 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 13260 feet true vertical 9007.0 feet Plugs (measured) L TTP Set in BKR DEPLOY SLY @ 10188 (07/16/06) Effective Depth measured 13213 feet Junk (measured) None true vertical 9004.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 20" 94# H·40 30 - 98 30.0 · 98.0 1530 520 SURFACE 2662 13-3/8" 68#/ 72# N-80 29 . 2691 29.0 - 2691.0 5020/ 5380 2260/2670 PRODUCTION 2079 9·5/8" 47# L·80 28 - 2107 28.0 · 2107.0 6870 4760 PRODUCTON 7992 9·5/8" 47# N·80 2107 - 10099 2107.0 · 7739.0 6870 4760 LINER 1877 7" 29# N-80 9601 - 11478 7363.0 · 8787.0 8160 7020 LINER 3061 2-3/8" 4.4# L-80 10188 - 13249 7803.0 - 9006.0 11200 11780 ... ,. """. (,:.;,<;\IL::L, Perforation depth: Measured depth: 12330·12370,12370-12610,12610-12850,13100-13201 True vertical depth: 8999-9001,9001.9006,9006·9000,8999·9003 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 YAM TOP @ 25 - 9501 3-1/2" 9.2# L-80 @ 9501 . 11478 Packers & SSSV (type & measured depth): 9·5/8" Baker S-3 Packer @ 9404 9-5/8" TIW HBBP-R Packer @ 9540 7" BOT Packer @ 9601 4-1/2" HES X Nipple @ 2117 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO completed ..- cut & replaced part of TBG with 4-1/2" Chrome TBG. 13 ReDresentative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-BbJ Casing Pressure TubinQ Pressure Prior to well operation: 51 0 0 -.. 0 Subsequent to operation: 51 0 0 ..- 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentOO ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAGD GINJD WINJO WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 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: Contact DeWayne R. Schnorr 306·319 Printed Name DeWayne R. Schnorr " Title Petroleum Engineer Signature A~_h _ /f. ~ f.. :J Phone 564-5174 Date 1 0/26/06 R8DMS 8Ft 0 CT 3 ] 2006 Form 10-404 Revised 4/2004 TREE: 4-1/18"CMf5M WElLHEAD: 13-5/8" 5M WCÐIOY ACTUA TOR: OTIS KB. B..EV = 55.65' BF. B..EV = 36' KOP = 2700' Max Angle: 96' @ 12900' Datum MD = 11559' Datum TVO = 8800' SS 19-5/8" CSG, 47#, L-80 NeSS, ID = 8.681" I PJC DRAFT C-07 A S OTES: IA& TBGANNULARCOMM NOTED AT BEGINNING OF DRlG. ***IA X OA COMM. MAX lAP = 2000 PSI; MAX OAP = 2000 PSI. (04/01/03 WAlVER)***4-1/2" CHROMETBG"** 2107' -14-112" HES X NIP, ID = 3.813" 13-3/8" CSG, 68172#, N-80, 68#, ID = 12.415" /72#,10: 12.347" Minimum ID = 1.969" @ 10188' 23/8" LINER TOP DEPLOYMENT SLV 4_1/2" TBG, 12.6#, 13CR-80 YAM TOP, .0152 bpf, ID = 3.958" WBING STUB 3-1/2" TBG, 9.2#, L-80 TDS, .0087 bpt, 10 2.992" TOP OF 7" BOT LNR HGR 19-5/8" CSG, 47#, N-80, BTRS, ID: 8.681" I TOP OF WHIPSTOCK PffiFORA TION SUMMARY REF LOG: CN-FO ON 09/03/73 ANGLE AT TOP ÆRF: 87 @ 12330' Note: Refer to A"oduetion OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE 1-11/16" 4 12330 - 12370 e 10/09/00 1-11/16" 6 12370 - 12610 e 10/09/00 1-11/16" 4 12610-12850 e 10/09/00 1-11/16" 4 13100 - 13200 C 10/09/00 17" LNR, 29#, N-80 BTRS, ,0371 bpf, 10 = 6.184" I 2690' -I FULL OPENING CEMENTffi GAS LIFT MANDRB..S ST MD TVO DE\! TYÆ VLV LATCH 4 3007 3007 7 MMG OCR RKP 3 5837 5192 55 MMG DMY RK 2 8359 6603 58 MMG DMY RK 1 9294 7137 44 MMG DMY RK 9373' -14-1/2" HES X NIP, 10: 3.813" I PORT OA TE o 10/14/06 o 10/14/06 o 10/14/06 o 10/14/06 9404' -14-1/2" X 9-5/8" BKRS-3 A<R, ID= 3.870" 9438' -I4-1/2"HESXNIP, 10=3.813" I 9504' -13-1/2" OTIS X NIP, 10 = 2.750" I 9512' 3-1/2" X 9-5/8" UNIQUE OYERSHOT, ID = 2.992" 9522' 9540' -i 9-5/8" TMf HBBP-R A<R, 10 == 4.00" 9601' -17" FER (40' BOT) I 10188' 10188' 10188' LTTPSEfINBKROEPLOY SLY (07/16/06) I BKRDEPLOY SLV,ID= 1.969" (00=2.70") I H TOP OF 2-3/8" LNR I I MILLOUT WINDOW 11478' 11475' -i RA TAG I 2-318" LI'R, 4.4#, L-80 FL4S, '<XJ387 bpf, Ð= 1.995" DATE REV BY COMIiIENTS OATE REV BY COMMENTS PRUDHOE BAY UNfT 01/30/78 ORIGINAL COMPLETION 07/21/06 OPS/PJC 10-3/4" eSG CORRECTION WB..L: C-07A 10/08100 SIDETRACK WORKOVER 09/21/06 PClTLH CORRECTIONS (THERMAL CSG ÆRMfT No: '2000520 10/14106 D16 RWO 09/26/06 RLMlPAG LTTPSET(07/16/06) API No: 50-029-20128-02 04/01/03 JRC/KAK WArvER SAFETY NOTE 10/18/06 ? / PJC ORLG DRAFT CORRECTIONS SEC 24, T11 N, R13E, 1766' SNL & 879' WB.. 07/16/06 CJNlPJC PULL PXX & SET L TIP 07/16/06 BSElPJC GLV C/O BP Exploration (Alaska) . . C-07 A DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 03/18/2004 TIO=880/1420/460. Temp=SI. TBG & IA FL's (Post IA bleed). TBG FL at 9070'. IA FL at 4570' (between St. #4 & #5). TBG increased 380 psi, lAP increased 380 psi, & OAP increased 110 psi from yesterday. AWGRS 03/22/2004 ***WELL SHUT IN UPON ARRIVAL*** (SECURE WELL) PULL PX PRONG @ 9496' SLM. A WGRS 03/23/2004 PULLED DGL V/RA FROM ST A #1 @ 9472' SLM. PULLED DGL V/RM FROM ST A #2 @ 7989' SLM. SET DGLV/RA LATCH (EXT PKG) IN STA #2. SET DGLV/RM LATCH (EXT PKG) IN STA#1. RIH WITH 2.775" LIB, GOOD MARKS OF FISHING NECK. LATCHED AND PULLED 31/2" PX PLUG @ 9,491' SLM. SET 2.75" PX PLUG BODY @ 9,496' SLM. (OAL=24") SET PRONG @ 9,993' SLM. (1.75" FISHING NECK, OAL=76") BLED TUBING PRESSURE FROM 1800# TO 1500#. HELD ROCK SOLID. ***LEFT WELL SHUT IN UPON DEPARTURE*** AWGRS 03/28/2004 T/I/O=1650/1520/1040. Bleed WHP's (Post TTP). Temp SI. TBG FL @ 6991' st # 3), 107 bbls. IA FL @ 4980' (st # 4),285 bbls. Bled IA from 1520 psi to 400 psi in 3.5 hrs. IA FL remained at 4980'. OA FL @ 150'. Bled OA from 1040 psi to 660 psi in 1 hr. OA FL @ 150'. Monitored WHP's for 30 mins, OAP increased 10 psi. Final WHP's 1650/400/670. Will continue later. AWGRS 03/29/2004 TIIIO = 1060/600/740, temp = SI. Bleed WHPs post-TIP. Tubing FL @ 6631' (71 BBLs), OA FL @ 270' «15 BBLs).Tubing pressure decreased 590 psi, lAP increased 200 psi, and OAP increased 70 psi overnight. Bled tubing from 1060 psi to 300 psi in 45 minutes. Bled OA from 740 psi to 400 psi in 1 hour. Final WHPs = 350/570/400. AWGRS 03/30/2004 T/I/O = 460/570/470, temp = SI. Bleed WHPs post-TTP. Tubing pressure increased 110 psi and OA pressure increased 70 psi overnight. Bled OA from 470 psi to 310 psi in 1 hour 15 minutes. Bled IA from 570 psi to 330 psi in 1 hour 30 minutes. Bled tubing from 460 psi to 310 psi in 1 hour. Monitored WHPs 30 minutes. Final WHPs = 310/340/330. AWGRS 04/04/2004 T/I/O=480/400/350. (for F/B). TBG FL @ 6991' (107 bbls) fA FL @ 4980' (285 bbls) OA FL @ 330' (15 bbls). AWGRS 04/06/2004 TII/O=500/440/360 MIT Tubing to 3000 psi, PASSED (Eva!. for TBG repair) Pump 71 bbls crude down tubing to pressure up to 3000 psi, Start first test, TBG lost 430 psi in 15 min, Fail, Bump up wI .5 bbl crude, Start 2nd test, Lost 200 psi in 15 min, Fail, Bump up w/ .2 bbl crude, Start 3rd test, Lost 130 psi in 15 min, Lost 90 psi in 2nd 15 min, Fail, Bump up w/ .2 bbl crude start 4th test, Lost 60 psi in 15 min, Lost 20 psi in 2nd 15 min, Passed Bleed TBG Final WHP's=400/440/360 AWGRS 04/07/2004 Post MIT TBG Rig down & travel to EOA AWGRS 04/25/2004 WHP=200/500/500. MITIA FAILED, loses 100 psi! 15 min. Pumped 176.4 bbls crude to load & test. On four Attempts. CMIT TxlA PASSED to 2500 psi. Lost 50 psi in 1 st 15 min & 30 psi in 2nd 15 min. Unable to get LLR do to flowline being tied to the GC. Note: 350 bbl volume required to re-freeze protect flowline. Bleeding down tubing & I.A. Page 1 . . C-07 A DESCRIPTION OF WORK COMPLETED AWGRS 04/26/2004 Finished bleeding down tubing & I.A. to starting pressures. MITOA to 3000 psi (PASSED). Pumped 22.5 bbls crude to load & test. On Third Attempt, Loss 10 psi in 1st 15 min & 0 psi in 2nd 15 min. Bled down OA to starting pressures. Final TIO=260/420/500 AWGRS 05/01/2004 TIIIO = 210/390/400. TBG and IA FL's. (Waiver Eyal). TBG FL @ Surface. IA FL @ 325'. AWGRS 05/0712004 TIO=31 0/500/460 MIT IA to 2500 psi - FAILED (Tubing slowly tracks up w/ IA) Pressure IA to 2500 psi w/ 31 bbls crude, Start 1 st test, IA lost 220 psi in 15 min, Fail Bump up w/ .9 bbl crude, Start 2nd test, IA lost 100 psi in 15 min, Lost 60 psi in 2nd 15 min, Fail Bump up .5 w/ bbl crude, Start 3rd test, IA lost 60 psi in 15 min, Lost 40 psi in 2nd 15 min, Fail TP slowly tracked up from 310 to 2250 psi during testing IA to TBG LLR appx. 1.4 gpm CMIT T x IA to 2500 psi - PASSED Pressure TII to 2500/2540 psi, Start 1st test, TBG +50 psi & fA lost 40 psi in 15 min, TBG +50 & IA lost 20 psi in 2nd 15 min, Pass Bleed IA to 750 psi, TBG came down to 1500 psi RD lA, RU TBG MIT TBG to 3000 psi - FAILED (Did not show stabilization) Pressure up tubing to 3000 psi w/1 bbl crude, Start 1 st test, Lost 250 psi in 15 min, Fail Bump up w/ .2 bbl crude, Start 2nd test, Lost 200 psi in 15 min, Bump up w/ .2 bbl crude, Start 3rd test, Lost 150 psi in 15 min, Lost 200 psi in 2nd 15 min, Fail Bleed TBG Final WHP's=100/900/500 AWGRS 06/23/2004 *** WELL SHUT IN ON ARRIVAL*** TAG TOP OF TTP @ 9486' SLM W/ 2.5" CENT, 1.5" SAMP. BAILER *** LEAVE WELL SHUT IN *** AWGRS 06/23/2006 ***WELL SI ON ARRIVAL *** PULL EQUALIZING PRONG @ 9,498' SLM. JOB SCOPE CHANGE, RE-RUN EQUALIZING PRONG (1 3/4" FN, 76" OAL). SET PRONG @ 9,498' SLM. PERFORM DRAW TEST. BLEED TUBING PSI DOWN TO 20 PSI, GOOD TEST, RDMO. ***WELL LEFT SI*** AWGRS 07/15/2006 *** WELL SHUT IN *** (pre pwo work) DRIFTED TO TOP OF "P" PRONG @ 9,501' SLM. PULLED PX PRONG. **** JOB STILL IN PROGRESS**** AWGRS 07/16/2006 PULLED 1 1/2" DGLV WITH EXTENDED PACKING FROM STA# 1. PULLED 31/2" PXN PLUG @ 9,508' SLM. SET LTTP @ 10,189' SLM. RDMO. ****LEFTWELL SHUT- IN. STA# 1 IS STILL EMPTY, LEFT L TTP IN HOLE FOR UPCOMING WORK**** AWGRS 07/18/2006 T/I/O=240/290/320. Temp=SI. TBG, IA & OA FL (for EL). TBG FL @ 492'. IA FL @ 678'. OA FL @ 66'. AWGRS 07/22/2006 TIO = 180/360/450. Temp = SI. Bleed TBGP to zero (pre-EL). TBG FL @ surface. IA FL @ 540'. Bled TBGP from 180 psi to 130 psi in 50 mins (all fluid, 5.5 bbls). lAP decreased 40 psi. Bled lAP from 320 psi to 80 psi in 2 hrs, IA then went from gas to fluid, lAP & TBGP then began to climb. In 10 mins lAP @ 300 psi & TBGP @ 380 psi. IA & TBG FL's @ surface. Monitored for 30 mins. TBGP decreased 60 psi, lAP decreased 90 psi; TBG FL near surface, IA FL @ surface. Bled lAP from 210 psi to 110 psi in 30 mins (mostly fluid, 4.5 bbls). TBGP decreased 70 psi. Bled TBGP from 250 psi to 230 psi in 20 mins (mostly fluid, 1/4 bbl, bleed tank 1/2 full). Monitored 20 mins. TBGP decreased 20 psi, lAP increased 10 psi. FWHPs = 210/120/450. AWGRS 07/22/2006 TIIIO=300/300/400 (CMIT-TxIA) Pump 62 bbls dead crude down TBG to pressure up to 3000 Psi. MIT-T x IA. Pre-Test Press.=300/300/400. Initial Press.=3000/3000/500. 15 Min Press.=2800/2800/500.) Min Press.= 2700 Psi. CMIT= PASS. FWHP=375/375/450 Page 2 . . C-07 A DESCRIPTION OF WORK COMPLETED AWGRS 07/23/2006 TIO = 200/110/450. Temp = SI. WHPs (for EL). TBGP & lAP decreased 10 psi, OAP unchanged overnight. AWGRS 08/13/2006 ***WELL S/I ON ARRIVAL*** (pre rwo) UNABLE TO RIG UP DUE TO RIG WORKlHARDLlNE ON LOCATION. ***LEFT WELL S/I ON DEPARTURE*** AWGRS 09/07/2006 ***WELL S/ ON ARRIVAL*** RAN 10' * 2.50" DUMP BAILER, 2.15 BLIND BOX TO 10,143' (SLM) DUMPED SLUGGITS. AWGRS 09/08/2006 (RWO Prep) DUMPED BAIL 100# SLUGGITS FROM 10142' SLM TO 10128' SLM. (13' TOTAL) ***LEFT WELL S/I*** PAD OP NOTIFIED AWGRS 09/20/2006 T/I/O=S/I/800/320. (Pre-RWO). Freeze protect FL w/2 bbls meth followed by 138 bbls crude, 3 bbls meth, 227 bbls crude, & 2 bbls meth as per WOA procedure. FWHP=S/I=800/320. AWGRS 09/2012006 T/I/O=800/800/300 ( Circ - Out I Mit x OA ) Pump 215 bbls 60/40 meth down IA then Pump 36 bbls 60/40 meth down TBG For Circ - Out. Rig - Up To OA, MIT x OA To 2000 Psi. Initial Press. =800/720/2000. 15 Min Press.=800/720/1900. 30 Min. Press.=8001720/1850. MITx OA is a Pass. AWGRS 09/22/2006 T/l/O=400/400/300 Circ-out (Pre RWO) CMIT TxlAxOA to 2000 PASSED Freeze Protect TxlA & Flow Line. Circ Out--Pumped 5 bbls of neat methanol followed by 1073 bbls of 2% KCL down IA up tubing taking returns to the flow line. Freeze Protect IA with 215 bbls of 60/40 methanol & Tubing with 36 bbls of 60/40 methanol. CMIT TxIAxOA--Pumped 7.7 bbls of 60/40 methanol down tubing to reach test pressure. Tubing lost 40 psi in the 1 st 15 min and 20 psi in the 2nd 15 min, IA lost 20 in the 1 st 15 min and 20 psi in the 2nd 15 min, OA lost 60 psi in the 1 st 15 min and 40 psi in the 2nd 15 min. Total losses in the 30 min test. Tubing lost 60 psi. IA lost 40 psi. OA lost 100 psi. Freeze Protect the Flow Line with 7 bbls of 60/40 methanol and 365 bbls of crude. Final WHP's = 100/100/260 AWGRS 09/24/2006 ***WELL SHUT IN UPON ARRIVAL*** T/l/O= 010/240 PSI SHOT 12' STRING SHOT FROM 9487' - 9499'. AWGRS 09/25/2006 RAN IN HOLE TO 9600' WiTH 2 3/8" CHEMICAL CUTTER CUT 3.5" TUBING AT 9496' FINAL T/I/O= 010/240 PSI **PAD OP NOTIFIED UPON DEPARTURE*** **Job Com pi ete** AWGRS 09/26/2006 TIO = vac/40/250. Temp = SI. Bleed WHPs to 0 psi (pre PPPOT-T, IC). OA FL near surface. Bled OAP to GBT from 250 psi to 0+ psi in 4 hrs (some fluid, mostly gas). Bled lAP from 40 psi to 0 psi in 10 mins (gas). Monitored 20 mins. WHP's unchanged. FWHPs = vac/OIO+. Page 3 . . C-07 A DESCRIPTION OF WORK COMPLETED AWGRS 09/27/2006 T/INOA= Pre-rig Well head MIT PPPOT-T Passed PPPOT-IC Failed Bled off trapped pressure on test void. Pressure up test void on tubing hanger to 5,000 psi. for 30 minutes. Cycle all LDS on tubing spool, all functioned smooth, with no sign of any bent or broken LDS. Bled off trapped pressure on IC hanger to 0 psi. Cycle all LDS on casing spool, [12] of 16 gland nuts were froze to LDS, was able to break all free but [1] LDS is free. Ran LDS in and out while spaying with Kroil to lubricate packing stack and gland nut. Will be able to change out during RWO or grind the nose off. Attempt to pressure up on IC hanger, never would build over 1,000. Would bled off to 400. IC hanger seals are bad. Need to be changed out RWO. AWGRS 09/27/2006 T/I/O = vac/OIO+. Temp = SI. WHPs (pre PPPOT-T, IC). No change in pressures overnight. Cameron is currently working on the well head. DIMS 10106/2006 RDMO C-01A, Wait on Orders, MIRU on C-07A AWGRS 10106/2006 PULL 6' CIWTWC FOR BOP TEST AWGRS 10106/2006 PULL 6'CIW FOR RIG MOVE ON DIMS DIMS DIMS DIMS DIMS DIMS DIMS DIMS 10107/2006 Kill Well, N/D Tree, N/U and Test BOPE, LID Tbg. 10108/2006 LID Tbg, M/U BHA, P/U DP, Dress Tbg Stub, CBU 10109/2006 Set RTTS and PT. N/D BOP, Bleed OA down, N/UBOP, Circulate Warm Fluids and Bleed OA, Monitor Pressure. 10/10/2006 Monitor Annulus, Pump 60 deg Sea Water, Monitor Annulus, Reverse Circulate 60 deg Sea Water, Monitor Annulus, Set RTTS, Tested RTTS, Began N/D BOPE, Pressure Increase on Annulus, N/U BOPE, Retrieve RTTS, LID DP. RIH to 2,000' Circulate Warm SW. 10/11/2006 Circulate IA to 120 deg, In and Out of Hole. Pump Rate 10 bpm w/460 psi. Monitor Annulus Pressure, Circulated 60 deg Sea Water Down IA. Reverse In 145 bbl, 40 deg Sea Water at 4 bpm w/190 psi. 10/12/2006 N/D BOPE, N/D TBG Spool, cia 9 5/8"x13 3/8" Pack Off, Reset Emergency Slips, Cut and Redress CSG Stump, N/U TBG Spool, Test Pack Off to 3800 psi, N/U BOPE, Test Well Head Breaks, Retreive RTTS, R/U and Run 4.5" Completion. 10/13/2006 Continue to Run 4.5" 13 Cr 80 JFE Bear Completion, Land Tubing, Circulate 520 bbl140 deg, 2% KCL, wi Corrosion Inhibitor, Set and Test Packer, Set Test TWC ,N/D BOPs 10/14/2006 N/D BOPE, N/U Adapter Flange and Production Tree and Tested Same. Freeze Protect Well. RDMO. AWGRS 10/14/2006 PULL 4'CIW TWC FOR BOP TEST Page 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-07 C-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 10/6/2006 1 0/14/2006 Spud Date: 7/27/1973 End: 10/14/2006 10/6/2006 06:00 - 09:00 3.00 MOB P PRE RID and move rig off of well C-01A. Stage rig on pad and prepare to lower derrick. 09:00 - 18:00 9.00 MOB P PRE Waiting on Orders for next well. Perform light maintenance on rig and pits. Perform work orders. 18:00 - 20:00 2.00 MOB P PRE Spot rig over well C-07A. Level and shim rig. 0 psi on annulus and tubing. 20:00 - 22:00 2.00 MOB P PRE Spot Generator #4, Spot Mud Pump #2. Lay herculite and spot cuttings tank. 22:00 - 00:00 2.00 MOB P PRE RlU floor equipment, RlU #2 Mud Pump, Install secondary annulus valve, RlU lines to circulate well. 10/7/2006 00:00 - 00:30 0.50 KILL P DECOMP Hold Pre-Spud Meeting. 00:30 - 01 :00 O.SO KILL P DECOMP RlU DSM Lubricator and pull BPV. 0 psi on tubing. 01 :00 - 02:30 1.50 KILL P DECOMP Pump 130 degree seawater down annulus taking returns out tubing through choke manifold, recover diesel freeze protect in tubing, Line up and pump 40 bbl high vis Safe Surf-O sweep followed by 130 degree seawater down tubing taking returns through choke manifold. 8 bpm with 1,300 psi. Recovered -170 bbls of diesel freeze protect. 02:30 - 03:00 0.50 KILL P DECOMP Monitor well. Well static. 03:00 - 05:30 2.S0 WHSUR P DECOMP Install TWC, test TWC from below to 1,000 psi for 10 minutes. Good test. RlU and test TWC from above to 3,SOO psi for 10 minutes. Good test. 05:30 - 07:30 2.00 WHSUR P DECOMP Drain and N/D Tree. 07:30 - 10:30 3.00 BOPSU P DECOMP Inspect tubing hanger and check threads for pulling hanger. N/U BOP Stack. 10:30 - 11 :00 O.SO BOPSU P DECOMP Rig Up to Test BOPE. 11 :00 - 14:00 3.00 BOPSU P DECOMP Pressure Test BOPE 2S0 psi low / 3S00 psi high for 5 mins each. All components pass. Test Witnessed by BP WSL and Doyon Tool Pusher. Chuck Scheve waived witness of test. 14:00 - 14:30 0.50 BOPSU P DECOMP Rig Down BOP Test Equipment. 14:30 - 16:00 1.S0 WHSUR P DECOMP Rig Up Tubing Handling Equipment, Safety Valve, Control Line Spooler, Power Tongs. 16:00 - 16:30 0.50 WHSUR P DECOMP P/U BPV Lubricator and Pull BPV. UD Lubricator. 16:30 - 17:00 O.SO PULL P DECOMP M/U 7" IJ4S Xo to a Joint of DP. RIH and Engage Hanger. Back Out LDS. 17:00 - 17:30 0.50 PULL P DECOMP Pull hanger To the floor. Required 130,000 # to break hanger loose and 115,000 to pull hanger to the floor. 17:30 - 18:30 1.00 PULL P DECOMP Terminate control lines, Break out and UD Landing joint and hanger. RlU Circulating equipment. 18:30 - 19:30 1.00 PULL P DECOMP Circulate bottoms up. 1,950 psi pump pressure with 10 bpm. RID circulating equipment. 19:30 - 22:00 2.S0 PULL P DECOMP POOH laying down 4 1/2" 12.6# TDS tubing and control line from 9,460' to 7,515'. 22:00 - 23:00 1.00 PULL P DECOMP Terminate control lines on SSSV, Break out and lay down SSSV. RID control line spooler. RID 4 1/2" handling equipment, RlU 3 1/2" handling equipment. Recovered 26 Clamps and 3 SS bands. 23:00 - 00:00 1.00 PULL P DECOMP POOH laying down 3 1/2" 9.2# TDS tubing to 7,200' 10/8/2006 00:00 - 07:30 7.S0 PULL P DECOMP POOH laying down 3 1/2" 9.2# TDS tubing. 282 Joints of Tubing, 5 GLM's, 1 SSSY, 26 Clamps, 3 bands. Cut Joint was 3.1S'. Approx 7.03' ofTubing Stub looking up above X Nipple. 07:30 - 09:00 1.S0 PULL P DECOMP UD Tubing Handling Equipment. Clean and Clear Rig Floor. Install Wear Ring. Prep Dress Off BHA. Printed: 10/25/2006 10:00:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-07 C-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 10/6/2006 1 0/14/2006 Spud Date: 7/27/1973 End: 10/14/2006 10/8/2006 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM. P/U Dress Off BHA. 10:00 - 13:30 3.50 CLEAN DECOMP RIH wI Dress Off BHA on 4" DP. P/U 1x1 from Pipe Shed. 13:30 - 14:00 0.50 CLEAN P DECOMP High Level H2S Drill. Full Participation by rig and support crew. All personal knowledgable of roles and responsibilities, evauation routes, and safe areas. 14:00 - 20:30 6.50 CLEAN P DECOMP Continue to RIH with Singles from Pipe Shed to 9,483'. 20:30 - 22:30 2.00 CLEAN P DECOMP M/U Top Drive and establish parameters. Up weight 160,000#, Down weight 140,000#, Rotating weight 150,000#. 60 rpm with 5,000 ftIlbs of torque. 440 psi pump pressure at 4 bpm. Wash down and tag top of tubing stub at 9,504' Drill Pipe measurement. Wash over and dress top of tubing stub. 60 rpm with 6,000 - 8,500 ftIlbs of torque, 490 psi pump pressure at 4 bpm and 5,000 - 9,000# weight on dressing mill. Work over top of tubing stub several times. 22:30 - 00:00 1.50 CLEAN P DECOMP Pump 20 bbl high vis sweep around. 3,050 psi pump pressure at 11 bpm. 10/9/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Stand back one stand of DP in derrick and RlU to pressure test casing. 00:30 - 01 :30 1.00 CLEAN P DECOMP Test 9 5/8" casing to 3,500 psi for 30 minutes. Good test. 01 :30 - 02:30 1.00 CLEAN P DECOMP Stand back two stands of DP in derrick and M/U HES 9 5/8" Storm Packer. RIH and set at 102'. 02:30 - 03:00 0.50 CLEAN P DECOMP Test HES 95/8" Storm Packer to 2,000 psi for 15 minutes. Good test. 03:00 - 03:30 0.50 WHSUR P DECOMP Pull Wear Bushing. 03:30 - 05:00 1.50 WHSUR P DECOMP N/D BOPE and Stand back. 05:00 - 07:30 2.50 WHSUR P DECOMP Bleeding off annulus. Still getting fluid of out 9 5/8" X 13 3/8" Annulus. Good Stream of Fluid coming out of 1/2" hose to bleed tank. RlU 2" line to Slop Tank. Bleed through 2" line. 07:30 - 08:30 1.00 WHSUR P DECOMP No visual signs of fluid or gas to slop tank. RID 2" line. Check pressures, annulus building to 40 psi in 1/2 hour. Crude / diesel in returns. Annulus bleeds down to almost nothing in 15 mins but will build back up at -1 psi/min. Rig Up 300 psi gauge and 1/2" line to bleed tank and open up. 08:30 - 12:30 4.00 WHSUR P DECOMP Continue to monitor 9-5/8"x13-3/8" annulus. Small intermitant spurt of fluid coming through 1/2" hose to bleed tank. When Shut-In OA building 20 - 25 psi in 15 mins. After being shut-in will get a solid small fluid stream but dies off quickly. 12:30 - 15:00 2.50 WHSUR P DECOMP N I U BOP's 15:00 - 16:00 1.00 WHSUR P DECOMP M/U Test Plug and Land in Wellhead. Pressure Test Tubing Spool FLange to 250psi low and 3500 psi high for 5 mins each - Good Test. 16:00 - 16:30 0.50 WHSUR P DECOMP Pull Test Plug and Install Wear Ring. 16:30 - 18:00 1.50 WHSUR P DECOMP M/U RTTS Retrieval Tool and Single In Hole to 102'. Make Up Top Drive and Wash Down on top of RTTS. 8/0 Top Drive and Install TIW, Engage RTTS wI 20 turns and Check for Pressure. P/U and Release RTTS. RlU Circ Head to DP and RlU to Reverse Circ. 18:00 - 21 :00 3.00 WHSUR P DECOMP Reverse Circ 145 bbls of 90 degree SW from pits @ 4 bpm and 540 psi, OA open to bleed tank while circulating. Shut - down pumps and monitor wI OA open for 30 mins. Initial OA pressure when shut-in at beginning of circulating was 160psi. Open annulus to bleed tank and bleed down quickly to 20 then 10 psi. Repeat Process again reverse circulating 145 bbls of Printed: 10/25/2006 10:00:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-07 C-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 10/6/2006 10/14/2006 Spud Date: 7/27/1973 End: 10/14/2006 10/9/2006 18:00 - 21 :00 3.00 WHSUR P DECOMP 90 degree SW from pits. Shut-down and monitor with OA open, pressure down to 5 psi. 21 :00 - 00:00 3.00 WHSUR P DECOMP Reverse Circ 145 bbls of 120 degree SWat 4 bpm and 530 psi, with OA open to bleed tank. Shut-down and monitor for 30 mins with wI OA open to bleed tank. OA pressure at 10 psi. Repeat process. On shut - down of pumps OA pressure at 5 psi. 10/10/2006 00:00 - 02:00 2.00 WHSUR P DECOMP Monitor 9-5/8" x 13-3/8" Annulus (OA), open to bleed tank. 0 psi and now flow. 02:00 - 03:00 1.00 WHSUR P DECOMP Reverse Circ 145 bbls of 60 deg SW. @ 4 bpm and 480 psi. 03:00 - 03:30 0.50 WHSUR P DECOMP Monitor OA with it open to bleed tank. 0 psi and no flow. 03:30 - 04:30 1.00 WHSUR P DECOMP Reverse Circ 145 bbls of 60 deg SWat 4 bpm at 500 psi. 04:30 - 05:00 0.50 WHSUR P DECOMP Monitor OA with it open to bleed tank. 0 psi and no flow. 05:00 - 06:00 1.00 WHSUR P DECOMP Set RTTS at 72' and UD Running Tool. Test RTTS @ 2000 psi for 15 mins. Shut-in OA to bleed tank. 06:00 - 06:30 0.50 WHSUR P DECOMP M/U wear ring running tool and run in and pull wear ring. 06:30 - 07:00 0.50 WHSUR P DECOMP Rig Up to NID BOP's. Notice -2 to 3 psi on OA. Small amount of dry gas pressure, bleeds off quickly. Swap 600 psi to 100 psi gauge to monitor more closely. Close OA back in and monitor. 07:00 - 08:30 1.50 WHSUR P DECOMP Monitor OA Pressures. 4 psi on gauge after 1.5 hrs. 08:30 - 09:00 0.50 WHSUR P DECOMP Set Wear Ring. R/U to pull RTTS and UD. 09:00 - 10:30 1.50 WHSUR P DECOMP POOH and Stand Back 17 stands of DP, 21 total in Derrick. 10:30 - 12:00 1.50 WHSUR P DECOMP POOH and LI D DP. 12:00 - 13:00 1.00 WHSUR P DECOMP Slip and Cut 85' of Drilling Line. Perform Complete Derrick Inspection. 13:00 - 18:30 5.50 WHSUR P DECOMP Continue to POOH and UD DP. 18:30 - 20:30 2.00 WHSUR P DECOMP UD 4-3/4" DC's and Dress-Off BHA. 20:30 - 22:00 1.50 WHSUR P DECOMP Clean and clear rig floor. M/U Mule Shoe on DP and RIH w/21 stands to 2015' 22:00 - 00:00 2.00 WHSUR P DECOMP Circulate 1500 bbls of warm seawater at 10 bpm and 540 psi. Inital OA pressure at 13 psi, Bleed to 0 psi and leave open. No returns from OA seen after inital bleed. 10/11/2006 00:00 - 07:00 7.00 WHSUR P DECOMP Heating Seawater wI LRS Hot Oil while circulating at 10 bpm and 460 psi. Temperature of fluid pumped in 116 deg F, temperature of return fluids at 112 degree F. OA open to 2" hose and allowed to bleed to slop tank. 07:00 - 09:00 2.00 WHSUR P DECOMP Shut - Down pumps and monitor OA pressure. Shut -in OA to bleeding for welding job on slop tank railing. OA pressure build to 6 psi in 2 hrs. 09:00 - 12:00 3.00 WHSUR P DECOMP Pump out 290 bbls from pits to slop tank and take on 290 bbls of 60 deg F SW. Circulate well with cool fluids. Final Temp of fluids pumped in 80 degrees, Temp of fluid returns 85 degrees. OA open to slop tank wI 2" hose while circulating. 12:00 - 14:00 2.00 WHSUR P DECOMP Monitor OA. Shut - in wI 0 psi on gauge. Pressure after 2.0 hrs = -2.5 psi. Pressure Bleeds of quickly. 14:00 - 16:00 2.00 WHSUR P DECOMP Continue to monitor OA wI hose vented into small bucket of water. Small bubbling evident, pea size bubbles, rate varies and will even die off for short time periods. Consult wI town. 16:00 - 18:00 2.00 WHSUR P DECOMP R/U to reverse circulate with 40 degree SW. Circ at 3 bpm and 100 psi for 140 bbls. Temp of returns quickly drop from 75 to 55 degrees. Gas in OA increased when first came on with pumps then died off after 5 mins of pumping and went on a vac Printed: 10/25/2006 10:00:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-07 C-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 10/6/2006 1 0/14/2006 Spud Date: 7/27/1973 End: 10/14/2006 10/11/2006 16:00 - 18:00 2.00 WHSUR P DECOMP after pumping - 50 bbls. 18:00 - 19:00 1.00 WHSUR P DECOMP Shut-down pumps and monitor OA in bucket of water again. 19:00 - 19:30 0.50 WHSUR P DECOMP Line Up and Reverse Circulate 145 bbl Sea Water at 4 bpm and 190 psi. 19:30 - 21 :30 2.00 WHSUR P DECOMP Monitor Annulus· Minimal Gas From Annulus. First Hour No Bubbling, Slight Bubbling Noticed in Second Hour in Bubble Bucket. Consult Engineer in Town. 21 :30 - 22:30 1.00 WHSUR P DECOMP M/U And Run RTTS to 102', POOH UD 3 Jts DP. 22:30 - 23:00 0.50 WHSUR P DECOMP R/U and Test RTTS to 2,000 psi for 15 minutes. 23:00 - 00:00 1.00 WHSUR P DECOMP Nipple Down BOPs, Monitoring Annulus at Slop Tank w/2" Hose. 1 0/12/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP Continue NID BOPE. 01 :00 - 02:00 1.00 WHSUR P DECOMP NID Tubing Spool. 9 518" Casing Growing, Pushing Up Tubing Spool. 02:00 - 03:00 1.00 WHSUR P DECOMP Nipple Up BOPs, to Tubing Spool, Install 18"BOP Bolts on Tubing Spool, Check Growth 1.5" Up and Lifting BOP Stack. 03:00 - 03:30 0.50 WHSUR P DECOMP M/U Test Plug on Jt DP, Set Test Plug in Tubing Spool and Stack 30,000# Down Weight. 03:30 - 04:30 1.00 WHSUR P DECOMP Nipple Down Tubing Spool wI Longer Bolts ( Total Growth On 9 5/8" CSG 5.5"). 04:30 - 05:30 1.00 WHSUR P DECOMP Pull and Install 95/8" x 133/8" Pack Off. 05:30 - 06:00 0.50 WHSUR P DECOMP Wait on Baker Fishing to arrive wI 9-5/8" Spear. 06:00 - 06:30 0.50 WHSUR P DECOMP P/U 9-5/8" Casing Spear and RIH on a Joint of DP. Spear Casing and P/U 100,000 Ibs over to set casing slips and packoff in tension. 9-5/8" Casing came up -8 inches. S/O full weight slowly, slips holding. 06:30 - 07:00 0.50 WHSUR P DECOMP Release spear from casing. POOH and UD Spear and DP. 07:00 - 08:00 1.00 WHSUR P DECOMP M/U Wach's cutter. Measure out casing and cut off 12 inches. 08:00 - 10:30 2.50 WHSUR P DECOMP NIU 13-5/8" McEvoy 2 Step Tubing Spool wI Secondary Pack Off. Test to 3800 psi for 30 mins . Good Test. 10:30 - 13:00 2.50 WHSUR P DECOMP N/U BOPE and Test to 250 psi low and 3500 psi High. 13:00 - 14:00 1.00 WHSUR P DECOMP P/U 3 Joints of DP and RIH and Pull HES RTTS. Circulate Bottoms Up. POOH and UD RTTS and DP. 14:00 - 16:00 2.00 WHSUR P DECOMP POOH and UD 63 joints of DP. 16:00 - 19:00 3.00 RUNCO RUNCMP Clear and Clean Rig Floor, Pick Up Tubing Handling Tools, Organize Completion Jewelery in Pipe Shed, R/U to Run Completion. PJSM w/Rig Crew, Casing Crew, and Baker Completion Hands. 19:00 - 00:00 5.00 RUNCO RUNCMP Run 4.5" 12.6#, 13CR-80, JFE Bear Tubing. Use Jet Lube Seal Guard Pipe Dope. Average M/U Torque 4,500 ftllbs. 2,588' of 4.5", 12.6#, 13Cr80, JFE Bear Tbg, 1 Unique 9.625" x 3.5" Overshot, 1-jt 4.5",12.6#, 13CR-80, Yam Top Tubing. 1- 4.5" X Nipple wI RHC. Baker 9.625" x 4.5" S-3 9Cr Pkr, X Nipple, 1 jt 4.5"12.6# 13Cr80 JFE Bear Tubing, 1 GLM. 10/13/2006 00:00 - 10:00 10.00 RUNCO RUNCMP Run 4.5" 12.6#, 13CR-80, JFE Bear Tubing. Use Jet Lube Seal Guard Pipe Dope. Average MlU Torque 4,500 ftllbs. 231 jts of 4.5",12.6#, 13Cr80, JFE Bear Tbg, 1 Unique 9.625" x 3.5" Overshot, 1-jt 4.5",12.6#, 13CR-80, Yam Top Tubing. 1- 4.5" X Nipple wI RHC. Baker 9.625" x 4.5" S-3 9Cr Pkr, X Nipple, 1 Jt 4.5" 12.6# 13Cr80 JFE Bear Tubing, 4 GLM's , DCR Shear Valve in top Station, and 1 X Nipple at 2120'. 10:00 - 11:00 1.00 RUNCO RUNCMP M/U and RIH wI Yam Top x K-Bear XO and Joints #2 and #3 of Yam Top Tbg. M/U Circ Head to Joint #4 and MIU to Tbg Printed: 10/25/2006 10:00:49 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-07 C-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 1 0/6/2006 1 0/14/2006 Spud Date: 7/27/1973 End: 10/14/2006 12:30 - 13:30 1.00 RUNCO String. Establish Circulation at 3 bpm at 145 psi. SIO and see pump pressure increase 50 psi at 9513'. Shut Down Pump and continue to S/O. Take Wt another 4' in the hole at 9517'. Stack Up to 7500 Ibs and break Shear Pins. Continue to SIO another foot and Stack Out wI 10,000 Ibs. Repeat Process again. Establish Circulation at 3.0 bpm and 145 psi. SIO and see pump pressure increase at 9513'. Continue in the hole with pumps on. Pump Pressure up to 500 psi at 9517', shut-down pumps and continue to S/O. Stack Out at 9518'. Repeat again wlo pumps on, Stack Out in same spot. RUNCMP POOH and UD Circ Head and Yam Top Joints #4,#3,& #2. Pick up 17.8' of space out pups and M/U above Yam Top x K-Bear XO. Bottom of the Unique Over Shot will be spaced out -2.5' above 3-1/2" X Nipple. M/U Yam Top Joint #2. RUNCMP M/U McEvoy 2 Step Tbg Hanger to String. M/U Circ Head to TCII Landing Joint and Tbg String. S/O String and Land Hanger. RILDS. RUNCMP Rig Up to Reverse Circ 140 Deg SW. Line Up Trucks and review procedure wI new crew. Pressure Test lines to 3500 psi. Found leak in connection. Drain hose to annulus and repair connection. Pressure Test again to 3500 psi - Good. RUNCMP Reverse Circulate 150 bbls of 140 degree SW and 515 bbls of 140 degree SW wI Corrosion Inhibitor at 3 bpm and 300 psi. RUNCMP RID Circulating Lines Drop Ball and Rod, RlU Circulating Lines Pressured Up on Tubing Side, Set Packer, Test Tubing to 3,500 psi for 30 Minutes, Bled Tubing Pressure to 1,750 psi, Pressured Up On Annulus to 3,500 psi for 30 Minutes. Tested OK. Bled Tubing Pressure to O. RHC-M Opened at 2,500 Differential. Set TWC and Tested and Charted to 1,000 psi From Below and 3,500 psi From Above. Blow Down Surface Equipment. N/D BOPE Continue N/D BOPE, NU Adapter Flange. Test Hanger Void to 5,000 psi, for 30 minutes. RlU and Test Production Tree to 5,000 psi for 30 minutes. RlU DSM, Pull TWC w/Lubricator, RID DSM RlU Circulating Lines and Little Red to Tree and Pressure Test Same to 2,000 psi for 5 Minutes. Freeze Protect Well to 2500 ft wI 170 bbls Diesel. Pumped at 2.5 bpm w/300 psi. Allow Well to U-Tube. Wait on BPV. RID and Secur Cellar and Tree, Clean Out Slop Tank. Rig Released 10/14/2006 at 10:00 hrs. 11 :30 - 12:30 1.00 RUNCO 13:30 - 15:00 1.50 RUNCO 15:00 c 19:00 4.00 RUNCO 19:00 - 21:30 2.50 RUNCO 21 :30 - 22:30 1.00 RUNCMP 22:30 - 00:00 1.50 RUNCMP 10/14/2006 00:00 - 02:30 2.50 RUNCMP 02:30 - 03:00 0.50 RUNCMP 03:00 - 04:00 1.00 RUNCMP 04:00 - 05:00 1.00 RUNCMP 05:00 - 05:30 0.50 RUNCMP 05:30 - 07:30 2.00 RUNCMP 07:30 - 09:30 2.00 RUNCMP 09:30 - 10:00 0.50 RUNCMP Printed: 10/25/2006 10:00:49 AM C-07 A PTD: 200-052 Work over Change of S< Zoo - OS 2. '~ -~~- Subject: C-07 A PTD: 200-052 Workover Change of Scope From: "Cismoski, Doug A" <CismosDA@BP.com> Date: Fri, 06 Oct 2006 11 :58: 16 -0800 To: winton_aubert@admin.state.ak.us CC: "Chan, Paul (PRA)" <PauI.Chan@BP.com>, "Rossberg, R Steven" <Steven. Rossberg@BP.com> Well: C-07A PTD: 200-052 Sundry: 306-319 Winton - BP received Sundry approval on Sept 14, 2006 for the subject well. Based on further well research and diagnostic testing, BP has determined that the well no longers requires any casing repair. The revised procedure is as follows: 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-%" x 3-1/2" tubing string to the cut. 3. Test 9-5/8" casing to 3500 psi 4. Changeout 9-5/8" wellhead seals /""\ 5. Run 4-%" 13CR-80 completion with Baker S-3 packer. Position packer at f:~D. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 8. Set BPV. ND BOPE. NU and test tree. RDMO. Please call if you have any questions. Doug Cismoski Sr. Workover Engineer 564-4303 (office) 240-8041 (cell) ªCANNfD NOV 0 2 2D06 ,# -- --- I of I 10/9/20067:34 AM . . FRANK H. MURKOWSKI, GOVERNOR AI~SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-07 A Sundry Number: 306-319 ~5CANNED SEP 1 ~ 2005 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ?l4f~ Cathy P. Foerster Commissioner ~ DATED thisM aay of September, 2006 Enc!. ÐðL)-ôS ;;) :'\ .\o\i . fI;¿ rIJi/lob REC~ErJlfJ20oG:, 0: ~V ~ STATE OF ALASKA I· .Q:\ ~i, t\ \ \ ALASKA Oil AND GAS CONSERVATION COMMI SION ~~ ~ 1 3 2006 r s- . \ \ -~ APPLICATION FOR SUNDRY APPROVA~~~ .' ~ 20 AAC 25.280 Alaska Oil & Gas Cons. Commission ~ -- ()' 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time ExtenAßQhorage o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: ./ 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development o Exploratory 200-052 ..-- 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20128-01-00 /' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-07 A / Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028285 55.7' Prudhoe Bay Field / Prudhoe Bay Pool t?< ..... / ..... '.. .\IV..... Yr..; . ........... .··...i) ... ··../.'//is)/i/.i Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13260 9007 13213 9004 None None Casino Lenoth Size MD ./ TVD Burst Collaose Structural Conductor 98' 20" 98' 98' 1530 520 Surface 2691' 13-3/8" 2691' 2691' 4930 2270 Intermediate 1 0099' 9-5/8" 1 0099' 7739' 6870 4760 Production liner 1877' 7" 9601' - 11478' 7363' - 8781' 8160 7020 Liner 3073' 2-3/8" 10187' - 13260' 7802' - 9001' 11200 11780 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft)/ 12330' - 13201' / 8999' - 9003' 4-112",12.6# x 3-1/2",9.2# L-80 11478' Packers and SSSV Type: 9-5/8" TIW 'HBBP-R' packer I Packers and SSSV MD (ft): 9540' / 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: October 15, 2006 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Paul Chan, 564-5254 SignatureV~ ~ ./ --^-. Prepared By Name/Number: Phone 564-4303 Date 7/13/0(", Terrie Hubble, 564-4628 v Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ( ~(¡J -<-=?J9 . D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: T e- s t öoPE to 3':>00 fU. Subsequent Form Required: \0 - 4;0 4-. RBDMS BFl SEP 1 5 2006 Approved BV:().jg .. ~ ./L APPROVED BY Date 9'-!(.-tJ;:. COMMISSIONER THE COMMISSION Form 10-403 Revised 'f6/2006 Submit In Duplicate ORIGINAL . . C-07 A Rig Workover Scope of Work: Pull 4-%" x 3-Y:z" completion, cut and pull 9-S/8" casing, run and cement to surface new 9-S/8" ~a' run 4-%" 13CR-80 completion. MASP 2360 psi Well T : roducer Estimated Start Date: October 1S, 2006 Pre-ri 0 1 S 2 E 3 F 4 0 S 0 6 re work: Check the tubing and IC casing hanger lock down screws for movement. Complete back out and check each LDS for breaka e. PPPOT T & IC. NOTE: Well is current! SECURED with a TTP. Pull TTP from X nipple @ 9S04~. Set 2.2S" OD L TTP. Dump 10 -1S' of sluggits on top of L TIP. CMIT TxlA to 3S00 psi. / o tion: Pull GL V from Sta#1 thus fore oin the tubin unch with e-line Chern Cut @ 9496' Cut is to be 2' below the top of the pup just above the X nipple: Reference Tubing Tally dated 3- S-1990. The chem. cutter anchors should be 7' above the severin head thus be below GLM #1. Circ Out Well w/ SW and FP w/ diesel. Bleed WHP's to 0 si. Set a BPV in the tubin han er. Remove the wellhouse & flow line. Level the ad as needed for the ri Proposed Procedure ~ 1. MIRU. ND tree. NU and test OPE 3S00 psi. Circulate out freeze protection fluid and circulate well to clean seawater througcut. 2. Pull and LD 4-%" x 3-1/2" tubing string to the cut. ./' 3. USIT Log 9-S/8" casing for top of cement (TOG) / 4. Cut and pull 9-S/8" above TOC S. Run and fully cement new 9-S/8" casing to surface ,,/ 6. Run 4-%" 13CR-80 completion with Baker S-3 packer. Position packer at -9400' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3S00 psi. Freeze protect to 2200' MD. / 9. Set BPV. ND BOPE. NU and test tree. RDMO. . TREE = 6" CrN 5M WELLHEAÐ = 13-5/8" 5M MCEVOY ACTUATOR = OTIS KB. ELEV = 55.65' BF. ELEV = 36' KOP = 2700' Max Angle = 96' @ 12900' Datum MD = 11559' Datum 1VD = 8800' SS sAA' NOTES: IA & TBG ANNULAR COMM NOW AT BEGINNING OF DRLG. ***IA X OA COMM. MAX lAP = 2000 PSI; MAX OAP = 2000 PSI. (04/01/03 WAlVER)*** C-07 A . 1991' -14-1/2" SSSV LANDING NIP, ID = 3.813" I 19-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" H 14-1/2" TBG, 12.6#, L-80 TDS, .01522 bpf, ID = 3.958" I 2107' 2015' 2015' -i4-1/2" X 3-1/2" XO I 2690' -1 FULL OÆNING CEMENTER GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH 5 3000 2943 7 MERLA DMY RM 4 4980 4637 50 MERLA DMY RM 3 6991 5774 56 MERLA DMY RA 2 7996 6349 56 MERLA *DMY RA 1 9474 7213 42 MERLA OÆN -EXTENDED PACKING 9504' -i3-1/2" OTIS X NIP, ID = 2.750" 13-3/8" CSG, 68/72#, N-80, 68#, ID = 12.415" /72#, ID = 12.347" PORT DATE o 03/05/04 o 03/05/04 o 1 0/08/00 o 03/23/04 07/16/06 Minimum ID = 1.969" @ 10188' 23/8" LINER TOP DEPLOYMENT SLY 3-1/2" TBG, 9.2#, L-80 TDS, .0087 bpf, ID - 2.992" 9522' -1TrN SBR, ID = 4.0" I 9540' -19-5/8" TrN HBBP-R PKR, ID = 4.00" I 7" BOT PBR I TOP OF 7" BOT LNR HGR I 19-5/8" CSG, 47#, N-80, BTRS, ID = 8.681" I 9601' -i7" PBR(40' BOT) I 9601' 9643' 10099' 10188' I BKR DEPLOY SLY, ID = 1.969" (OD = 2.70") 10188' HTOPOF 2-3/8" LNR I MILLOur WINDOW 11478' I TOP OF WHIPSTOCK I 11470' 17" LNR, 29#, N-80 BTRS, .0371 bpf, ID = 6.184" 11803' ÆRFORA TION SUMMARY REF LOG: CN-FD ON 09/03/73 ANGLE AT TOP ÆRF: 87 @ 12330' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 1-11/16" 4 12330 - 12370 C 10/09/00 I 2-3/8" LNR, 4.4#, L-80 FL4S, .00387 bpf, ID = 1.995" I 1-11/16" 6 12370 -12610 C 10/09/00 1-11/16" 4 12610 -12850 C 10/09/00 1-11/16" 4 13100 -13200 C 10/09/00 PRUDHOE BA Y UNrT WELL: C-07 A ÆRMrT No: '2000520 API No: 50-029-20128-02 SEC 24, T11 N, R13E, 1766' SNL & 879' WEL DATE 01/30/78 10/08/00 04/01/03 03/05/04 03/19/04 03/23/04 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK WORKOVER WArvER SAFETY NOTE GL V C/O CORRECTIONS (ID & XO) GL V C/O REV BY COMMENTS BY/KAK CORRECTIONS MORlTLH PXX TIP SET (03/22/04) CJNlPJC PULL PXX & SET L TIP BSElPJC GL V C/O DPS/PJC 10-314" CSG CORRECTION DATE 07/09/04 09/24/05 07/16/06 07/16/06 07/21/06 JRC/KAK DA V ITLP JBMlTLH JLJI1LP BP Exploration (Alaska) .. TREE= .. 6" erN SM WB..LHEAD = 13-5/S" SM MCEVOY ACTUATOR = OTIS KB. B..EV = 5S.65' BF. B..EV = 36' KOP = 2700' Max Angle = 96' @ 12900' Datum M) = 11SS9' Datum TVD = SSOO' 55 19-5/S" CSG, 40#, L-SO C-07 A Proposed Completion 13-3/8" CSG, 68/72#, N-80, 68#, 10 = 12.41S" I 72#, 10 = 12.347" 14-1/2" TBG, 12.6#, 13CRBO, .01522 bpf, Ð = 3.958" I 3-1/2" TBG, 9.2#, L-80 TDS, .0087 bpf, 10 = 2.992" I 7" BOT PBR I TOP OF 7" BOT LNR HGR I 19-5/8" CSG, 47#, N-SO, BTRS, ID = S.6S1" I 9643' 9601' TOPOFWHIPSTOCK H 11470' I 17" LNR. 29#, N-80 BTRS, .0371 bpf,ID=6.184" 11803' SURFAC 1TOPOFceÆNT -2100 14-1/2" HES X NP, 10= 3.813" 2690' - FULL OÆNING CEMENTER GAS LIFT MANDRB.S TVD DEV TYPE VLV LATCH PORT DATE ST MD 4 3 2 1 "*EXTENDED PACtONG 4-1/2" HES X NP, Ð = 3.813" -9400' -I9-5/S" BAKERS-3 A<R, 10 = 4.00" - 4-1/2" HES X NP, 10 = 3.S13" 1 UNIQUE MACHINE OVERSHOT - 3-1/2" OTIS X NP,ID= 2.7S0" I 1TIW SBR, ID = 4.0"' 19-5/S" TIW HBBP-R A<R. 10 = 4.00" 9522' 9540' 9601' 17" PBR (40' BOT) I 10188' BKRDER.OY SLV, 10 = 1.969" (OD= 2.70") 10188' HTOPOF 2-3/8" LNR I MILLOUT WINDOW 11478' I PERFORA IDN SU~RY REF LOG: CN-FD ON 09/03/73 ANGLE AT TOP PERF: 87 @ 12330' Note; Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 12330 -12370 C 10/09/00 I 2-3/8" LNR, 4.4#, L-80 FL45, .00387 bpf, 10= 1.99S" I 1-11/16" 6 12370 - 12610 C 10/09/00 1-11/16" 4 12610 - 12850 C 10/09/00 1-11/16" 4 13100 - 13200 C 10/09/00 DATE 01/30/78 10/08/00 04/01/03 03105/04 03/19/04 03/23/04 REV BY CO~S ORIGINAL COM PLETION SIDETRACK WORKOVæ WAWER SAFETY NOTE GLV C/O CORRECIDNS (ID & XO) GLV C/O DA TE REV BY COMMENTS 07/09/04 BY/KAK CORRECTIONS 09/24/05 MOMLH PXX TIP SEr (03/22/04) 07/16/06 CJNlPJC PULL PXX & SEr LTIP 07/16/06 BSElPJC GLV C/O 07/21/06 DPS/PJC 10-314" CSG CORRECTION PRUDHOE BAY UNrr WB..L: Co07 A PERMIT No: "2000520 API No: SO-029-20128-02 SEC 24, T11N, R13E. 1766' SNL & 879' WB.. JRC/KA K DAVITLP JBM'TL.H JUITLP BP exploration (Alaska) F:\LaserFiche\CvrPgs _ Inserts\Microfilm _Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~,., .," ".. ~', ~.. '" "'''10. ...'" .!'"' ':, DATA SUBMITTAL COMPLIANCE REPORT 111612003 Permit to Drill 2000520 Well Name/No. PRUDHOE BAY UNIT C-07A Operator BP EXPLORATION (ALASKA) INC MD 13260 L~- TVD 9007 r' Completion Dat ~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20t28-01-00 UIC N REQUIRED INFORMATION Mud Log N_9_o Sample No Directional Survey ? i'~-.--'. .... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt T (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments 10000 13203 Case 1/3/2001 09840 ~'~000-1320~ IL L R R iD D 11680 13000 Open 5/18/2001 10093 4,~r~680-13000 9840~ FINAL 10000 13203 CH 1/3/2001 9840/'~0000-13203 Digital Data UsSurvey Report FINAL 2/2/2001 Digital Data rvey Report FINAL 11479 13266 2/2/2001 11479-13266 Paper Copy ~ 5 FINAL 11488 13251 OH 5/23/2001 11488-13251 BL. Sepia LIS Verification FINAL 8745 13253 CH 5/23/2001 8745-13253 LIS Verification 10093,_,// FINAL 11680 13000 CH 5/23/2001 10093~1'~80-13000 Digital Data. Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Rec~.ivRd? Interval Dataset Start Stop Sent Received Number Comments Daily History Received? Y / N Formation Tops ~)/N Comments: Permit to Drill 2000520 MD 13260 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 1116~20O3 Well Name/No. PRUDHOE BAY UNIT C-07A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20128-01-00 9OO7 _~etion Dat 1013/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N 07:~ From-PRB OPERATIONS gO?-BSg-50B1 T-444 P.OZ/02 F-?ll BP EXPLORATION (ALASKA) INC. P.O. Box 196612, Anchorage, AK 99519.6612 REPORT OF ACCIDENTAL NATURAL GAS RELEASE DATE: May 25, 2002 TO: Ms. Cammy Taylor Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 FAX: 276-7542 RECEIVED MAY AlmmlmOil & C, as Ganmi n .DESCRIPTION OF INCIDENT 1. Date and Time: 2, Location: xx__x Prudhoe Bay Unit Milne Point Niakuk __ Other Saturday, May 25, 2.002 @ approximately 9:01 am Detailed Location Well Pad C, well 7 3, Volume of natural gas lost: 430 mscf 4. Cause of loss: Actions taken and planned to prevent further loss: Equipment or procedural changes to prevent loss from recurring: Contact (name and telephone number): 7. Signature: Gas release from inner annulus due to bleed port screw inadvertently removed. The well was shut-in. The Annular pressure was controlled by fluid packing the tubing and letting the inner annulus bleed to e safe pressure, after which the plug was re-installed in the bleed port. Maintenance procedures to be revised as necessary._ .............. An investigation is ongoing to determine the root cause(s) of the failure, . Hal Tucker / Mike Botkovatz (907) 659-5566 / 4276 Adrian McCaa (907) 659-,5224 BPXA Envlro~lmental Manager, MB 2-6 (FAX 564-5020) BPXA Volume Aocount!ng, MB 12.4 (FAX 554-4094) Froductiol3 Optimization Team Leader, PRB 6 GPB Operations Manager, PRB 10 Fwd: C-07 Gas release " Subject: Fwd: C-07 Gas release Date: Sun, 26 May 2002 22:17:21 EDT From: STMaunder@aol.com To: tom_maunder@admin.state.ak.us Subject: C-07 Gas release Date: Sat, 25 May 2002 20:42:18 -0800 From: Chuck Scheve <chuck_scheve@admin.state.ak. us> Organization: State of Alaska, Dept of Admin, AOGCC To: stmaunder@aol.com Hi Tom The IA on C-07 finally bled down enough to plug the bleeder port around 7:30 this evening. During the day the tubing was loaded with KCL water but there didn't apear to any comunication tubing to IA, just a lot of volume in 3 1/2 X 9 5/8 and the last fluid level they had said 9400'. No one seriously injured one man did visit medic was abrasion on arm. John Smart was there ramroding the response operation and as much as I hate to admit it did a good job keeping things organized. Forward plan in to completly bled IA and OA then attempt to to energize packoff seals and return well to production. Chuck I of 1 5/28/02 1:39 PI~ Transmittal Form BAKER HU HES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Prudhoe Bay North Slope, Alaska C-07A Contains the following: IVED 1 LAS Format disk 1 Film · 1 Measured Depth GR print 1 TVD-GR print Sent By.' Jo~f B,~rg ' Date: .May 18, 2001 Received~x..._~~/~ .'] ~~,~'~/} ' Date: "3.--- ! PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER RECE ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 ,~,,a,~,.,,,,,,...,~ i,,,...~,,~,a.,,,~,,,~,~,,,,~,~ ::,:,:,.:L:.::'.' ::::::::::::::::::::::::::::: .~ ............ . ~:,.~:,.~.;.....:::.:.:..:.. :::::::::::::::::::::::: :::.~::,..,:.:,,.::,, ~,::~-,.. ,- I , ...... ~ .............. .... *~' ..,,,,~ i ............. .... ,,~,..,,,., ~, , ...... ~ ...... .... ~ ....... i ,, ..................... :,,.,?,~ ......... ]},,..,,.',. ..................... ................~,~... ,. ~ ..... :D~"; 7' ~,,,;g~,~.,o,, ~.,,.,,~,L~' ,,~,~,,, ':'.'~':':.I '~,' .................... ..,,,,., .... . ............... 5~.., .;. ~ ............. 2 ....... ~,.~¢'~....: ..... '.1"" .... i i' '~'" ~'' ,~[~ ........ : ........... ~,. ,,, ..,. ,.., I .' I ...... ' ..... ~'~ , . ~i,~:a .... ~ ................ ,% ...... .', ........... I i ................. ~ .... .,., ........... , ........... if, ....... '~,~ .......... ~; ............................. ~,,~ ........ : ........... ~ ..... ~4,,.'.,:..' ,. ', t.', .,2,:, '.;,..'.'L.: i,:.,, .~.~::::::.,, ......................... I ................ :~ ........ ,.,,,,~.~,~,~,~, ,~,,,I ,~,,~...,,,u,~ ~ ,-,,,t., i ............ ~;" ........... ,. ....... ? ......... .... . .... ~ ...... ~ ,,, ..... ,, i, 'I~'"' ' ~ "'' ,..'/"7;::;'.,.i ,: ~ .~.~.~. , ~ . , ':77.'. '::'::1 , ..,['::':2:Z .... ; ...... ~., .,.: ,,,':,;".'.',.,.: ~.,,. 4 ...... [,,. ',~,z',Y~ .......... ..;;.2':. .... ',1 .... ~ ............. ,, ,.,,~... ., , i i .... .' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, -~'~ i~'""i Commissioner ~i'~'~-~:'~''''~ Tom Maunder, P. I. Supervisor DATE: April 23, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit C Pad Monday. Ar~ril 2.3, .20.0,.1.' I traveled to BPXs C Pad and witnessed a.portion of the 30-day retest of the safety valve systems. As the attached. . .. .. AOGCC.Safety Valve System Test Report indicates I witnessed the testing'Of'i 1'"Wells and 22 comPonents With 1 failure: The Surface Safety Valve on well C-20B failed.to .pr..essur. e test. This valve is a repeat failure from the previous test. ~'...'attempt'was 'made at this time t° SerVice..the.valve'.but the SUbsequent retest..al~0..failed. This..weli was' shut in until repairs could .be.completed. I departed location prior to completion of the testing on this Pad due to a required BOP' test on Nabors Rig 9ES. 'l.spoke With Merv' Liddelow on the morning of 4-24-01 and.he . indi~.t~,.~. ?:~he,re,wer,.e.,no further, failu.r.e.s, on remainder, of the wells tested,. Merv Liddelow performed the testing today; 'he demonstrated good test procedures and was a pleasure to work with. Summary: I witnessed a potion of 30-day SVS testing at BPXs C-Pad. PBu C Pad, 11 wells, 22 components, 1 failure 4.55% failure rate on the witnessed portion of the pad. ..A.,ffa~ chmen.t: SVS PBU C Pad 4-23-01 CS X. Unclassified Confidential (Unclassified if doc. removed ) SVS ?BU C Pad 4-23-01 CS (' (' Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: ,Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit~ad: Pmdhoe / PBU / C Pad Separator psi: LPS 174 ,, Date: 4/23/01 HPS 644 I · ... . r ' "'":"~ ; "-"' '~'" ' ..... ' ' ' '' "'" ~ ":" .... ' "' "~": .... :":' ': "~'"":"'""' ~' :' '; "' :' "'"" ' ' i': """" ':i' '"" '~ i"~ ...... ' ':"',;" ':"' ~" 'i "'A.' ....'. .:~5,. ': . ..:....'.......,..%.... ..:..... 7.. · Well Permit Separ Set L/P Test Test Test Date o~ WAG, GINJ, Number Number PSI ,, PSI Trip ,Code Code Code Passed GAS or CYCI.E C-01 1720300 , C-02 1730040 , C-03A 1981840 644 550 500: P P OIL C-04A 1960920 ' C-05 1730110 .174 '125 100 P 'P ' ' OII, , ,, , C-06A 1981570 C-07A 2000520 644 550 " 520 P P " ' OIL C-08A 1950280 1.74 125. 120 P P ' OII, , C-09 1790260 ' ' ,, C-10 1790350. ' C-Il 1790460 , C-12A 1981160 ' C-13A 1971430 , C-15' 1791090 .. , C-16 1800100 .. C-17A 1980230 " .' ' , ,, C-18A 1991290 · ' ' C-19B '2000050 644 550 525 P P " OIL C-20B 2001140' 174 125 110 p '.'i..=;:.;.i~!'::..'i....!..~ OIL C-21 1820810 174 125 115' P P ' OIL C-22 1820880 644 550 550 P P OIL , , C-23A 1961190 C-24 1821410 644 550 525 P P 01I, ' , , C-25A 1950110 644 550' 475 P P C-26A 1981450 ....... C-27A 1961390 C-28 1821950 ' ' ' C,29A 1961700 C-30, 1871360 ' C-31A 1950060 , C-33 1930770 .. ' - C-34 188015~ , · RJF 1/16/01 Page 1 of 2 SVS PBU'C Pad 4-23-01 CS II i I ..... i i'' I' I' ' : ' ' " '" '.' ". '. Well Permit Separ Set L/P Test Test Test Date o~, WAG, G~NJ, Number Number PSI PSI Trip Code Code Code Pass_~_ GAS orCVC~.r. C-35A 1952000 ' ' ..... C-36A " 2000020 ' ' " C-37 1930550 " ' .... C-38 1860660 .... C-39 ,1930940 644 ' 5SO 500' P ' P '- ' OIL C-41 1930990 ' ' ' ' ' C-42 1930500 .... ' ' · ~ ~1 Wells: _ 11, Components: 2____.._~2 Failures:1 Failure Rate: 4.55% El 9o Remarks: Sur~.~ Saf, e,~ Valve on Well C.20B failed when p.ressure tested. Retest a~er valve ~.; .This is a partial pad test. ' .... i I i [ i. il i i . ii . i i ii ii i i . t[ iii i i . ii i i t - . - [ i RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 4-23-01 CS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~: ~,~\ DATE: Commissioner Tom Maunder, ~ P. I. Supervisor O~1o%-0 I, THRU: March 23, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector , Safety' Valve .TeSts 'PBF/PBU C/Pad. , . Mar,cl~_.23, 200,1: I traveled to Prudhoe Bay Field to witness Safety Valve.System tests on BPX's C Pad. Well house inspections were also conducted,, Merv Liddelow was'the BPx representative in charge of testing, and performed the tests in' a. professional.manner'.' Twenty-one .wel.ls..on....C, Pad ..were tested with five...failures...witnessed. The .SSV on well C-04A tripped below 50% of the separator psi, the SSV on well' C-07A failed to hold D/P,. the pilot on well'. C-19B was frozen;'the pilot on well C-20B failed to trip and the SSV failed to hold D/P. Mr,' .Liddelow indicated., tome that all failures, were repaired within. 24'. hOurs. I inspected.21 'well houses and noted leaking' wing:.Valves on wells C,03A, C-13A and,C-19B,~. Ahydraulic fluid leak on the SSV control'iine of well C-05 and' a slight crude oil leak., from the SSV On well C-25A were also noted. Mr.. Liddel0w indicated he would .have these items corrected. The AOGCC test forms are attached for reference. . .. ., SUMMARY:' I witnessed the SVS tests on twenty, one oil producing wells on C Pad in the Prudhoe Bay Field. 21 wells tested 42 components, Ii failures witnessed, and 1'1.9% failUre rate. 2t well houses inspected.. '. A,,ttac,h, ments: SVS PBU C-Pad 3'23-01 JJ ',,cc: SVS PBU C Pad 3-23-01 SJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: , , Jeff,Jgn,es Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/C Pad Separator psi: LPS 174 Date: 3/23/01 HPS 662 .,..:,..~....,,.Well Data...:.,.~: ........ .~...:.:.. ,,:,.,...:,.,.:....:,.: ..... ...... ~ .... '.~lotsi .... ..:~.:..<...: . . Well Permit Separ Set L/P Test Test Test Date oa, WAG, GI~J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1720300 ...... C-02 1730640 ' 662 550 525 'P' P ..... oIL t C-03A 19818401 662 550 530 P P OIL C-04A" 196i)920 'i~62' '~50 "' 220 ' '3 C-05 1730110 174 125 115 P P OIL, C-06A ' 1981'570 ~62' 550 ' 580 'P ' P ........ oILi (~-07A 2000520 ...... 662 ' 550 ' 545 ' P ' ' 4 ...... OIL · . C-08A 1950280 C-09 1790260 C-10 1790350 C-11 "17904'60 " 662 550 " '595 ' P P ....... oIL: C-12A 1981160 C-13A 1971430 662 ' 550 ' 596 ' P -P .......... OIL C-15 1791090 i I I I , I I I I I Ill C-16 1800100 ' ' i I i ! . I ' . Il , .I ! I _ Il I I. C-17A 19,80230 ~62 550 580 P 1i OIL! C-18A 1991290 ......................... c-igB 2000050 1~62' ........... 550 250 2 P OIL~ C-20B 2001140 662' ' 550 '0 1 4 ....... OIL C-21 ' '1820810 i7~' " 125' 120 ' P ' ' ~ .... OIL c-22 82imo' ' 5 i)P 'P '' C223A' i~61190 ......... ,C-24 1821410 662 550 545 P P OIL C-25A 1950110 662 550 510 P P OIL :C-26A '1981450 ........... !C-27A 1961390 ,c-28 182J950 ................ ' ........ C-29A 1961700 iC-30 1871360 662 550 525 P P6iL C-31A , 1950060 ' 662 ' 550 ' 560, P P ...... OIL !C-33 1930770 ..... . i i . , i , 11 ., , i.i , j , ,~ ..... _ 'C-34 1880150 ~-35A "195~000 174 i2~ 120 "P ' P ....... 0iL C-36A 2000020 174 125...... 1i51' P 'P '" 0IL RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 3-23-01 JJ1 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or 6-37 1930550 6~2 550 550 P P ' ' OIL C-38 1860660 ..... ' ' ' iC-39 1930940 ' ' C-41 '"1930990 ....... , ,C-42 1930500 662 ' 550,, 590 'P P , , ' ' OIL · , Wells: 21 Components: ,4,2 Failures: ~-- 5j Failure Rate: '11.90°td~ 9o oar Remarks: ?pe. rator reports ail failures ,re.p .~ed and passed retest.. - . Il I I I I I I U . . I _ [ I I I . _ IIl II RJF 1/16/01. Page 2 of 2 SVS PBU C Pad 3-23-01 JJ1 STATE OF ALASKA ALASK~ ,IL AND GAS CONSERVATION COM~..,,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 200-052 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20128-01 4. Location of well at surface .. ;.-:--.-_ :....:.;. :::..-,.~ -~:j~,T,ff3N~ 9. Unit or Lease Name 1766'At topSNL'of productive879' WEL,intervaiSEC. 19, T11N, R14E, UM ..... ,...' '"...:' '"".._. _ !' V!~ Prudhoe Bay Unit 879' SNL, 1811' WEL, SEC. 24, T11 N, R13E, UM At total depth '~ ...... : ~ ~ '~~~ 1897'SNL, 1715'WEL, SEC. 24, TllN, R13E, uM .................... '~'i~"-'~ ...... i ~I.~. 10. WellNumber C-07A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 55.70' ADL 028285 12. Date Spudded 9/27/2000 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband' 10/3/2000 10/8/2000 115' water depth' if °fish°re N/A MSL I' 16. No. of Completions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 13260 9007 FTI 13213 9004 FTI [] Yes [] NoI (Nipple) 1991' MDI 1900' (Approx.) 22. Type Electdc or Other Logs Run MWD, GR, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 98' 26" 173 sx Permafrost 13-3/8" 68# / 72# N-80 Surface 2691' 18-1/2" 3750 sx Permafrost II lO-3/4, x 9-5/8" 47# / 56# N'80 Surface 2119' N/A Tieback String, w/top 3 its 9-5/8" x 11-3/4" Thermocase 9-5/8" 47# N-80 2119' 10099' 12-1/4" 1850 sx Halliburton Light & Class 'G' 7" 29# N-80 9601' 11478' 8-1/2" 710 sx Class 'G' 2-3/8" 4.4# L-80 10187' 13260' 3" 122 sx Class 'G' 24. Perforations pp. en to, P.roducti.on (M.D+,TVD of Top and 25. TUBING RECORD Bottom and ~merva~, s;ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1-11/16" Gun Diameter, 4 spf 1-11/16" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 2115' MD TVD MD TVD 3-1/2", 9.2#, L-80 11478' 9540' 12330' - 12370' 8999' - 9001' 12370' - 12610' 9001' - 9006' 12610' - 12850' 9008' - 9o00' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 13100' - 13201' 8999' - 9003' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with Dead Crude ~.....~ . ;~... 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 15, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS'OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED NOV ZOO0 Alaska 0il & Gas Cons. Commission Form 10-407 Rev. 07-01-80 Submit In Duplicate 29- 30. Geologic Markers Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. __ 26P 11509' 8813' 25P 11533' 8834' 24P 11579' 8872' 23P 11623' 8902 22P 11678' 8931' 21 N 11744 8965' 21P 11750' 8968' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys ' ' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,.~[~ ~~'~__~. Title TechnicalAssistant Date C-07A 200-052 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..,__Shlztt-ln. (~t,her~p=x,~l~l;l. ITEM 28: If no cores taken, indicate 'none'. RECEIV EU NOV ZOO0 Form 10-407 Rev. 07-01-80 Alaska 011 & Gas C, ons. ~ Well: C-07A Accept: 09/26/00 Field: Prudhoe Bay Spud: 09/27/00 APl: 50-029-20128-01 Release: 10/08/00 Permit: 200-052 CTD Unit: Nabors 3S Date PRE-RIG WORK 08/26/00 Set ClBP at 11660', tied in with SWS Perf Record of 12/25/98. Performed injectivity test. Able to pump sea water at 5.0 bpm with max. tubing pressure of 1000 psi. Well was freeze protected in preparation for setting of TIW whipstock. 08/27/00 Set top of whipstock at 11470'. Whipstock face at 154.5 deg. Right from high side. RA marker tag is at 11475.1 '. o8/2 /oo S~t packer at 11450'. Perf tubing at 10500' to 10504'. Injectivity test: 5.0 bpm at 1100 psi max. Well freeze protected and ready for CTU. 08/30/00 Sting into EZSV at 11450'. Injection of 2.1 bpm, 3100 psi. Pump 45 bbls of cement, pumping SLW down backside while stung into retainer. Pump 6 bbls BHP, 1000 psi pressure bump, 1-1 returns. Circulate 7 bbls cement out of top perfs. Fill clean out to 11440', pumping bio, bottom fell out, took gas kick, IA started tracking tubing. Jet out of hole. Surface check returns, tracked 1-1 on clean out / kick. Make up 2.25" JSN. Run in hole to jet mandrels and circulate gas from straddle. 08/31/00 Circulate out oil/gas from straddle. Well cleans up after 750 bbls fluid pumped off bottom. Pull out of hole, jetting all GLMs. Freeze protect tubing to 2500' with 50/50 MNV. Note: Definite tubing X IA communication post P&A, most likely at the OGLV. 09/02/00 Mill 'X' nipple at 9504' with 2.80" D331 diamond mill. Continue through cement, EZSV at 11450', then cement again to top of whipstock at 11466' (ctm). Flag at EOP = 11400'. Pull out of hole. MITIA to 2500 psi, passed. Lost 120 psi in 30 minutes. 09/03/00 Change out to BHA #2, window mill. Tag top of whipstock at 11470'. Mill to 11478'. Continue into open hole to 11488' (corrected). Pull out of hole for window. 09/04/00 RIH with BHA #3, window dressing assembly. Dress window with 2.79" crayola mill. Run in hole to 11488'. Lay bio in window, freeze protect top 2500' with MW. COIL TUBING DRILLING 09/17/00 Spot rig over C-07. Nipple up BOPE. Change rams. Prep for BOP'test. DS swapping coil in yard from 2-3/8" to 2" and inspecting mast. RECEIVED NOV 2 ZOO0 Alaska 011 & Gas Col~, ~ C-07A, Coil Tubing Drilling Page 2 09118/00 - 09/26/00 Rig on standby. Mast damage was found on DS Unit #4 inspection. Repairs were made. 09/27/00 Log tie-in. Drill build from 11484' to 11527'. Pull out of hole to check MWD. Keeps swapping 180 deg. Change out motor and orienter. Run in hole with BHA #2. Tie in. Drill 11527' to 11708'. Difficulty orienting in open hole. 09/29/00 Drill build section from 11708' to 11724'. Baker Inteq motor failed, trip for motor. Drill build section 11724' to 11950'. Finished build section, trip for I deg motor. 09/30/00 Run in hole with BHA #5. Drill 11950' to 12303'. Tripped for a bigger bend motor. Drilled from 12303' to 12467'. 10/01/00 Continue drilling horizontal from 12466' to 12497'. Trip for motor and bit. Drill horizontal from 12497' to 12790'. Trip for motor and bit. 10/02/00 Run in hole with BHA #8. Drill from 12790' - 12956'. Lost Nabors mud pump. Pull up hole to shoe. Circulate with DS pump, wait on backup pump to arrive. Resume drilling to 13044'. Trip for orienter. 10/03/00 Found orienter bad. Run in hole with BHA #9. Drill from 13044' to 13079'. Stuck pipe. Pumped crude, got free. Drill from 13079' to 13123'. Stuck, got free. Drill okay to 13250'. 10104/00 Drilling from 13250' - 13261' (13266' TO). Condition for liner. Make up liner assembly. 10/05/00 Pick up wash pipe assembly. Run in hole to TD with liner. Condition hole. Cement liner. Unsting and circulate out excess cement. Pull out of hole. Stand back washpipe. Jet out BOPS. Begin weekly test of BOPE. 10/06/00 Continue BOPE test. Change master valve on well head. Replace mud pump. Pick up and run Memory CNL/GR. 10/07/00 Run CNL/GR Icg. Process and evaluate logs. Make up and run 1-11/16" perf guns. Run in hole and perf liner. Pull out of hole. 10/08/00 'Complete perf operation. Lay down guns and washpipe. Run in hole. Displace well to crude. Nipple down. Release rig. RECEIVED NOV ZOO0 ( BP Amoco (' Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 11/20/2000 Time: 13:43:30 Page: 1 Field: Prudhoe Bay Co-erdinate(NE) Reference: Well: C-07, True North Site: PB C Pad Vertical (TV])) l~eference: 8' 07 7/2711973 00:00 55.7 Well: C-07 Section (VS) Reference: Well (0.00E,0.00N,187.00Azi) ....W_e_l.l_p_a.t_?: C-07A Survey Calculation Me.od: Minimum Curvature Db: Sybase Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre · SYS Datum:. Men? Se._a_L..ev_.e! .......................................................... _Ge.o_m_a_g_ne_fi_c.M_0_de? ....... B_G. GM2_O_0_0_ .... ........ Site: PB C Pad TR-11-14 UNITED STATES · North Slope Site Position: Northing: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Lasting: 662550.03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-07 Slot Name: 07 C-07 Well Position: +NI-S 2194.49 ff NotChing: 5959456.00 ff Latitude: 70 17 43.947 N +EI-W 2010.02 ft Lasting: 664512.00 ft Longitude: 148 40 4.212 W Position Uncertainty: 0.00 ft ~Veil~a'th: ' ' ~-'(~;~ ............................................................................................................. 6~[i1';~ 'F-r-o--~,~ .................. ~.-(~- ....................................................................... 500292012801 Tie-on Depth: 11479,00 ft Current Datum: 8 · 07 7/27/1973 00:00 Height 55,70 ft Above System Datum: Mean Sea Level Magnetic Data: 9/6/2000 Declination: 26,90 deg Field Strength: 57474 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +NI-S +E/-W Direction _ deg 0.00 0.00 0.00 187.00 '..' .'. "'...;:.' ;..'::':.'.'.:."::'": :'::-:':.':--:..':.:'..'::-...':.:" :.:' "'"::;" '::::.':-.':7:':::: .-.7': '::'c. Survey: MWD Start Date: 1014/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation ~'~'~":~;~'3'~ ........... ~;'~'~':~:~ ........... "~'~'~a-e'~';;~'~"i~';i~i ......... "1 13266.00 0.00 Projected to TD Survey ".71";:.';~',':'' ¥.';~.~i;;~'? :i":'~". ?~-~i~-,,,',':~!'~*~i~'..i~¥~ :-!?",,,,:~?,; ','7~.;,=~ '": ~.;':. ,' :: i'..:,~p~=~ ~';~?!:~i~;[;~?'¥!? '-'D%,'-:~:~¥-::~i;(~¥ ?::,': ..... · ,"' '" 'ft.'.' . .' , :",': deg'.,' :' .' :" "'deg.:~=,'." :",; :.,':.ft',.,.:, ?:',:/','/'~',::",?,:. ',:ft ':..",',.";..' :.,': ='.':,,,/..,'",'ft':::,:."::".:'.':::.":'!',.~:."::=:'! ::'f[;'.~":':.':'.:, ,:":'/!, .?'!,'.:;f~',':,'i':'=,'!,'i.~,;':, :,': ":,:.."'.,:,' ~'",'.::. ',fi :"," ;:. :." ,' :" ,d~g:/t00ff,,' ." :,'d~ ,., ":' ...' -* ;' ........... '~ ........... '--'-' ............ ;-:- ~',--; ....... ~. -:....,,~-."~ ......... ~',~...~,,2. ',-";; ,. ~_; ;':.~'~::'~.: ..~..~,;,,.,i~..~:'~ :~:~L .~;~..;.''2~;2-~-'~"~'.~.~-~`~--~'J~-~-~-~'~'~£'-~'-~-~-~.~-~;-~-:~ 11479.00 35.95 313,52 8787.45 8731.75 837.29 -5706.85 5960168.13 658788.58 0.00 0.00 11520.00 27.50 298.10 8822.35 8766.65 850.08 -5723.99 5960180.54 658771.17 28.41 217,43 11554.00 33.80 277.70 8851.67 8795.97 855.06 -5740.34 5960185.16 658754.71 35.53 292.11 11586.00 42.00 264.40 8876,94 8821.24 855.21 -5759.89 5960184.88 658735.17 36.06 309.68 11628.00 54.80 273,50 8904.80 8849.10 854.88 -5791.17 5960183.87 658703.91 34,46 31.14 11651.00 59.90 280.20 8917.21 8861.51 857.22 -5810.37 5960185,79 658684.67 33.05 49.74 11676.00 57.90 293.20 8930.17 8874.47 863.33 -5830.81 5960191.45 658664.10 45.21 103,51 11708.00 57.60 298,50 8947.25 8891.55 875.12 -5855.15 5960202.70 658639.50 14.04 95.24 11740.00 61.80 287.90 8963.43 8907.73 885.93 -5880.51 5960212.95 658613.92 31.45 291.90 11772.00 68.40 280.90 8976.90 8921.20 893.09 -5908.59' 5960219.50 658585.69 28.61 314.58 11797.00 75,50 278.80 8964.65 8928.95 897.15 -5932.00 5960223.04 658562.20 29.50 343.96 11838.00 86.60 275.60 8991.02 8935.32 902.20 -5972.11 5960227.21 658521.99 28.15 343,83 11871.00 85.60 266.10 8993.27 8937.57 902.69 -6004.99 5960226.98 658489.10 28.88 263.67 11898.00 86.70 256.30 8995.08 8939.38 898.57 -6031.58 5960222.28 658462.61 36.44 276.07 11924.00 89.90 247.80 8995.86 8940,16 890.57 -6056.28 5960213.74 658438.10 34.91 290.47 11958.00 90.50 235.20 8995.74 8940.04 874.38 -6086.10 5960196.90 658408.64 37.10 272,74 11999.00 90.00 227.80 8995.56 8939.86 848.87 -6118.16 5960170.70 658377.15 18.09 266.16 .............. ............. .......... ............. ........... ....... ........ .......... I~kl--t~l~lVl, I ~ NOV g ~ ZOO0 Alaska 0il & Gas Cons. Commission BP Amoco Baker Hughes INTEQ Survey Report Company: BP ~oco Date: 11~0~000 T~e: 13:43:30 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-07, True North Site: PB C Pad Vertical (TVD) Reference: 8: 07 712711973 00:00 55.7 Well: C-07 Section (VS) Reference: Well (0.00E,0.00N,187.00Azi) Welipath: C-07A Snrvey Calculation Me.od: Minimum Curvature Db: Sybase Sutwey · ' ' ~i) ........i~i .......... ~iI~- ............. i:~ .......... $~t7i~ .............. ~ ............. ~; .............. ~i-~-~ ............. ~'i;~ ............ ~ ........... i;F-(~ ................. fi. deg deg ff ff fi. ff fi. fl degll00ft deg : '"~2'0~8'i~ ........ ~:-~ ....... ~'2:l?l-o- ......... '~s:~-~ ........ ~'~-~ ......... ~'~i~-~ ..... ~'s-i~ ...... ~i~'i'~-~ ...... -e'~'~'i':l-,~ ....... ~"~'~'~'~ ........ ~;~(S~- .......... 12126.00 91.30 216.908994.828939.12 756.96-6205.46 5960076.91 658291.8911.30 282.12 12162.00 89.60 210.90 8994.54 8938.84 727.10 -6225.53 5960046.61 658272.48 17.32 254.22 12211.00 90.70 209.20 8994.41 8938.71 684.68 -6250.06 5960003.68 658248.88 4.13 302.91 12245.00 87.30 204.30 8995.01 8939.31 654.34 -6265.36 5959973.01 658234.26 17.54 235.22 12275.00 87.00 201.10 8996.50 8940.80 626.70 -6276.92 5959945.13 658223.30 10.70 264.56 12305.00 87.10 199.00 8998.04 8942.34 598.56 -6287.19 5959916.77 658213.65 7.00 272.68 12335.00 87.10 193.70 8999.56 8943.86 569.82 -6295.62 5959887.85 658205.85 17.64 269.87 12365.00 88.50 187.40 9000.71 8945.01 540.36 -6301.11 5959858.29 658201.01 21.50 282.40 12403.00 88.90 178.60 9001.58 8945.88 502.46 -6303.09 5959820.36 658199.86 23.18 272.50 12441.00 86.90 171.60 9002.97 8947.27 464.65 -6299.85 5959782.63 658203.92 19.15 253.94 12469.00 86.00 168.20 9004.71 8949.01 437.14 -6294.95 5959755.23 658209.42 12.54 255.05 12512.00 89.20 158.70 9006.51 8950.81 396.02 -6282.73 5959714.39 658222.55 23.29 288.39 12553.00 90.00 147.50 9006.80 8951.10 359.51 -6264.21 5959678.30 658241.86 27.39 274.03 12582.00 90.70 139.40 9006.62 8950.92 336.24 -6246.95 5959655.41 658259.62 28.03 274.96 12611.00 91.90 132.40 9005.96 8950.26 315.43 -6226.79 5959635.05 658280.23 24.48 279.80 12646.00 90.40 124.60 9005.26 8949.56 293.66 -6199.42 5959613.89 658308.06 22.69 259.21 12683.00 89.60 117.60 9005.26 8949.56 274.56 -6167.76 5959595.49 658340.13 19.04 263.49 12721.00 92.50 110.20 9004.56 8948.86 259.18 -6133.05 5959580.87 658375.17 20.91 291.44 12766.00 93.30 110.60 9002.28 8946.58 243.52 -6090.93 5959566.13 658417.62 1.99 26.53 12793.00 90.00 114.10 9001.51 8945.81 233.26 -6065.98 5959556.42 658442.79 17.81 133.26 12811.00 89.80 116.90 9001.54 8945.84 225.51 -6049.73 5959549.03 658459.20 15.60 94.09 12866.00 95.40 126.40 8999.04 8943.34 196.73 -6003.03 5959521.28 658506.52 20.03 59.31 12900.00 96.40 131.70 8995.54 8939.84 175.43 -5976.77 5959500.57 658533.23 15.78 78.99 12931.00 92.90 136.20 8993.03 8937.33 153.99 -5954.54 5959479.62 658555.93 18.35 127,77 12953.00 90.10 139.00 8992.45 8936.75 137.76 -5939.71 5959463.71 658571.11 18.00 134.96 13012.00 86.70 146.10 8994.10 8938.40 90.98 -5903.88 5959417.73 658607.96 13.34 115,66 13029.00 86.00 146.80 8995.18 8939.48 76.84 -5894.50 5959403.80 658617.64 5.82 135,08 13076.00 86.50 147.10 8998.26 8942.56 37.53 -5868.92 5959365.06 658644.07 1.24 30.92 13097.00 87.50 151.00 8999.36 8943.66 19.54 -5858.14 5959347.32 658655.24 19.15 75.71 13111.00 90.40 152.00 8999.61 8943.91 7.24 -5851.46 5959335.17 658662.19 21.91 19.03 13170.00 86.90 159.10 9001.00 8945.30 -46.41 -5827.06 5959282.07 658687.75 13.41 116.30 13192,00 86.00 160.50 9002.37 8946.67 -67.01 -5819.48 5959261.64 658695.78 7.55 122,83 13205,00 84.90 158.00 9003,40 8947.70 -79,13 -5814.89 5959249.63 658700.64 20.95 246.09 13234.00 86.50 155.90 9005.57 8949.87 -105.74 -5803.57 5959223.27 658712.54 9.09 307.30 13260.00 86.50 155.90 9007,16 8951.46 -129.43 -5792.97 5959199.82 658723.65 0.00 351.90 RECEIVED NOV 2 2 ZOO0' Naska 011 & Gas Cons, Commission Anchorage REFERENCE INFORMATION 8400 8 86oo ?::L ~ 8~oo 9000 900 600 300 -300 ~6900 ..6600 -6300 -6000 -5700 West(-)/East(+) -5400 -51 O0 -400 200 0 200 400 600 800 1000 1200 1400 Vertical Section at 187,00" [100ft/in} ALASI~A OIL AND GAS CONSERVATION CO~ISSION TONY I~NOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501 -,3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit C-07A BP Exploration (Alaska), Inc. Permit No.: 200-052 Sur Loc: 1766' SNL, 879' WEL, Sec. 19, T1 IN, RI4E, UM Btmhole Loc: 1954' SNL, 1718' WEL, Sec. 24, TIlN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The 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. · y, Chair BY ORDER OF TH_~r. tCOMMISSION DATED this [ ~:~ ~--"" day of April, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. ., , STATE OF ALASKA ALASK/~.' L AND GAS CONSERVATION COMIC" SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Reddll i lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE -- 55.70' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1766' SNL, 879' WEL, SEC. 19, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1078' SNL, 1473' WEL, SEC. 24, T11 N, R 13E, UM C-07A Number 2S 100302630-277 At total depth 9. Approximate spud date 1954' SNL, 1718' WEL, SEC. 24, T11N, R13E, UM 05/18/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well '14. Number of acres in proPerty 15. Proposed depth (MD and TVD) AD.L 028305, 1718' MDI No Close Approach 2560 13129' MD / 8955' TVD 16.'To be completed for deviated wells 1:7. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11485' Maximum Hole Angle 90 ° Maximum surface 2219. ps.ig, At total depth (TVD) 8800' / 3275. psig ,, ..... 18. Casing Program "- Specifications Setting Depth Size To3 Bottom , Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4'~ 2-7/8" 6.16# L-80 ST-L 2459' 10670' 8097' 13129' 8955' S9 sx Class 'G' , .................. ,, ,, ,, ,,,,,,,, , ,, ' ~? " ..... ~!~"" ',!~ ~ .~ ,¥" ~:"'t 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary · ,....,. .... Total depth: measured 11803 feet Plugs (measured) ii', :i '" !~.. ,.j~ 0 i".;.';" true vertical 9053 feet ~."~ 'i'.'. ':' .'.":~ ... ~., ¢' ..,.~: .T', i'.,;??',~';i:i'~ '?,.:"'" Effective depth: measured 11770 feet Junk (measured) ,_."" "..'....'.',:i:i...,.,,..:~ ~.::,. ...... :,..~.J ,~,...~.~,.....:, .... true vertical 9025 feet Casing Length Size Cemented M D TVD Structural Conductor 98' 20" 173 sx Permafrost 98' 98' Surface 2671' 13-3/8" 3750 sx Permafrost II 2691' 2691' Intermediate 2099' 10-3/4" x 9-5/8" Tieback String 2119' 2119' Production 8880' 9-5/8" 1850 sx Halliburton Light & Class 'G' 2119' - 10099' 21 19' - 7739' Liner 2202' 7" 710 sx Class 'G' 9601' - 11803' 7363' - 9053' PerforatiOn depth: measured Open Interval: 11740' - 11760' Sqzd or Isolated Intervals: 11068' - 11740' ORIGINAL true vertical Open Interval: 9001' - 9017' Sclzd or Isolated Intervals: 8458' - 9001' 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 ';'CObtaqt'=E~gi"e~Y'N~rne/NUrnb"c=i i Ted:stag~l,:.:$64~z[6~"'=.' :: i:.:=:!"~;::":.::?!:'=' ii:.". '.':" ' i"' .'= '." .'";' ':'::' ';: ;".' .. ;'. :':. i i';:'PrePared!B~:.Name/Numbe~;Te~e! !~U~!~!e,'. 564~628' 21. I hereby certify that the fore, Icing is true and correct to the best of my knowledge . / Signed TedStagg ~'#~/)-~'-~':' Title CT Drilling Engineer Date ~/a..~//~e Permit Number APl Number .Approval Date See cover letter ~,-~O --,,~' :~ 50- 029-20128-01 x_~~l L~ [OO for other requirements Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes 'J~ No Hydrogen Sulfide Measures ~'Yes [] No Directional Survey Required ~1 Yes [] No Required Working Pressure for BOPE [] 2K; [] 3K; [~,4K; [] 5K; [] 10K; [] 15K Other: ORIGINAL SI~3NED. BY by order of Approved By Robert N. Chl'JS~ll~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX C-07a Sidetrack Summary of Operations: C-07 is being sidetracked to target lower Zone 2 (21P), reserves. This sidetrack will be conducted in two phases. Phase 1: Set retainer, punch and squeeze straddle annulus, set whipstock: Planned for May 1-4, 2000. A Mechanical Integrity Test will be performed. · A whipstock drift and tubing caliper will be run. · E-Line will be used to set a cement retainer and punch the straddle. · Service coil will be used to cement the straddle annulus, clean out and pressure test. · E-Line will be used to set the whipstock. Phase 2: Mill window, Drill and Complete sidetrack: Planned for May 18, 2000. Drilling coil will be used to mill the window, drill and complete the directional hole as per attached plan. Mud Program: · Phase 1&2: Seawater · Phase 3: FIo-Pro (8.6- 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 10,670' MD and cemented with approx. 14 bbls. cement to bring cement to approx. 10,670', or 200 ft above the punched holes in the 3 ~/~" straddle.. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well · · · Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction log will be run in the open hole. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is approx. 3275 @ 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2219 psi. C-07 Vertical Section -500 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 0 I .... TSGR - J7" Liner, 11,803' Path Distance (Feet) 500 1,000 1,500 2,000 2,500 Jc-07a 3/1/00 Case 103 Low side window 25 deg/100' DLS Angle @ K.O.= 36 deg MD:11485 J3 1/2"Tbg. Tail 11,701 MD, J Tot Drld:1644 ft 13129 TD Marker Depths ~:)ri~l Wellbore J 8,698JftTVD I 8,627Jf TVD 8,955J 8,955Jft TVD TSAD I 8,443Jfl TVD Kick Off J 8,737Jft TVD 11,485lfl MD Deprtr @KO 5,786 fl MD KO Pt 11,485J MD New Hole 1644J I Total MD 13,129J TVD TD 8,9551 Curve 1 DLS de~l/100 6 Tool Face Len~lth 180 30 Curve 2 25 - 135, 30 Curve 3 25 -901 30 ;Curve 4 25 -15 240 Curve 5 25 -90 389 10 Curve 6 Curve 7 27 10 -90 399 Curve 8 10 90 499 1,644 Drawn: 3/27/2000 14:04 Plan Name: Case 103 I -7,000 C-07 2,000 1,500 C-07a 3/1/00 Case 103 J Low Side window J25 deg/100' DLS 1,000 5OO 0 I I I I I ~ nnn -- IiUUU -6,500 -6,000 -5,500 -5,000 -4,500 X disfonce from Sfc Loc -4,000 Jwell Name C-07 J CLOSURE JDistance 5,800 ft Az 267 deg ~EW HOLE E/W OC) N/S (Y) Kick Off -5,726 715 TD -5,792 -313 State Plane 658,720 5,959,143 Surface Loc 664,512 5,959,456 DLS de~l/100 Tool Face Length Curve 1 6 180 30 Curve 2 25 - 135 30 Curve 3 25 -90 30 Cuwe 4 25 - 15 240 Curve 5 25 -90 389 Curve 6 10 0 27 Curve 7 10 -90 399 Curve 8 10 90 499 1,644 Drawn: 3/27/2000 14:04 Plan Name: Case 103 TREE: 6" / 5M / ClW ACTUATOR: OTIS WELLHEAD: 13 5/8" / 5M / McEvoy 9 5/8" x 11 3/4" Thermo case I 10 314"55.5# N-80 Butt Csg tieback 4 1/2" 12.6# L80 TDS TBG TBG. ID: 3.958" CAPACITY: .01522 BBL/FT K.B. ELEV= 55.65' C-07a Proposed CompletionB.F. ELEV 36.00' SSSV LANDING NIPPLE (OTIS) (3.813" I.D.) 1991' 4 1/2"x 3 1/2" XO 2015' 13 3/8", 68/72#/ft, 2691' L-80, Btrs Csg KOP · 2700' Max Angle' 58° @ 8600' FOC 3 1/2", 9.2#/ft, L-80, TDS TBG TBG. ID: 2.992" CAPACITY: .0087 BBL/FT 7" PER (40' BeT) I 9601' TOP BeT I 9643' LINER HANGER ~ ~/~,,, ,~#~, N-80 BTRS. PERFORATING SUMMARY RE.. LOS: C.-FD LO~ ~-~-Z~ SIZE SPF INTERVAL OPEN/SQZD 4 11,068 - 11,073' SQZD/ 4 11,085-11,110' SQZD/ 4 11,124-11,166' SQZD/ 4" 4 11,619 - 11,628' SQZD/ 4" 4 11,631 - 11,640' SQZD/11-13-88 4" 4 11,646 - 11,688' SQZD/11-13-88 2 1/2" 6 11,635 - 11,640' OPEN/12/25/98 PERI ~S ABOVE STRAI )DLE PKR 4" 4 11,689- 11,720' SQZD11-13-88 3 3/8 4 11,720 - 11,740' SQZD/1-18-90 5" 4 11,740 - 11,760' 3PEN/3-5-90 PBTD 7" 29#, N-80 BTRS GAS LIFT MANDRELS (MERLA W/1-1/2" RA LATCH) No MD(BKB) TVDss 5 3OO0' 2943' 4 4980' 4637' 3 6991' 5774' 2 7996' 6349' 1 9474' 7213' 3 1/2"X NIPPLE (OTIS) (2.750" I.D.) TIW SBR (12' Long) (5.438 O.D. 4.0" I.D.) 9 5/8" TIW PACKER (HBBP-R) (4.00" I. D.) 9504' 9522' 9540' ~ 3 1/2", 9.2#/ft, L-80, TDS TBG Cement to be squeezed .through retainer set at approx. 11,550' w/returns thru punches @ 10,870'. 2 3/8" liner to be cemented to approx. 10,670'. Top of whipstock approx. 11,475'. TIW Anchor (5.5" O.D., 4.00" I.D.) 7" TIW PKR (HBBP) (4" I.D,) 3 1/2"X NIPPLE (OTIS) (2.750 I.D.) 3 1/2" OTIS WLEG (2.897" ID) (EL MD) 11,687'[ 1,694' 11,696' 3 1/2" XX plug set in tail pipe Do not set down on plug W/smaller than 2.30" tools 2 3/8" CT 10,000 psi Pack-Off C-07a CT Drilling & Completion BOP LU 12" 22.5" 1 aI' 38" 7 1116" Annular 7 1/16" $000 psi Blind/Shear 7 1116" Pipe/Slip 7 1/16' x 5,000 psi 1/16' x $,000 Slips ~ 2 7/8" 7 1/16" ~ ~-~ 2 3/8" Pipe 7 1/16' x $,000 psi SWAB OR MASTER VALVE STATE OF ALASKA ALA~" , OIL AND GAS CONSERVATION C~" MISSION APPLICATION FOR SUNDRY APPRO'~ AL 1 Type of Request: 2. Name of Operator BP Exploration (Alaska) Inc. [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 6. Datum Elevation (DF or KB) KBE = 55.7O' 3. Address I P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1766' SNL, 879' WEL, SEC. 19, T11N, R14E, UM At top of productive interval 1078' SNL, 1473' WEL, SEC. 24, T11N, R13E, UM At effective depth 816' SNL, 1750' WEL, SEC. 24, T11N, R13E, UM At total depth 803' SNL, 1764' WEL, SEC. 24, T11N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Structural Conductor Surface Intermediate Production Liner 11803 feet 9053 feet 11770 feet 9025 feet Length 98' 2671' 2099' 8880' 2202' 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Plugs (measured) 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C-07 9. Permit Number 173-019 10. APl Number 50- 029-20128-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool TVD 98' 2691' 2119' 2119' - 7739' 7363' - 9O53' Casing Junk ~,measureu) ':,., 1. ..... ~ '~''' ~:..1'... I 20" 173 sx Permafrost 98' 13-3/8" 3750 sx Permafrost II 2691' 10-3/4" x 9-5/8" Tieback String 2119' 9-5/8" 1850 sx Halliburton Light & Class 'G' 2119' - 10099' 7" 710 sx Class 'G' 9601' - 11803' Perforation depth: measured Open Interval: 11740' - 11760' Sqzd or Isolated Intervals: 11068' - 11740' true vertical Open Interval: 9001'- 9017' Sqzd or Isolated Intervals: 8458' - 9001' Tubing (size, grade, and measured depth) 4.1/2", 12.6#, L-80 to 2015'; with crossover to 3-1/2", 9.2#, L-80 to 11694' Packers and SSSV (type and measured depth) 7" TIW 'HBBP' packer at 11687'; 9-5/8" TIW 'HBBP-R' packer at 9540; 4-1/2" Otis SSS\ Nipple at 1991' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation May 1,2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Ted Stagg, 564-46.94 [] Detailed Operations Program [] BOP Sketch I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 i17.I hereby certify that the foregoing is true and correct to the best of my knowledge ,,_// · ''¢,,~.. Title CT Drilling Engineer DateCz.__.~ Signed Ted Stagg~..,,---7/- -,,4,/~.,, ..... . ......... ...,~,,,..., ........... ..,....',..,, ' ~.r,. ~'~,:~?.::,.~': i",:.!~,;,'",~ :!~ ~¥;,':'.'.,'..':' ~;, ¢~::~i':;,~'! ,, ;;.'~ :~,i~!~;~!,'~.,'.;.~t,:!;.', ,'.,'.?~'~!~;.;,¢' i~!~!, ~~:!."~ :i~*ili~,'.',..,'"':~!~ ":',:=r =.."' '~,'..'.'~'=":'; ";" ~;?!~ ~""' ;~'!~": '~ f'"'::~ ¢;~'";,i,.. ~,~, ~ !:,'.'!!~ ~' .... ~!~' I~;~l~.~'~i~¢;?:J¢:'f= ?'?:~:? ? "7:¢:'= '="?;¢i ~ '¢'"; ?' f:'h' ?:''' ' ~ =~;~i .~,~1¥, ~.;:~4~,~.~:;" *' ¢:?..;,:' ' ,:??,?::' '~:= ¢~: !'':':' 'i~ =. ,;~,"¢':i¢;,,,:..:.,' ' '"¢~'*~'¢ ';'."?;;'~".~ ? ,' ="' '''~,~:, .: r ........... '~ ¢' '': :~;¢;";c" %~;,., ~,' ~ L,,.,,.=~ ,.,'-":" =, ~¢ i~[¢[~¢,:i~,~.:~%,!. ,,i~=~ ,,,= ,.,'., ,., ¢,,~:-= ~. ;';,,:-!. ..':; .: *:.;.; ".";" ":~;.':".':~. 2"~,.":';r E:. :; .: .. '.! .,.(!~', :! ,~',' ~'~'" ' .','." ~. ' .' '~ '." '"-.:.!¢.;~'.~' :~:' "~4,;' ':.'~;~ ~,5.; ' 1:,.,.. ................. .,,~:~:,:.,~,.,,~,~,,~,,.,.,.,....~,,,. ......... . ......................... , ........ , ...... :.i~'~' · I Approva, No. O0 ,- ¢ IConditions 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 Form 10-403 Rev. 06/15/88 Commissioner Date Submit In Triplicatu i D^'rE I I C.EC,<NO. H 162397 IO '"o' /OOl VE.DO. ALASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 0;20300 C½020300F 100. O0 100. O0 HANDLING: INST: S/H TERRIE HUBBU: .:BP.EXPLORATION (ALASKA).,-..INC. ." s: - ...:'-:: --: - - .. :c.: -'.- -':. -' .... . 'P.O,":;BOX-': 196612- · "::-. - " ' ' -.. -:.: .. · -:!--:.'--'AN~HORAGE;~'ALASK'.A;: 99519-6612" '.'- -.:.... . .. . ......... ..- --:-:.-:-:'~:' ~-:.- '-;;'i:; . .' .- ': ;":~.-: -.:..::..; ..... " ""-':: ""-~ ~i :i:iRST..... NATIONAL.BANK.. OF ASH!cAND AN:AFFILIATE OF '.. NATIONAL CITY BANK CLEVELAND. OHIO No. H 1.62;597 CONSOLIDA fED COMMERClAL.ACCOU'NT.,~,~, '.-': ..-"56-389 ' O01 &2397 .... 412 PAY To-'I -Th:e:.. -..., -.-:. oR:DER:- ";:.. . .- ....- .- . . --i:;:;i."i:'i';' ".i_iii.-.:"?:;;;;'"' i;i".:.: ";;?'i'; ..... DATE .?".". "'::ii ': .. AMOUNT :.- ..-- . ,:: 02/04/00 $100. O0 CLASI(A STATE :.DEP'T OE REVENUE aOcC. C;~"-' ": "..-. ';' :'i!' :?'" :.:'~!:..?:. 300; 1; .'P:OR C UP I NE.':'DR .... ·: -.'; Z - -' :''"'".' -:::: ." .. ANCHORA(~E AK 99501-3120 NOT:!VALID AFl'ER 120 DAYS .... ,' [R ~? ~,q ?,' ~:Ot.l,i?O~,aqS~: OOSt, h;i,q,' WELL PERMIT CHECKLIST FIELD & POOL ~,/~~/~'~ _ COMPANY. , ADMINIS i' i~.TIO N AT INIT CLASS ~._/j _//,-/~ "j/ ENGINEERING APPR DATE GEOLOGY WELL NAME/~X' ~"'Z/~, PROGRAM: exp dev 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 fome ............. 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 ............. ~ N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... CYJN 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to ].C. OC:x3 psig. ~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (:~_ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. N 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ redrll ~ serv wellbore seg ann. disposal para req UNIT# _~,/',~'~ _,('c",) ON/OFF SHORE 31. Data presented on potential overpressure zones ....... ,~NN/Y J~/~~ 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. o./~] 34. Contact name/phone for weekly progress reports [exploratory Y N ANNULAE_DISPOSAL35. With proper ce~menting records, this plan (A) will contain/~Naste in a suita~ble~eiving zone; ....... Y N APPR DATE (B) will not cg~taminat~hwat, et~ or cause ddlling.~aste-:~. Y N to surf~c~e; ~ / _ ~ ,./ (C) will ~ i~li~'mechanic~integrity~oHfi~well used for disposal; Y N (D) ~~amage produ In(fi_..~.g..~on or impair recovery from a Y N . (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQGY: ENGINEERING: UlC/~n~.ular COMMISSION: Comments/Instructions: O Z O Z -I- c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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 APPE .N. DIX~ ,, . . No'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 01/05/17 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD OO/lO/O3 78540 01 2.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 8745.0000: STOP.FT 13253.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM. UNIT SECT. TOWN N RANG PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 -Remarks (1) Value 19 : llN : 14E : MSL : 0 : RKB : 55.7 : KB : 55.7 : N/A N/A : N/A : DIRECTIONAL : All depths are Measured Depths (MD) CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Alaska C-07A Prudhoe Bay Unit 1766' SNL, 879' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 03-Oct-00 500292012801 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well C-07A was drilled to TD @ 13251' MD (8954' SSTVD) on Run 9. (5) The well C-07A was kicked off at 11488' MD (8743' SSTVD) on Run 2. (6) The interval from 13233' MD (8954' SSTVD) to 13251' MD (8954' SSTVD) was not logged due to sensor to bit offset. was not logged due to sensor to bit offset. (7) The data presented here may not be final and will possibly be depth adjusted to a PDC (Primary Depth Control) log later. (8) A Magnetic Declination correction of 26.90 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SSTVD -> Subsea True Vertical Depth, feet SSTVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: SENSOR OFFSETS: RUN GAMMA DIRECTIONAL RUN GAMMA DIRECTIONAL 1 17.46 22.47 2 17.46 22.47 3 17.46 22.47 4 17.46 22.47 5 17.46 22.47 6 18.57 23.58 7 17.70 22.70 8 17.70 22.70 9 17.70 CURVE SHIFT DATA BASELINE, MEASURED, 11519, 11576.5, 11594.7, 11626, 11637.1, 11652.7, 11676, 11681.9 11746.7 11789.7 11832.7 11919.3 11930 2 11960 6 11980 6 11986 3 12000 1 12014 7 12084, 12180, 12230.8, 11519, 11575.5, 11595.1, 11627, 11637.6, 11653.4, 11677, 11682.2, 11745.3, 11790.2, 11832.2, 11919.3, 11931.2, 11961.1, 11980.8, 11986, 12000.8, 12014.9, 12088.5, 12279.7, 12232.6, 22.70 DISPLACEMENT 0 -0.988281 0.494141 0.987305 0.494141 0.741211 0.987305 0.24707 -1.48145 0.494141 -0.493164 0 0.987305 0.494141 0.24707 -0.246094 0.740234 0.24707 4.44434 -0.24707 1.72852 12255.3, 12256 7 12325.9, 12325 1 12671.6, 12670 6 12713.4, 12712 9 12740.9, 12741 4 12780.1, 12780 8 12874.5, 12875.5 12963, 12965, 12974.9, 12980.3, 13127.9, 13129.8, EOZ END 1.48145 -0.740234 -0.988281 -0.494141 0.494141 0.740234 0.987305 1.97461 5.43164 1.97559 ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 115 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Alaska WN C-07A FN Prudhoe Bay unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** 1!!!!!!1!!!!1!1!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 27-0ct-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i GR GRAXl 0 0.0 2 ROP ROPS10 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 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 MWD 68 1 F/HR 4 Total Data Records: 108 Tape File Start Depth = 8745.000000 Tape File End Depth = 13253.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 117 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 Length 4 4 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Alaska WN C-07A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 G~ G~ 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool i GRAX MWD 2 ROPS MWD Code Samples Units 68 i API 68 1 F/HR Size Length 4 4 4 4 8 Total Data Records: 108 Tape File Start Depth = 8745.000000 Tape File End Depth = 13253.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 117 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 00/10/03 78540 01 **** REEL TRAILER **** MWD Ol/O5/17 BHI 01 Tape Subfile: 4 Minimum record length: 2 records... 132 bytes Maximum record length: 132 bytes Tape Subfile 1 Tape Subfile 2 is type: LIS is type: LIS DEPTH 8745.0000 8745.5000 8800 0000 8900 0000 9000 0000 9100 0000 9200 0000 9300 0000 9400 0000 9500 0000 9600 0000 9700 0000 9800 0000 9900 0000 10000 0000 10100 0000 10200 0000 10300 0000 10400 0000 10500 0000 10600 0000 10700 0000 10800 0000 10900 0000 11000 0000 11100 0000 11200 0000 11300 0000 11400 0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600 0000 12700 0000 12800 0000 12900 0000 13000 0000 13100 0000 13200 0000 13253 0000 GR -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 16 7524 11 4187 1.4 3269 13 9620 13.7186 42.4410 17.3379 27.4589 12.1176 15.2921 22.8580 34.9756 14.1044 28.6307 19.6050 14.6422 14.2509 19.6025 -999.2500 ROP -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 19 12 52 79 97 39 126 95 42 71 64 65 85 61 115 96 114 110 5 2500 2500 2500 2500 2500 2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2216 .2411 .0000 .8602 .5197 .3174 0087 6480 0508 8397 6030 7904 2513 8572 8156 0534 2650 1789 6881 Tape File Start Depth = 8745.000000 Tape File End Depth = 13253.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 8745. 8745. 8800. 8900 9000 9100 9200 9300 9400 9500 9600 9700 GRAX ROPS 0000 -999.2500 -999.2500 5000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 0000 -999.2500 -999.2500 98OO 9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10900 11000 11100 11200 11300 11400 11500. 11600. 11700. 11800. 11900. 12000. 12100. 12200. 12300. 12400. · 12500. 12600. 12700. 12800. 12900. 13000. 13100. 13200. 13253. 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 16 9070 10 1720 14 1770 12 3640 13 6090 43 4860 19.0920 23 9640 11 8100 18 1820 22 7680 35 0350 35 6580 21 6580 18.7560 21.4930 13.2140 21.8230 -999.2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 19 12 51 78 97 38 138 10 42 71 64 63 88 31 40 44 114 71 -999 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2500 .2050 .2700 .7540 .8940 .5930 .4040 .4460 .4810 5300 2880 6180 1670 7490 9480 3790 6750 7340 2210 2500 Tape File Start Depth = 8745.000000 Tape File End Depth = 13253.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet [] Tape Subfile 4 is type: LIS
