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Home My WebLink About177-041 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, February 10, 2018 6:23 PM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL;AK, OPS FS2 Field OIL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Chamansingh,Ann Marie; G GPB FS2 Drillsites; Nottingham, Derek; Ohms, Danielle H; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector 09-20(PTD# 1770410) Failed drilling screen MIT-IA Attachments: 09-20.pdf;09-20 AA Approval 03-24-09.pdf All, Injector 09-20(PTD#1770410)operates under AA 4E.033 for slow IAxOA communication. On 2/10/18 DHD performed a failing MIT-IA with rapid OA pressurization during the test. The rapid OA response to the IA pressure indicates a deterioration in the integrity of the well. At this time the well is reclassified as NOT OPERABLE and must remain shut in. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,February 09,2017 P.I.Supervisor (1?ell"l" 410(1 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-20 FROM: Bob Noble PRUDHOE BAY UNIT 09-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ck-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-20 API Well Number 50-029-20261-00-00 Inspector Name: Bob Noble Permit Number: 177-041-0 Inspection Date: 2/3/2017 Insp Num: mitRCN170203130421 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 09-20 Type Inj W '4TVD8197 - Tubing' 1650 1664 1665 1653 PTD 1770410 TypeTest psi Test� SPT _— 2049 _ IA 177 2700 2640 - 2617 - BBL Pumped: 1.4 ' BBL Returned: 1.3 - OA 6 3 - 3 - 3 Interval 1 REQVAR P/F P Notes: MIT-IA every 2 years to the maximum anticipated injection pressure.AA 4E.033.Maximum injection pressure in the last 2 years is 1868 psi CANNED APR 2 7 2U17. Thursday,February 09,2017 Page 1 of 1 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other:Crystal Seal/Cmt Sqz 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 177-041 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20261-00-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-20 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 9685 feet Plugs measured 9460 feetfol I true vertical 9271 feet Junk measured 9567 feet Effective Depth: measured 9460 feet Packer measured See Attachment feet J U L 2 5 2016 true vertical 9054 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 34-114 34-114 1530 520 Surface 2653 13-3/8"72#N-80 32-2686 32-2686 4930 2670 Intermediate 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: 9188 9202 feet feet 9216-9250 feet 9275-9277 feet 9277-9305 feet 9305-9317 feet 9329-9333 feet 9361-9373 feet 9424-9454 feet True vertical depth: 8792-8805 feet feet 8819-8852 feet 8876-8878 feet 8878-8904 feet 8904-8916 feet 8928-8931 feet 8958-8970 feet 9019-9048 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): Sqzed Perfs:9188'-9202',9216'-9250',9275'-9305',9277'-9317',9329'-9333'. , Treatment descriptions including volumes used and final pressure: SCANNED MAY( 1,) . i_" 17, 65 Bbls Cement,2255 Lbs Crystal Seal,100 Bbls 1%Slick KCL,45 Bbls 50/50 Methanol/Water,2000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 4673 20 1180 Subsequent to operation: Shut-In 20 1328 14.Attachments:(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 I Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG ❑ SundryNumber or N/A if C.O.Exempt: 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. p 315-273 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature — Phone +1 907 564 4424 Date 7/20/16 Form 10-404 Revised 5/2015 /�� yrL. i n/ -/1' RBEMM 1V, t6 P1.G Submit Original Only • • C 0 OL U (p 0. Y d d ( E E co 0- - m m o n 00 I— ch Q 0) X a) a) N �c - L (0 (0 4.4N CO CO C CD m N 4 O O co (nN > Ld O io O O CO > O ct N LO N CO CO CO � a C ca N L _ 0:1) N ti O V 2 O N- L) Lo CI. N 00 a0 Y Y H Q CL CL C7 ° CO CO E- d E o 0 0 ZN N N O O O O O • • Q.a 0 0 0 0 0 0 0 0 0 0 (0 CX) C.O 0o r O O O _ O CO f- O f- LO C) LO LO LO N V LO LC) N- C` N- U y 0 0 0 0 0 0 0 0 0 0 0 I.- CO CO LO I- LO N- LO ' co co co c LC) O) co — co N- N •:1- CO :1-m V CO CO CO CO CC) N- CO CX) CO CO N O CO LO r LO (0 O r co co O LC) (A lO — r — LO CO CO LO N- N- N CO CO CO CO N N N- CO CO CA CO CO CO CO F N O CO LO L1') LO LO N O CO O LO O) O CO C0 CO CO CO CO LO N- r V co N LO N N- CO (X) N CO CO iJ 0) d CO N N- N N LO CO N CO N COCO O LO O O CO N CO co co O — co c0 co O N N N- 0) 0) CA CO CO CC) 0) o o C I 1 I I I I I I I I 1 a NN- N N N LO CO N 'Cr CV O CO O LO CA O CX) CO LO • a) co co co co or_.? C.O N O M• � N O O N (X) a0 • W ICL LO CD 0) a LO LO 0 0 O CO CO C3) CO 00 CO z 0 ' 2 2 J J co N *k N *# *k co co *k cssi (CD • fn ,„ cr _ .4- O � N - N _ U O � � m ---- co � NNN N () Lc) Ln OOO vv CD CO LO t _ C O LO LO N 0) 0)) CO in O c co CO CO ct co co '— co co O J N N LO , C0 co Z Z Z Z Z C)O 00000 cHLHF- F- E- E- y U 0 0 0 0 U 0 cISDDDDDD O D LL D D D D D ccQ Z Z z c 0 0 0 0 0 w W m O D CCCCIYCCZ Z D D 1F&E CM141/16 5M • —Si.NOTES:H2S READINGS AVERAGE 125 1 WELLHEAD= FMC NSBB 5M 09-20 Q ') �`/ ppm WHEN ON MI.WELL REQUIRES A SSSV_ • ACTUATOR= AXELSON WHEN ON MI. NOW LEG ON TAILPIPE. OKB. E LEV= 54' BF ELEV= KOP= 3888' Max Angle= 26°@ 7209 2036' —4-1/2"HES X NP,D=3.813" Datum MD= 9253' Datum TVD= 8800'SS 2478' H9-5/8"X 7"BKR ZXP LNR TOP PKR.D=6.29" N2496' H9-5/8"X 7'BKR FLEXLOCK LI42 HIR,ID 6.32" 1 13-3/8"CSG,72#,N-80,D=12.347" — 2683' 14. r, 1 8498' --14-1/2"HES X NP,D=3.813" Minimum ID = 3.70" @ 9090' 1/ / ►tet 0+ L 8663' 7"X 4-1/2"SKR S-3 PKR,D=3.875" TOP OF MILLED CEMENT / ,, ; 8686' H4-1/2"FESXKW,D=3.813" 4v [ 8661' —14-1/2"FES XN NP MLLED TO 3.805'(07/01/15)) 1 � • 8672' —{4-1/2"WLEG,D=4.000" r SCAB LNR,26# L-80,D=6.276" — 8672• ' / 1 14-1/2-TBG 12.6# L-80, 0152 bpf,D=_3.958"1-1 8673' }-"�1A,, ••• ; 8672 -{7"X 4-1/2"PORTED SUB XO,D 3.960" J 111 '�'iv 8694' H5-1/2"X 4-1/2"XO,D=5.53" 4-1/2'TBG, 12.6#,L-80..0152 bpi,D=3.958' --J 8694' ��'4 1`1�1. 11� X111 8706' --{9-5/8"X 5-1/2"UNIQUE MACHINE OVERSHOT I 11111 '111 8800' H ESTIMATE TOP OF CEMENT 11� '414 1■ ■'i♦ 8920'4926'--I PUNCH SET 10/22/03 � ` i1 8932' H5-1/2"BAKER PBR ASSY 44 M� �� 8949' ,—9-5/8'X 5-1/2'BAKER SAB PKR j 5-1/2"TBG-PC,17#,L-80,.0232 bpf,ID=4.892" H 8961' 8961' —15-1/2"X 4-1,2"XO TOP OF 4-1/2"TBG-FC H 8961' 9021' --j4-1/2"OTIS XN NP,D=3.725" 4-1/2"TBG-PC,12.6#,MN-80,.0152 bpf,D=3.958" H 9037' 9037• H ELND TT NO WLEG x 9090' 1-13.70"MILLED CEMENT TOP(06/21/16) PERFORATION SUMMARYAs• 47 • REF LOG: BHCS on 01/11/78 ANGLE AT TOP PERF: 16°@ 9188' ` Note:Refer to Reduction D6 for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE .10 3-1/8" 4 9188-9202 S 06/21/16 ,. : <3- 1 3-1/8" 4 9216-9250 S 06/21/16 3-1/8" 6 9275-9305 S 06/21/16 3-1/8" 4 9277-9317 S 06/21/16 3-1/8" 4 9329-9333 S 06/21/16 3-1/8" 4 9361-9373 0 02/14/78 —I 9460' ]--[FCO(06/21/16)J 3-1/8" 4 9424-9454 0 02/20/84 illiv9567' —FISH-40'X 4-1/2"TUBNG TAIL(06/02/86) FBTD - 9612' ,11,11,1,, 1111111111 19-5/8"CSG,47#,N-80,D=8.681" --1 9662' .111111111111111/11111 11/111111111/111111 � 11111111111111111111 ( l ,_._. f 6685' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRLIDHOE BAY UNIT 01/19/78 ORIGINAL COMPLETION 01/11/12 TMWJMD ADDED H2S SAF-L1 Y NOTE WELL: 09-20 05/31/86 LAST WORKOVER 07/28/15 CJS/JMD MILLED XN NP(07/01/15) PERMT No '1770410 04/03/05 JIM/TIN RWO 04/21/16 JLS/JMD SANDBACK(04/20/16) AF1 No: 50-029-20261-00 04/26/05 SGS/TLH FCO(04/16/05) 06/21/16 LLYJMD CMT SQZ,MLL&SAM)CLEANOUT SEC 10,T1ON,R15E,3655.56'FEL&1367.6'FIS 07/05/05 /ThH SCAB LNR CORRECTION 02/11/11 M3/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • • CO CO 73toT. CO p N C Y Q 00 Q N N N b O O C N a O CLE„,.) Q N a) � C O E O E Q E co o Ca cs) E E E o . a) o O a) a 0) O O -o = s UC CC CO N M a3 m a) o `e m E aCi _ D cn U — m U Q E m m > rn 0) ami 0 a d CD 13 o o L 0 0 o a) E Q a) 0 cp co a O co 0 _ p b 7 a) O O u) O) C co c0 D i c C a U C 0 - a E p �- N 0)-o 0 E N U s- O x 0 @J O z) 0) C O p Q0 O p0 O > w .- * N -o U p io O C U U U U o ¢ j x 0 p a o 0 Co x Cam x a 2 c� 0 a) 0) * w co 3 E 2 '5 * E Q o 3 cn a) p as `,) o o CO v) cn z m u p cts — a.� .,_ m p a) cn 1 0 °- (/) -- E ° ozf a a coo c ,~- • a co >,a a • O o _ Y 3 0 CO 2 ai E o c N p U pC E 7 .a d -,- "O � Q-O 0 ... ~ '� o _o fo _a o N - Ts a) — 0 i " o a3 co p ctS (T5 p - - C p O co C _ Q p J 7 N O -o 'p 3Q O �{) U) �p 0 a) (i) s 0 . * ,# d C O (o U • p cs5 c0 ca O N a) WI O p « O O ++ co CO (o U E a) v) 0 O N .�--. C y C x Y CO CO Q � --- _cp > 3 -' p a0 � CO C" 0 N Cr) a co 0 0) O O Co 0 O O o 0 0 C U U j a O N Z 2 i E .0 0_•2 O E � ,_ p 0__ E i O O a) U C 0 3 N = p ' O (n a,p a o N p-cs C a-� p E a) O a) E CO U N Z ay O Q p 7 ?i N U LO a Q a) CD C N T a) p c o co -0 -0 m E E r CD 'O U U O a N co U p C 0 p N '' 0 0 11 as CT O N LL 73 c O J I- C p N 0 (Li Q N O . Z O a) U) m ,- 0 = O m U 0 m -oCO U m U C S • m C .� 0 c� ro p -- o }, CO m U) OO C ° EE U) O •- as .;_> co co p g ca 0) p y — UN d p p C m N co o C7 a) c 2 a) o-0 E Q - a) : p a) 3 x Q -� Q-- •o m CD_0 a) .0 a) m * .0 Y 4-, Q n ) 0 io U .> Q x ��11x a) a) E a) 73 a p a3 Q a) V as U - O a) 0 co U) i, p y _N N = N o CC O O U O 0 _ 0.1 O O N I E p O U) =... N M 77 CDC f_ . J = Q O O , O p 0 > H _ tom C !� a) J O O N p CO Co -, -, -, -0 cCa = - . a * - O -0 * , o Q', -o pON -) 2 m x 0- O x ai x (d a) w p U) U N U c� EE a 3 N U p co O a3 N U x _O U U ' Jci) in o I� N • N 0 a 3 N - N a� -0 C N > a 0) SI Q N. 0in Til .0 C 0 \ Q) ; O E 0 o - as 3 = 2 as a U `o p •p 'n o up T m up p � a m p = d � O � O) � c aS E a) as0 N z Z _ m •c rnoCrn 0) ma a)O C io C 0) °) U 0v) a) a)a) ••- ( * C o) r 00S)- o a) co Q i* ' U 3 a) 4t io oo Q CC Q x o in . cn O 0)-) Q x 2 ._-Q -) * p _o i "0 7 111 Q CC i U N co C co * H * p x x x O O C p-U H 02Ux IL rn � aco .= x Ux CCU Vx Ux cc � x -, U42 co cc CD2 Ux W I- < Q CO 0 CO CO CO CO CO Q O O o o O O O E— aa) O) O r M M > N U Q • • -o • 5 \ I $ ,- w \ _ E Cl) * o \ \ ƒ CO E \ \- o � / / 0 § \ / m £ o = – o co 071- ( \ \ E \ / 0 \ _ ° @ ® t \ E0 2 = 0 \ \ _ 0 0 � / / § E ƒ \ - _ 2 ° e – - ° ® 5 3 223 b - oL- o i E Z \ 0 , ?k = \ } % \ f c , 2 Sao / COCL - g - nC / oo ^ §- ) oaf k u)\ f ƒ \ \ \\ \ \ / \ CC W \§ \ \ % k ° 3 § O / § / • ZZ. E RI \ E\ k co o E \ O c Ea = R « 8 ® 3 co r n @ 000 , 1_ \ \ \ \ { \ \ \ \ = NS -0 E< c E t 2 E = 2 o E G.) o /cs � \ / ƒ o 0 a) 0 in 0 CO / / k / / \ y : k = '- (2 Lc; 2 y o o .- o - - \ \ \ \ - a \ 7 O.CD \ E2 \� •oE \ \ � / \ CC 0 / 0-\ % / / / Cr O g r \ as f /�? / : \ / / � k a \ ate b b CI g 2 / @ ; w 7 ® § F- / $ 0 = 3 # 2 § ƒ \ / a % e G ° _ £ ® ` \ / ® e ± e - m ; e =o – c \ 2 \ \I % o / / \ / / J ( c \ ( ~ 5e / � / ® \ fy2y / \ aE _ _ y focl ° � / / \ 2 ¥ 3fG % = m / E \ -I 2J5 f \ \ \ f ° � \ ec ƒ 2 \ \ \ E \/ 2 \ / / � 5 a) Ross $ + + * (02 + 907 = 62 6226 / / 5 $ O O o _ _ = 0 > E < o CO 0 o I m = co c c,' c) E O O co co e 8 G 3 mmma � w \ / \ d2tCO—N- $ % CO CO 110 Loepp, Victoria T (DOA) From: Sidoti,Todd <Todd.Sidoti@bp.com> Sent: Wednesday, October 07, 2015 11:39 AM To: Loepp, Victoria T (DOA) Subject: RE: Sundry Number: 315-273 Well: 09-20 PTD: 177-041-0 Follow Up Flag: Follow up Flag Status: Completed Understood,thank you very much! Todd Sidoti I BPXA Well Intervention Engineer I Office 907-564-5113 I Cell 907-632-4113 I todd.sidotiCD_bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Tuesday, October 06, 2015 1:59 PM To: Sidoti,Todd Subject: RE: Sundry Number: 315-273 Well: 09-20 PTD: 177-041-0 Todd, Approval is granted to modify sundry 315-273 to squeeze off zone 3 instead of running a scab liner. Please include this change with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer scAptiEO AUG 0 4 2016 State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeoo a(�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov From: Sidoti,Todd [mailto_Todd.Sidoti@bp.com] Sent: Tuesday, October 06, 2015 1:49 PM To: Loepp, Victoria T(DOA) Subject: RE: Sundry Number: 315-273 Well: 09-20 PTD: 177-041-0 Hi Victoria, New WBS attached as requested. Thanks, Todd • • Todd Sidoti I BPXA Well Intervention Engineer I Office 907-564-5113 I Cell 907-632-4113 I todd.sidotiAbp.com From: Loepp, Victoria T(DOA) [ to:victoria.loepp@ alaska.gov] Sent: Tuesday, October 06, 2015 10:40 AM To: Sidoti,Todd Subject: RE: Sundry Number: 315-273 Can you send me a wellbore schematic of the new change?Also include the well name and PTD#in the subject line Thanx, Victoria From: Sidoti, Todd [mailto:Todd.Sidoti@bp.com] Sent: Tuesday, October 06, 2015 10:37 AM To: Loepp, Victoria T(DOA) Subject: Sundry Number: 315-273 Hi Victoria, Back in May we applied for a sundry on injector 09-20.The job objective was to shut off zone 3 using a scab liner. After progressing the well work we have found that it is no longer possible to set and cement the scab liner in place.The reason is that there is a cement sheath in the liner that severely limits the amount of annular volume available with which to cement the scab liner. Under-reaming this cement sheath prior to setting the scab liner would be very difficult. We would like to change the intervention technique from a scab liner to a cement squeeze. Do we need to cancel the current sundry and re-apply or since the job objective is the same or may we move forward with our current sundry? Thanks, Todd Todd Sidoti I BPXA Well Intervention Engineer I Office 907-564-5113 I Cell 907-632-4113 I todd.sidotiabp.com 2 PvOF Tye ,w.��%sem THE STATE Alaska Oil and Gas �,�►;-s��, ofA T ftS1K2k Conservation Commission 4A `•t'i h=_ 333 West Seventh Avenue ' i` GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Tti'� Main: 907 279.1433 Op, .4LAS 5'� °\v3 )01 Fax: 907.276.7542 F� A� $ www.aogcc.alaska gov N S� G Todd Sidoti0 4" / Well Interventions Engineeri -- BP Exploration(Alaska), Inc. I P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-20 Sundry Number: 315-273 Dear Mr. Sidoti: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of May, 2015 Encl. '1 o.,.. . ',..4 t 7'rte,,, , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mi-',l 0 `A ' ;'3 APPLICATION FOR SUNDRY APPROVALS SI e//, 20 AAC 25.280 GC 1 Type of Request' Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ ' Perforate 0 • Pull Tubing❑ Time Exterp,ion❑ .cam 1, Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. //�6.1 2.Operator Name. 4.Current Well Class: 5.Permit to Dnll Number BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 177-041-0* 3.Address: Stratigraphic ❑ Service 0• 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20261-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 09-20 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028327 ' PRUDHOE BAY, PRUDHOE OIL • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured). 9685 • 9271 • 9612 9201 None 9567 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 34.24-114.24 34.24-114.24 Surface 2653 13-3/8"72#N-80 32 44-2685.9 32.44-2685.76 4930 2670 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 MD(ft). Perforation Depth ND(ft). Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 28.44-8683.32 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Todd Sidoti Email Todd.Sidoti@BP.Com Printed Name Todd Sidoti Title Well Intervetions Engineer Signature Phone 564-5113 Date Prepared by Garry Catron 564-4424 ,s/3 0/ 5 COMMISSION USE ONLY L Conditions of approval: Notify Commission so that a representative may witness Sundry Number Z>\5" 21 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required. / o — 4G4 APPROVED BY Approved by: "1 '! ---• COMMISSIONER THE COMMISSION Date'.S— e_! 11. s/Fp RI to A I i /�' Form 10-403 Revised 10/2012 I \ G ote is tlaw is valid for 12 months from the date of approval. Submit Form and Attachm is in Duplicate RBDMS MAY 1 1 2015 5 73� a) in rn a 600COCOrn , coo00000 = Z Z Q J J Z J a) Q O o O o o O O O _o O O O coco ((:=0) 00oao00 (L=03N- O N O Ln N N (ND- O Ln p V V Ln Ln f- O CO to N- N 0 O o 0 o OLn cc,,) V o o O o 0M 0 M 1- 1` LnM M Ln CO CO - N- N- N CO CO CO CO CO CO ti 1� CO V CO a) cocn O CO N 0) CO N- CO O) CO O CO Ln O Ln CO V CO r O N CO N LO CO CO Ln CO CO CO CO M aO N- co N CO CO CO CO CO N 00 F- Q CO N O M O (A CO CO Ln CO O O CO N CO O N CO CO N- M Ln M LO CO CO Nr CO M N > CO N N- CO CO 00 N CO L F- EN E Ln N N O) O N N cosCO m (o O Ln 00 M V 00 O o (b O CO co - co O d7 N- CO ti CO CO Q (A 1, O N O) O aO M o0 N 00 0) p 2 0 (z CO Ln CO O O LO O CO CO N CO O Q C'') M cc CO O 1- N V (0CO N CA N 1- aO Cb 00 (X) Ln U O O a ro, O O co a00 CO O co co Q z co co O J= Z J ZZ0 '1Jao Z a) *k *k *k J CO N CO NV V . 4 O (N N- O N- N M - aO 00 r .zr N N N - 0) (3) co, ---co N Ln in, 4 (2 O 4 Ln (fl - M M Ln O N V Ln O ,„'4- O CA N Ln Ln 0O co co O) �- N CO Co J Ln r- N CO N CO Z Z Z Z 0)00000 F- HF- F- H w 700DDDD ,r 000 0 0 a 0 0 0 0 CC CC CC C Z Z O O O O w w w w w m Q Z Z Z Z Z D D d d d d J J J J J (n F- Perforation Attachment ADL0028327 Well Date Perf Code MD Top MD Base TVD Top TVD Base 09-20 10/21/03 BPP - 9188 - 9202 8792 8805 09-20 10/21/03 BPP 9216 1 9250 8819 8852 09-20 10/21/03 BPP 9275 9277 8876 8878 09-20 10/21/03 BPP 9277 9305 8878 8904 09-20 10/21/03 BPP - 9305 9317 8904 8916 09-20 10/21/03 BPP 9329 9333 8928 8931 09-20 10/21/03 BPP 9361 9373 8958 8970 09-20 10/21/03 BPP 9424 9454 9019 9048 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028327 Well Facility Type MD Top Description TVD Top 09-20 PACKER 2488 7" Baker ZXP Top Packer 2488 09-20 PACKER 8950 4-1/2" Baker SAB Perm Packer 8563 Summary of Proposed Work BP Exploration Alaska Inc (BPXA) 09-20 Scab Liner PTD 1770410 API # 50-029-20261-00 This procedure includes the following steps: # Type Procedure 1 S Drift/Tag 2 E Mill out XN Nipple 3 S Deploy QCLL liner 4 C Run QCLL liner to bottom/cement liner 5 S WOC 3 days. D/T with dummy gun 6 E Reperf Z2 Current Status Water Injection Well Last Test: 12,000 BBL/D @ 1848PS1 Max Deviation 26° @ 7209' MD Min ID 3.725" @ 8651' & 9021' (4-1/2" XN nipples) Last Tag: 4/16/2005 @ 9500' CTMD Last Downhole Op: 4/16/2005 Coil FCO Latest H2S value: 100 ppm on 11/21/08 SBHP/SBHT 3,437 psi, 160° @ 8800' TVDss (03/29/2009) Well History 09-20 is a PWI injector with a maximum injection rate of 15,000 BWPD. It has a slow IAxOA leak and an AA for PWI only, no MI. the well had a RWO in 2005 to repair TxIA and a PC leak. The most recent (PROF is from 2003. Most of the injection in the well is entering Z3, which is not supporting most of the surrounding producers. Attempts in similar wells to squeeze Z3 have not had much success, so it has been decided not to attempt a straight squeeze. Objectives We will run a 3-1/2" QCLL scab liner and cement it in place to shut-off the high permeability Z3. We will then re-perforate Z2 to move injection lower and improve conformance. Slickline & Fullbore— Drift/ MIT-IA 1. Drift and Tag to TD 2. Load IA w/ crude. 3. MIT-IA to 2500 psi. EL— Mill Out XN Nipple 1. Mill out 4-1/2" XN Nipple at 8651 MD'. Slickline - Deploy QCLL 1. Set releasable X-lock on S/L at 2035' MD. 2. Run QCLL liner joints. 3. Drift the assembled QCLL system. CTU Run and Cement QCLL Liner 1. Engage deployment Sleeve. Establish circulation. 2. Release lock. 3. RIH and land deployment sleeve on No-Go in XN nipple @ 9021' MD. 4. Establish circulation with weight down and PU to release Hydraulic Release spear. 5. Fluid pack backside with diesel. 6. Batch mix and test 34 bbls pumpable LARC cement 7. Pump fluids and cement down CT with backside shut in: 8. Open choke and take returns 1:1 as cement reaches the stinger/nozzle.. 9. Circulate/contaminate excess cement with spacer and Powervis above the BDFV. 10. POOH pumping Powervis at 2:1 to contaminate cement at top of liner. 11. MU Jet Swirl Nozzle and clean out liner with Powervis to TD. Slickline Drift 1. After waiting for cement to setup for 3 days, RU Slickline and drift to TD for 2" perf guns. 2. RDMO. E-Line Peri 1. RIH and perforate Z2. 2 ` x• . TREE= OW 4 1116 5M SAFETY NOTES H2S READINGS AVERAGE 125 WEL L lEA D-.-- FMC NS38 5Mppm WHEN ON MI WELL REQUIRES A SSSV ACTUATOR= AXR SON 09-20 w r ir N ON MI NO WLEGON TAILPIPE. KB ELEV- 54 , BF El EV- KOP= 3888 Max Angle= 2t, tg r2c9 1 1 - L 2035 i-4.4 112' HES X NIP ID-3 813" altUrr MD= 9253' Ctiturr TVO= 8830 SS -=—I 2478' 119-5.8 X 7 BKR ZxP LNR TOP PKR 0=9 29 - 2496' 119-5,8"X r BKR FLEXLOCK LNR HNR,0=6 32' „I 3-313 CSG 721 N-83 0=12 347" — 2683' —A4 4 8498. -1---L4 "'71 HES X NIP 0=3 813' .Minimum ID = 3.725" @9021' ills IN.*: .. „........ ... ,.. - 8663' __1 .17. X417 BKR S-3 PICR.,0.3875 1 44/2" OTIS XN NIPPLE W/ NO-GO 4 8686' 14 i.7 ,in',x NIP 0-i it 3- ,I 4 4 8651' —14 1,7HES XN NIP ID-3 725- 1 ll r ScABLNR261 ,800,-6276 ]--1- 867 2' 1 4 8872' _114-12 WLEG 10-4 00C" I . I..' f2"ma 1281 t 80, 0152 bp/ 0 3 858 H 8673' 1---- ; 8872' 7 X 4-112 PORTED SUB x0,ID'3 980" 8694' 5-1/2..X 4-"i2"XO ID.5 53" 4-1/7 MG 1261,L-80. 0152 bpf 0=3 958" -1—f1e16* — 0446 Al 411 8706' 1—9-5/8"X 5 I/2-uNKluE MACHINE OvElisHoT I 4.44 14 '#. 8800' HESTIMATED TOP OF CEMENT I 4, 14 41 .4,4 441 •A. 1• .6920%4925'4n JR/Ntl PlINCJ-S FT 1n/77111 li • • •,.. 44 '48 I/2"134KEiri P3R ASSY 11/# *et 01 441 8949' 1 9-5/8-X 5-1/7 BAKER SAB PKR 1 SI'? TBG-PC 178,L-80 0232 big,ID,4 892 1--L, 8961' I 8961' ]—I5 '.7 X 4-.1/2-XO.1 TOP OF 4-1/2 TBG-PC 8981' 1 I 1 9021' H4177 OTIS XN NP ID=3 725' I ----- [4 1/2'TBG-PC 1261 MN-80 0152 bp1 0- 3958J -I 9037' r 1 MT -{, END TT NO W EG PERFORATION SUMMARY REF LOG Bl-CS or 01/1'178 1 1 ANGLE A T TOP PERF 16"@ 9188 Note Refer to Production De for historical perf data SIZE SPF INTSRVAL Opn/Sqz DATE 3-1/8" 4 9108-9202 0 04707/84 3-1/8" 4 9215-9250 0 04707/84 3.1/S 6 9275 9305 0 11708796 I 3-1/8" 4 9277 9317 0 02/14/78' 3-178" 4 9329 9333 0 02/14/78 3 1/8" 4 9381 9373 0 02/14/78 1 9600' —FCC(04/16/05) 31/8' 4 9424 9454 0 02/20/84 1 AlliV I tIRR7' FIFSH 40 X 4-1)2"TUBING TA11 (06/02'86)1 1PBTD H 9612' 1 IP 9 4 *449444044 5 9444444 9-518"CSG 471 N-80 0=6 681" H 9662. • •••••••• ... .4.4.4.4.4.4.4 5 1440444 4 44444444 04.444440 [TD 11 9685' 1 DATE -?JV BY 30 W:CV-S DATE REV BY a)MVENTS RIL0110E BAY ow 01/19/78I, ORIGINAL COMPLETION 01/11/12 TMN/./MC AMFD-QS SRH.--Y %C-E, WELL 09-20 05/31186 I LAST WORW3VER PERM-No r1170410 04/03105 LIOM/IL H RWOAR No 50 029 20261 00 047261051-SCS/TLF1 F-00(04/16705) SEC 10,TiON,1215E X.55 56'Ea& 367 6 FN._ I C7105/05,, iTLH SCAB LM4 CC 44-CTON , 0211111' Vf3/J3/0 ACOED SSSV SA 7 ETV NOTE I ) BP Exploration(Alaska) 3 MEMORANDUM TO: Jim Regg P.I. Supervisor �� & �Z�Z�,I�q FROM: Chuck Scheve Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 17, 2014 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-20 PRUDHOE BAY UNIT 09-20 Src: Inspector Reviewed By: P.I. Suprv96r Comm Well Name PRUDHOE BAY UNIT 09-20 API Well Number 50-029-20261-00-00 Inspector Name: Chuck Scheve Permit Number: 177-041-0 Inspection Date: 12/13/2014 Insp Num: mitCS141214153855 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-20 Type Inj W TVD 8197 Tubing 1760 1760 1760 1759 TD 1770410 Type Test SPT Test psi 2049 IA 563 2700 2663 2651 Interval IREQVAR PIF 1 P OA 283 391 476 500 Notes: Two year test per AA4E.033 SCANNE') JAN 0 6 2015 Wednesday, December 17, 2014 Page I of I bp RIcEiven 0 AUG E 12014 iaoGc'c BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOG DATA) Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Contents CD-ROM Containing OPEN HOLE Digital Log Data: 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-171, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-241 B-251 C-10, L2 -07A, 0-02, M-04, M-05, U-14 The information on this CD is to be used for BP Exploration (Alaska) Inc. business only. If you are not the owner or licensed user of this CD, any disclosure, copying or use of the information on this CD is prohibited. If you obtain this Anela K.S CD by error, please return the CD to the address shown g below. BP will pay the postage. Thank you. Please Sign and gancpdc@bp.com Doug Dortch Petrotechnical Data(t Attn: State of Alaska!� Attn: Makana Bender 333 W. 7th Ave, Suite 1 Anchorage, Alaska 99501 If found please return CD to: BP Exploration PO Box 196612 Anchorage, AK 99519-6612 CD1of1 by 0 For External Distribution BPXA OH Log Data 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-24, B-25, , C-10, L2 -07A, 13-02, M-04, M-05, U-14 18 -AUG -2014 Petrotechnical Data enf�' t�-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Inspection Date: 2/8/2013 DATE: Thursday, February 14, 2013 TO: Jim Regg Rel Insp Num: P.I. Supervisor Re -IC Z I Z -7I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 15 Min 30 Min 45 Min 60 Min 09-20 FROM: Chuck Scheve PRUDHOE BAY UNIT 09-20 Petroleum Inspector 1770410 Type Test Src: Inspector Test psi Reviewed By: OA P.I. Suprv� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-20 API Well Number 50-029-20261-00-00 Inspector Name: Chuck Scheve Permit Number: 177-041-0 Inspection Date: 2/8/2013 Insp Num: mitCS130211073006 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-20 Type Inj 1 W ' TVD– 8197 IA j 568 2535 = 2496. 2480 TD 1770410 Type Test SPT- Test psi 2049 OA 298 402 404 – - 463 - -- -- — Interval ___ REQVAR p/F P Tubing 1850 1850 1850 1850 - Notes: S1NED, o C T o 9 2014 Thursday, February 14, 2013 Page 1 of I • MEMORANDUM State of Alaska • Alaska Oil and Gas Conservation Commission TO Jim Regg r� DATE: Friday, February 1I, 2011 P.I. Supervisor ->etqc Z /t(/4 SUBJECT: Mechanical Integrity Tests l BP EXPLORATION (ALASKA) INC 09 -20 FROM: Bob Noble PRUDHOE BAY UNIT 09 -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Comm Well Name: PRUDHOE BAY UNIT 09 -20 API Well Number: 50- 029 - 20261 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN110210160334 Permit Number: 177 - 041 - Inspection Date: 2/10/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -20 1Type Inj. W ' TVD 8197 " IA 400 2390 - 2320 2300 - P.T.D 1770410 'TypeTest SPT Test psi 2390 ' OA 320 400 450 480 Interval REQVAR P/F P - Tubing 1540 1540 1540 1540 Notes: IA X OA comm l �T� 46I,t Prb kh& A u ' • • 3 tkIttielj APR 3 nit Friday, February 11, 2011 Page 1 of 1 • • t(6c) /A\ �� 1 1 . � ALASKA OIL AND GAS 3331. 7th AVENUE, SUITE 100 CONSERVATION COrMnIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL 4E.033 Mr. Steve Rossberg Wells Manager 54 MAR `l BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 RE: PBU 09 -20 (PTD 1770410) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order (AIO) 04E.000, the Alaska Oil and Gas Conservation Commission (Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. BPXA's request to resume miscible gas injection is DENIED. BPXA reported to the Commission that PBU 09 -20 failed a mechanical integrity test (tubing -casing annulus) on June 6, 2003. Diagnostic test results provided to the Commission in December 2003 showed the well to have a production casing leak at a depth of 3400 feet. BPXA performed a rig workover in 2005 involving the installation and cementing of a scab liner to isolate the production casing leak, and installation of a new tubing string with packer. Prior to 2003, it appears that PBU 09 -20 was restricted to water only due to other well mechanical integrity concerns. Water -only injection has continued following the 2005 rig workover. Commission injection records indicate PBU 09 -20 has not injected miscible gas since December 1998. On February 14, 2009, BPXA performed a passing mechanical integrity test in support of an administrative approval request for water - alternating -gas injection. The test was witnessed by a Commission Inspector. The current wellhead pressure trend plot indicates PBU 09 -20 exhibits outer annulus repressurization that tracks and eventually equalizes with the inner annulus pressure. Some level of pressure communication between the inner annulus and outer annulus is evident. Infrequent pressure bleeds while injecting water have been demonstrated to be effective at managing the OA pressure. BPXA does not indicate any other diagnostic tests have been completed, and does not plan to perform corrective action at this time on PBU 09 -20. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the constraints enumerated below. Administrative approval to continue water injection only in PBU 09 -20 is conditioned upon the following: • • AIO 4E.033 March 24, 2009 Page 2 of 2 1. BPXA shall record wellhead pressures and injection rate daily; submit to the Commission a monthl report pressures and of well 2. BPXA shall subm y p p injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA every 2 years to the maximum anticipated injection pressure; 4. BPXA shall immediately notify the Commission and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 5. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection; and 6. The MIT anniversary date is February 14, 2009. DONE at Anchorage, Alaska and dated March 24, 2009. l h.LAS1`.l 0 AA_ L�a.tf � Daniel T. Seamount, Jr. Cat y P oerster Jo or � r : gri� %'' ed Chair Commi sioner Co issioner f rr cc: BPXA Well Integrity Coordinator, PRB -20 P.O. Box 196612 Anchorage, AK 99519 -6612 ''r;ftlA RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person atTected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 14 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t)he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. OPERABLE: 09-20 (PTD #I'i•110) IAxOA Communication awaitin~l Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, February 28, 2009 7:23 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Phillips, Patti J Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 09-20 (PTD #1770410) IAxOA Communication awaiting AA All, A request for an Administrative Approval (AA) for continued. injection into well 09-20 (PTD #1770410) was sent to the AOGCC on 02/26/09. In addition, the well has two competent barriers for injection, proven by a passing MITIA to 2400 psi on 02/14/09. The well has been reclassified as Operable. An update will be sent as soon as we hear word from the AOGCC about the status of the AA. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ,_ 1 4 ~`' ~'~~'` From: NSU, ADW Well Integrity Engineer ,Ad~~~,~,~,-~-,,,~, mss;. ~~'~~~~ ~ S ~ r~r i n /.~ 4E Sent: Sunday, February 08, 2009 7:40 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Phillips, Patti J Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: 09-20 (PTD #1770410) IAxOA Communication All, Well 09-20 (PTD #1770410) is currently on PW! and has been found to have OA repressurization. On 02/04/09, the IA was pressured from 540 psi to 1640 psi to evaluate the OA response. Since that time, the OAP build up rate has been ~90 psi/day. A PPPOT-IC was completed on 02/07/09 in an attempt to mitigate the slow communication and we will continue to monitor the pressures for several more days. The well has been reclassified as Under Evaluation while diagnostics continue. The plan forward for the well is as follows: 1. D: DART - In progress 2. W: PPPOT-IC -PASSED 3. D: Bleed IAP back to original pressures, get OAP build up rate. 4. F: AOGCC MITIA 5. WIC: Apply for AA 3/24/2009 OPERABLE: 09-20 (PTD #1'10) IAxOA Communication awaitin~ Page 2 of 2 A TIO plot, injection plot and wellbore schematic have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/24/2009 • • 09 -20 TIO Plot 4,000 1 i 3 firm I 1 i -0- T6g • IA ,000:1 - 0A 00A -4- 0004 -1111- On 1.000 N ■nd" III N ■N NN .UNNN N • N • 12/13/08 12/20/08 12/27/08 01/03/09 01/10 /09 01/17/09 01/24/09 01 /31 /09 02/07/09 09 -20 Injection Plot 18,000 - 17,000 1700 1 ( - 16,000 1,600 - -15,000 1,500 4,000 1,400 - -13.000 1,300 - - 12,001 1,200 - - 11,000 1,100 • — "HIP 3 900. sou fl -1,000 12/13/08 12/20/00 12/27/08 01/03/09 01/10/09 01/17/09 01/24/09 01 /31 /09 02/07/09 • • bp BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 196612 Anchorage, Alaska 99519 -6612 February 25, 2009 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well 09 -20 (PTD #1770410) Request for Administrative Approval: Continued WAG Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval to continue water and gas injection operations into Prudhoe Bay well 09 -20. The well exhibits outer annulus repressurization of —100 psi /day until it has equalized with IA pressure. However, a pressure test of the inner annulus passed to 2400 psi, indicating the tubing and production casing are competent. Outer annulus operating pressure is maintained below the maximum allowable pressure limit with infrequent bleeding. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well 09 -20 is safe to operate as stated above and requests administrative approval for continued water and gas injection operations. If you have any questions, please call me at 564 -5637 or Andrea Hughes / Anna Dube at 659 -5102. Sincerely, . Steven Rossberg BPXA, Wells Manager • . Attachments Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby /Olsen Hughes /Dube Steve Rossberg East Area Manager Patti Phillips Harry Engel Kurz/Kruger • • Prudhoe Bay Well 09 -20 Technical Justification for Administrative Approval Request February 25, 2009 Well History and Status Prudhoe Bay WAG injection well 09 -20 (PTD #1770410) exhibits outer annulus re- pressurization of —100 psi /day until it has equalized with IA pressure. The most recent MIT -IA passed, demonstrating competent tubing and production casing. Annulus pressure is maintained under MOASP with infrequent bleeds. Recent Well Events: > 02/07/09: PPPOT -IC Passed to 3500 psi LDS OK > 02/08/09: OART Failed —100 psi /day BUR > 02/13/09: MIT -IA Passed to 2400 psi > 02/14/09: AOGCC MIT -IA Passed to 2400 psi Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 2,400 psi, demonstrating competent primary and secondary barriers systems. Pressure on the outer annulus is maintained below the normal operating limit of 1000 psi with infrequent bleeds when the well is on -line. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a monthly report of well pressures and injection rates to the AOGCC. 3. Perform a 4 -year MIT -IA to 1.2 x maximum anticipated injection pressure. 4. The well will be shut -in and the AOGCC notified if there is any change in the well's mechanical condition. • 09-20 TIO Plot 6.0N -- 5.000 • 4.000 III IA 3 ON • a-- OA ODA •- ODOA On 2,000 • 'MO 0 14"tri r • octi I I hit Alumi .11111111 03/1 04443 05/1 06/1"3/0 03F2O03 09120/D3 10/21M 11T21/08 I MO 01f22/9 02/2 S • 09 -20 Injection Plot 2 ....- 18.10 , 1. -17•ECO 1.81 -1604 • 1.81 ! 1 -14;01 tuitio 1 °�`3 13.C4<1 1.400 tii I ` - tzr ,.„0 1 tGdAJ 121 W —w►� I f‘t c lam ��n/ 1 - 5. ° " 7E0• -6.01 E1 ( -5Om 511 - 4 0m 4m -310 - 2.01 2n0 11 -IOW M .. 03/1848 04(1846 mi /191(8 03/1 07/20A 08/2011 03/2048 10/21108 11/21//03 12/22/03 01/22/09 02/22/03 I STATE OF ALASKA ALAS A OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS „~~~~ /O ~'Od~ 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ Other ~ BRIGHTWATER , Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension TREATMENT Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 177-0410 ° 3. Address: P.O. Box 196612 Stratigraphic Service ` ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20261-00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 54 KB ' PBU 09-20 8. Property Designation: 10. Field/Pool(s): ADLO-028327 i PRUDHOE BAY Field/ PRUDHOE BAY Pool 11. Present Well Condition Summary: Total Depth measured 9685 - feet Plugs (measured) None true vertical 9271.14 - feet Junk (measured) 9567 ~~~ Effective Depth measured 9612 feet true vertical 9201 feet Casing Length Size MD TVD Burst Collapse Conductor 101' 20" Surface - 101' Surface - 101' 1530 520 Surface 2683' 13-3/8" 72# N-80 Surface - 2683' Surface - 2683' 5380 2670 Production 9662' 9-5/8" 47# N-80 Surface - 9662' Surface - 9249' 6870 4760 Scab Liner 6209' 7" 26# L-80 2496' - 8705' 2496' - 8331' 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 27 - 8961 4-1/2" 12.6# MN-80 8961 - 9037 Packers and SSSV (type and measured depth) 5-1/2" BAKER SAB PKR 8949' 9-5/8"X7" BKR ZXP TOP LINER ~~~ Pa~k,«~ 3 PKR ~ "X / " BKR S 7 4-1 2 - `` - rp ~ ~~C~E I 0 ° a (~ ~ F ~f ~ ~ ~ ~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Alaska Lll ~;, u:, ;" :;ort'1t11f~~1p~ /4n~l~gr~ida Treatment descriptions including volumes used and final pressure: - .,r, ~ ? ' P ~: ~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 8633 630 1455 Subsequent to operation: 9004 1430 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~' Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ ° GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature '~ ~~ Phone 564-4944 Date 10/14/2008 r-°~ ; ~„""k 6 Form 10-404 Revised 04/2006 ) , ~ - Submit Original Only ~(~/~ . - y-.-,. 09-20 177-0410 PFRF ~TT~(:HMFNT • Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2/1488 PER 9,277. 9,317. 8,877.5 8,915.99 2/14/78 PER 9,329. 9,333. 8,927.55 8,931.4 2/14/78 PER 9,361. 9,373. 8,958.37 8,969.94 2/20/84 APF 9,424. 9,454. 9,019.11 9,048.05 _ 48/84 APF 9,188. 9,202. 8,791.95 8,805.4 4/7/84 APF 9,216. 9,250. 8,818.86 8,851.54 11/8/96 APF 9,275. 9,305. 8,875.58 8,904.44 8/22/03 BPS 9,147. 9,151. 8,752.53 8,756.38 10/21/03 BPP 9,188. 9,612. 8,791.95 9,200.62 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLE D _ SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REM OVED 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 ~ • 09-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/28/2008Started Brightwater chemical app 1600 hours. BWPD injection rate--8900 to :9300. Injection rate pressure--1450 psi. EC9360A Surfactant---Target rate started off with 118 GPH and ramp down at timed intervals to reach a target rate of 59 GPH, Total injected past 12 hours(1279 gallons). EC9378A Polymer---Target 'injected rate (236 GPH), Total injected past 12 hours(3347 gallons) 9/29/2008 Continue B.W. chemical injection. BWPD injection rate--8800 to 9200. Injection rate pressure--1400 to 1450 psi. EC9360A Surfactant--Target rate (59 GPH), 24 hour injected (1305 gallons), Total volume injected to date (2584 gallons). EC9378A Polymer--Target rate (236 GPH), 24 hour injected (7279 gallons), Total infected to date (10626 gallons). 9/30/2008 Brightwater injection to well. BWPD injection rate--8400 to 9200. Injection rate pressure--1400 psi. EC9360A Suafactant--Target rate (59 GPH), 24 hour injected (1,157 gallons), Total injected to date (3,741 gallons). EC9378A Polymer--Target rate (236 GPH), 24 hour injected (6,063 gallons), Total injected to date (16,689 gallons). 10/1/2008 Completed Brightwater injection to well.@ 2200 hrs on 9 30-08. BWPD injection rate--8400 to 9100. Injection rate pressure--1400 psi. EC9360A Surfactant-- Target rate (59 GPH), 17 hour injected (874 gallons), Total volume injected (4615 gallons). EC9378A Polymer--Taget rate (236 GPH), 17 hour injected (3669 gallons), Total volume injected to date (20,358 gallons). FLUIDS PUMPED GALS 4614 SURFACANT 20358 POLYMER 24972 TOTAL Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman ¡~~:~:~~~~~V~9~~~te 100 "....~"t· Field: Prudhoe Bay, Milne pt. \11' 11/28/05 Schlumberger (:;r'\c:n/~¡J ~~_": -~_"",/I ~ ì '~ã ~-W8' NO, 3613 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;2 9 20C) ~.. C()n~;..,:ù{nroi~fl 2.J¡f,;TIorage WII J b# L D D t BL CI CD 'f e 0 oa eSCrlpl10n ae o or PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12103 1 Z-02A 11132059 USIT 10/06/05 1 S-14A 10987547 USIT 09/13/05 1 Y-1OA 10889216 SCMT 02/21/05 1 D.S. 03-33A 10893093 SCMT 03/05/05 1 C-19B 10928633 SCMT 05/15/05 1 09-20 10889215 SCMT 1'17-04 { 02/18/05 1 D.S,09-31C N/A SCMT 11/05/05 1 P-06A 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT 07/04/05 1 D.S. 06-20 11062630 USIT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: \ I Ilf:1 \ 05 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R~;'edb¡J~.. (:1 JU G ~ SCANNED DEC 0 8200S . . MEMORANDUM State of Alaska TO: ) Jim Regg P.I. Supervisor ~/ OJ 5/l1{ Or- ~"1i . -> Alaska Oil and Gas Conservation Commi FROM: John Crisp Petroleum Inspector DATE: Thursday, May 12,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-20 PRUDHOE BAY UNIT 09-20 \{\ 1,/0 f\ Src: Inspector Reviewed By: P.I. Suprv 58ft- Comm Well Name: PRUDHOE BAY UNIT 09-20 Insp Num: mitJCr050512115405 Rei Insp N um: NON-CONFIDENTIAL API Well Number: 50-029-20261-00-00 Permit Number: 177-041-0 Inspector Name: John Crisp Inspection Date: 511012005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-20 Type Inj. w TVD 8197 IA 160 2220 2190 2180 P.T. 1770410 TypeTest SPT Test psi 2049.25 OA 10 180 160 160 Interval WRKOVR P/F p Tubing 1450 1450 1450 1450 Notes: No problems witnessed. SCANNED MAY 3 '1 2005 Thursday, May 12,2005 Page 1 of 1 · STATE OF ALASKA ALASKJ. ·)L AND GAS CONSERVATION C(,..1ISSION REPORT OF SUNDRY WELL OPERRBat!~ED APR 2 ? Z005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028327 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Scab Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): IBI Repair Well 0 Plug Perforations 0 StimA_a Oil & Gas Cons.[Q6nVlWísion o Pull Tubing 0 Perforate New Pool 0 Waiver AnchoragEP Time Extension o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 54' 9685 9271 9612 9201 101' 2683' 9662' 6209' 4. Current Well Class: o Development 0 Exploratory . o Stratigraphic IBI Service 5. Permit To Drill Number: 177-041 6. API Number: 50-029-20261-00-00 99519-6612 9. Well Name and Number: PBU 09-20 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) 9500 feet Size MD TVD Burst Collapse 20" 101' 101' 1530 520 13-3/8" 2683' 2683' 5380 2670 9-5/8" 9662' 9249' 6870 4760 7" 2496' - 8705' 2496' - 8331' 7240 5410 9188' - 9454' 8792' - 9048' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# x 5-1/2", L-80 & MN-80 9037' 17# x 4-1/2", 12.6 9-5/8" x 5-1/2" Baker 'SAB' packer; 7" x 4-1/2" Baker 'S-3' 8949', 8563', 2478' packer; 9-5/8" x 7" Baker 'ZXP' Liner Top packer; 4-1/2" HES 'X' Nipple 2035' Treatment description including volumes used and final pressure: SCANNED !~PR 2 5 2005 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations 1m Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas IBI WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A If C.O. Exempt: Contact Nick Miller, 564-4746 305-059 Printed Name Terrie Hubble Signature /fÔ~ .b,l~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date 04/2-I/as L( , ;).S Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 ~B.O^1) ') ) Well: Field: API: Permit: 09-20 Rig W orkover Prudhoe Bay Unit 50-029-20261-00-00 177 -041 Accept: Spud: Release: Rig: 03/25/05 N/A 04/01/05 Nabors 4ES PRE-RIG WORK 11/08/04 DRIFTED W/3 3/8 DUMMY GUN & S.B. TAGGED TD AT 9280' SLM. LOGGED 4.5 & 5.5 TUBING W/PDS CALIPER AT 50 FPM (GOOD DATA). 02/12/05 DRIFTED TO 8796' SLM W/ 4.5" CENT. DRIFTED TO 8886' SLM W/ 3.70" CENT AND SB. SB EMPTY, CENT HAD CEMENT ON IT. RAN 3.25 CENT. WENT THRU TO 9020' SLM. RAN 3.5 CENT, WENT DOWN TO 9020' SLM. RAN 3.62 CENT. SAT DOWN AT 8896' SLM. RAN 3.62 BROACH, SAT DOWN AT 8896' SLM. WORKED THRU TO 9020'. RAN 3.70 BROACH, SAT DOWN AT 8890' SLM. WORKED THRU TO 9020' SLM. RDMO. 02/18/05 RAN SCMT LOG FROM 8600' - 9000'. FOUND TOP OF CEMENT AT 8764', DEPTH CORRECTED TO TUBING TALLY. TRIED TO RUN HALIBURTON FAS-DRILL 3.66" PLUG, COULD NOT GET BELOW CEMENT STRINGER AT 8873'. COULD NOT REACH TARGET DEPTH OF 8980'. 02/21/05 RAN 3.725 - 3.8" BROACHES FROM 8831' TO 8940'. BELOW 8940' IS CLEAR TO XN NIPPLE AT 8994'. 02/22/05 BROACH TIGHT SPOT IN TUBING FROM 8831' SLM TO 8942' SLM. TAG XN NIPPLE AT 8992' SLM W/ 3.80" BROACH. 02/27/05 SET 4.5" HES FASDRILL BRIDGE PLUG AT 8976'. SHOOT STRING SHOT IN PREPARATION FOR CHC. SHOT INTERVAL = 8705'-8717'. 02/28/05 SHOT TUBING PUNCH FROM 865' TO 8653'. SHOT 1.56" HSD 1564 PJ, HMK CUT 5.5" TUBING AT 8716' WITH 4-3/16" CHEMICAL CUTTER. RECE I\/r:: r\ APR 2 2 Z005 Alaska Oil & Gas COli}., .''''d'. . ,~,¡(!n Anchorage ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-20 09-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES pate COde· . NPT· Phåse FrÖrn- To 3/25/2005 04:00 - 08:00 08:00 - 10:00 4.00 MOB P 2.00 RIGU P PRE PRE 10:00 - 12:30 2.50 RIGU P 12:30 - 14:00 1.50 KILL P 14:00 - 14:30 0.50 KILL P 14:30 - 15:00 0.50 KILL P 15:00 - 18:00 3.00 KILL P 18:00 - 19:00 1.00 WHSUR P 19:00 - 21 :00 2.00 WHSUR P 21 :00 - 23:30 2.50 BOPSUP P 23:30 - 00:00 0.50 BOPSUP P 3/26/2005 00:00 - 04:00 4.00 BOPSURP 04:00 - 04:30 0.50 WHSUR P 04:30 - 05:30 1.00 WHSUR P 05:30 - 06:00 0.50 WHSUR P 06:00 - 07:00 1.00 PULL P 07:00 - 07:30 0.50 PULL P 07:30 - 10:00 2.50 PULL P PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 10:00 - 10:30 0.50 PULL P DECOMP 10:30 - 16:30 6.00 PULL P DECOMP 16:30 - 18:00 1.50 PULL P DECOMP 18:00 - 19:00 1.00 PULL P DECOMP 19:00 - 20:30 1.50 PULL P DECOMP 20:30 - 00:00 3.50 PULL P DECOMP 3/27/2005 00:00 - 01 :30 1 .50 CLEAN P DECOMP 01 :30 - 02:30 1.00 CLEAN P DECOMP 02:30 - 05:00 2.50 CLEAN P DECOMP 05:00 - 09:00 09:00 - 10:00 4.00 CLEAN P 1.00 CLEAN P DECOMP DECOMP Alaska Oil & G§bHa'\5aÇa~'~w~ 977 Start: 3/24/2005 AM rage 4/1/2005 Rig Release: 4/1/2005 Rig Number: . . . ... .. . ..... .... . . . . '..... '. ... .. .... .. . :.' .... . ... . ··.Descriptiqndf()per~ti()hš ... RDMO from DS 17-11. Move Rig to DS 09-20i. Spot Sub Base on Well Slot 09-20i. Spot Pits and Pipe Shed. Spot Camp. Take on 9.8 Ib/gal Brine in Rig Pits. Accept Rig at 10:00 hrs. Spot Tiger Tank. Lay Lines. Rig up Lines to Tree for Well Kill. Pick-up Lubricator and attempt to pull BPV. DSM inspect and re-repair Pulling Tool. Second attempt, good. Lay down BPV and Lubricator. Well on vacuum. OAP = 140 psi. PJSM and Well Kill Ops Meeting with all. Pressure Test Lines at 250/3500 psi. Final inspection of line going out to the Tiger Tank. Open well. SITP = 0 psi. SICP = 0 psi. Begin circulation @ 2 BPM, 50 psi & end @ 5.5 BPM @ 250 psi. Total bbls pumped 600. Partical returns. SID monitor well. Well dead. Vacuum. Blow down & R/D lines. Set BPV & prong. Test to 1000 psi, OK. Bleed off tubing void. N/D & remove X-mas tree. N/U BOPE. R/U & begin testing BOPE. BOP test witnessing waived by John Crisp w/ AOGCC. Test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 4000 psi. Annular 3500 psi. R/D test equip. Drain BOP stack. Blow down kelly. Pull blanking plug. Wait on DSM to pull BPV. Pick-up Lubricator. Pull BPV. Lay down same. Rig up Camco Spooling Unit to spool Control Line. Pick-up Landing Jt. BOLDS. Pull Tubing Hanger to Floor with no problems. Broke at 175K. Pulling free at 140K. Lay down Tubing Hanger and Landing Jt. Start POOH. Single down 51/2" 17lb/ft L-80 LTC Tbg in Pipe Shed. Spool Control Line to SSSV (52 Jts). Lay down SSSV. Recovered all Clamps and SS Bands. (27 Clamps and 5 Bands). Rig down Spooling Unit. Continue to single down 5 1/2" Tubing in Pipe Shed. Recovered 198 Jts, 4 Pup Jts, and SSSV Assembly. Plus a 19.02 Chemical Cut Stub. Clean cut. R/D tubing handling equip. Clear & clean rig floor. R/U to P/U BHA. Load, tally & caliper BHA #1. M/U BHA #1' as follows: Shoe, Extension, Boot Basket, XO, Boot Basket, Bit Sub, Bumper Sub, Oil Jars, 9 * 4 3/4" DCs. TL = 324.36'. P/U 31/2" DP, 1 x 1 & RIH w/ BHA #1. Can't to P/U 31/2" DP, 1 x1 & RIH w/ BHA #1 P/U 264 jts. P/U kelly fill hole & break circulation. 5 BPM @ 900 psi. Tag up on tubing stub @ 8705'. dress & washover tubing stub to 8716'. P/U 135k, S/O 124K, Rot 130K. 60 RPMs, torq 3.5K, WOB = 2-4K. Work up & down & over stub several times. Still needs slight rotation to get over stub. Mix & pump Hi-Vis pill around. 5 BPM @ 900 psi. Blow down lines. Set back kelly. Lost 32 BPH while circulating. POOH w/3 1/2" Drill Pipe and BHA #1. Lay down BHA #. Clean out Junk Baskets. Printed: 4/4/2005 8:29:20 AM ') ') RECEIVED Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-20 09-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From -T() Hours Task 'Code· NPT Phase 3/27/2005 10:00 - 11 :00 1.00 CLEAN P DECOMP 11 :00 - 11 :30 0.50 EVAL P DECOMP 11 :30 - 12:30 1.00 EVAL P DECOMP 12:30 - 15:00 2.50 EVAL P DECOMP 15:00 - 16:30 1.50 EVAL P DECOMP 16:30 - 20:00 3.50 EVAL P DECOMP 20:00 - 20:30 0.50 CASE P TIEB1 20:30 - 21 :30 1.00 CASE P TIEB1 21 :30 - 00:00 2.50 CASE P TIEB1 3/28/2005 00:00 - 04:30 4.50 CASE P TIEB1 04:30 - 05:30 1.00 CASE P TIEB1 05:30 - 06:00 0.50 CASE P TIEB1 06:00 - 09:00 3.00 CASE P TIEB1 09:00 - 10:00 1.00 CASE P TIEB1 10:00 - 11 :00 11 :00 - 12:30 12:30 - 13:00 13:00 - 16:30 1.00 CASE P 1.50 CASE P 0.50 CASE P 3.50 CEMT P TIEB1 TIEB1 TIEB1 TIEB1 16:30 - 17:00 17:00 - 17:30 0.50 CASE P 0.50 CASE P TIEB1 TIEB1 . .. .. ." . . .. ".. . ,. Alaska UII &. lias (;ons~·l,;ommlsslOn Anc~~ Date: 12/28/1977 Start: 3/24/2005 End: 4/1/2005 Rig Release: 4/1/2005 Rig Number: .. Descri ption. Of Opèr~ti<>ns Clear and Clean Rig Floor. Continue to load and tally 7" Casing. Make-up Halco 9 5/8" RTTS Packer. TIH with Packer and 31/2" Drill Pipe. Set Packer at 2,842'. Fill hole with Brine (44 bbls). Pressure test 9 5/8" casing from 2,842' back to surface at 4,000 psi/30 min. Record on Chart. Good test. POOH w/ RTTS. UD RTTS. Clear & clean rig floor. R/U tools to run liner. Load & inspect overshot, shoe track & liner hanger assys. Hold PJSM w/ all hands. Review liner running procedures. M/U & run Overshot. Install 1 1/2" Ball in Ball Seat. Fill Ball Seat up to Ported Sub with 20/40 Mesh Sand. , Continue making up remainder of shoe track assys. Baker lock all connections. Check floats. P/U 7" liner & RIH. Ran 50 its. Con't to RIH w/ 7" liner. Ran total of 148 its. 7" 26#, L-80, BTC-MOD casing. Ran total of 87 turbolators, every other one on 1st 120 its, then every it from 121 to 147. P/U liner hanger/packer assy & RIH. R/D 7" casing tools. R/U tools to run 31/2" DP. RIH w/ 7" liner on stands of 31/2" DP. Continue TIH with 3 1/2" Drill Pipe and 7" Liner. Call out Vac Trucks. Tag Top of 51/2" Stump at 8,705'. Swallow Stump".actually saw brass pins shear at -5K). Continue to swallow Stump (9'). Stack out. Pick-up to neutral plus 2' and space out. Install Cementing Head. Wait on Vac Trucks and Cement Equipment. Rig up Cementing Equipment and lines. Spot Vac Trucks. Hold PJSM with All. Prime up and pressure test Line at 5,000 psi with 5 bbls of FW. OAP = 0 psi. Pump 43 bbls FW Spacer. Pump (191 bbls) Class G Cement...start at 5.5 bpm/1175 psi, density = 15.8 ppg. End Cement at 5.3 bpm/750 psi, density = 15.79 ppg. Drop Drill Pipe Dart. Pump 5 bbls FW. Start Sea Water at 3.0 bpm/100 psi. Dart landed 2775 psi. Shear Liner Wiper Plug. Continue with displacement. Increase rate at 5.6 bpm/250 psi. Displace 100 bbls at 5.6 bpm/275 psi. Displace 150 bbls at 5.5 bpm/480 psi. Displace 200 bbls at 5.4 bpm/1 015 psi. Displace 225 bbls at 5.3 bpm/1250 psi. Displace 235 bbls at 5.3 bpm/1380 psi. Displace 245 bbls at 5.3 bpm/1460 psi. Displace 246 bbls. Slow down rate to 2.0 bpm/1075 psi. Bump Plug at 15:17 hrs with 252.8 bbls pumped (calculated rate to bump plug was 252.5 bbls). Increase pressure to 3,200 psi and hold to set Liner Hanger. Increase pressure to 4,200 psi and slack off to set Packer. Bleed off pressure. Check Float. Rotate Running tool to release from Liner Hanger. Reverse Drill Pipe x 4. Saw no Cement returns. Shut down Pump. OAP = 0 psi. RD Cement Head. TOOH with 31/2" Drill Pipe and Baker Setting Tools. Lay down Baker Setting Tool. Printed: 4/4/2005 8:29:20 AM ) ····B.PEXPIl;OAA T,ONRECEI\lED Pâge30fS Ö.Þøl!~tiQr.iS$ijn1ro~ryJ:¡&pórt.APR22ZÛ05: .. ... .. . . ^laak:ïOiI& GIS Cofts.Commission>. . Anchorage Spud Date: 12/28/1977 End: 4/1/2005 ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-20 09-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date Frorn-Tó Hours Task Code' NPT IPhê3.se 3/28/2005 17:30 - 18:00 18:00 - 19:00 0.50 CASE P 1.00 CASE P TIEB1 TIEB1 19:00 - 21 :00 2.00 CASE P 21 :00 - 22:00 1.00 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 00:00 1.00 CASE P 3/29/2005 00:00 - 03:00 3.00 WHSUR P 03:00 - 05:00 2.00 WHSUR P 05:00 - 05:30 0.50 WHSUR P 05:30 - 06:30 1.00 WHSUR P 06:30 - 07:30 1.00 CASE P 07:30 - 09:00 1.50 CASE P 09:00 - 10:00 , 1.00 CASE P 10:00 - 16:00 6.00 CEMT P TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 16:00 - 19:00 3.00 CEMT P TIEB1 19:00 - 19:30 0.50 CEMT P TIEB1 19:30 - 22:30 3.00 CEMT P TIEB1 22:30 - 00:00 1.50 CEMT P TIEB1 3/30/2005 00:00 - 01 :00 1.00 CEMT P TIEB1 01 :00 - 03:00 2.00 CEMT P TIEB1 03:00 - 03:30 0.50 CEMT P TIEB1 03:30 - 06:00 2.50 CEMT P TIEB1 06:00 - 08:30 2.50 CEMT P TIEB1 08:30 - 14:30 6.00 CEMT P TIEB1 14:30 - 15:00 0.50 CEMT P TIEB1 15:00 - 16:30 1.50 CEMT P TIEB1 16:30 - 19:00 2.50 CEMT P TIEB1 Start: 3/24/2005 Rig Release: 4/1/2005 Rig Number: . . . .. . . . . :. . .. .... . {>ésqriþtiÓn· ()f bpérations····· Clear and Clean Rig floor. M/U BHA #2 to clean out liner as follows: Bit, 2 - Boot baskets, 7" casing scraper, Bit Sub, Bumper Sub, Oil Jars, 9 * 4 3/4" Dcs. TL = 313.78 RIH wI BHA #2 on 31/2" DP to 6019'. P/U storm packer. RIH & set @ 28'. Test packer to 2000 psi, Ok. Drain stack. N/D BOPE. P/U set back same. Bleed of hanger void. N/D & remove tubing spool. Clean up casing spool. Install new standard FMC tubing spool & pack off. N/U BOPE & spacer spool. Test hanger void to 3500 psi, 15 min. OK. Install test plug & test breaks in BOP. LP 250 psi. HP 4000 psi. Pull test plug. Install wear bushing. UD running tool. RIH & retreive storm packer. POOH & LID same. Con't to RIH wI BHA #2 on 31/2" DP. Ran total of 85 stands. .Close in well & pressure test casing & liner top to 4000 psi for 30 min. Tested good. Charted same. Tag up on cement @ 8536'. P/U kelly break circulation & drill cement, landing collar & float shoe to ported X-O @ 8678'. P/U 140K, SIO 107K, Rot 125K. 80-100 RPMs, 70 SPM @ 700 psi, Torq 4-6K. WOB 4-12K Circulate & pump Hi-Vis sweep til clean. 5 1/2 BPM @ 1400 psi. POH & UD 5 jts 31/2" DP. Pump dry job. POOH & stand back 3 1/2" DP. Stand back drill collars. UD BHA #2. Clear & clean rig floor. R/U tools for 27/8" PAC DP. P/U 27/8" PAC DP & M/U BHA #3 as follows: 3.70" MM Mill, Bit Sub, 13 jts 2 7/8" PAC DP, XO, Bumper Sub, Oil Jar, 9 * 4 3/4" DCs. TL = 707.89'. RIH wI BHA #3 on 31/2" DP. P/U kelly. Tag up on fill @ 8678'. Break circulation. Displace well to 8.5 ppg clean seawater. 4 BPM @ 2200 psi. Clean seawater all around. Ease in and wash sand fill down to ball-seat. Pump rate = 5.0 bpm, 1900 psi. Tag ball-seat, mill up same with 5-6K WOB, 5 bpm, 2200 psi. 20-min to mill thru. Pump pressure dropped back to 1900 psi once thru ball-seat. Acts like mill is pushing junk/rubber ahead of it. If rotary is kicked out, we stack weight even with the mill inside the old 5.5" tubing. So continue rotating ahead at 5 BPM, 5-10K WOB. No excess torque observed. Cement wlsome sand, aluminum flakes over shaker. Mix and pump 25-bbl hi-vis sweep. Continue milling ahead in the original 5.5" tubing. Sweep at mill, start seeing improved ROP. Hardly saw the Fasdrill at 8976'. Started taking weight at the "XN" nipple. Well is not taking much fluid. Con't to mill & clean out to to 9084'. Had to rotate to go down. No losses noted while milling. Tagged up on 7" x 41/2" Ported X-Over. P/U 140K, SIO 107K, Rot 125K. WOB 5-10K, 70 RPMs, 5 BPM @ 2000 psi. Printed: 4/4/2005 8:29:20 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-20 09-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Alaska Oil & Ga§~88b~r:'~~'~'ID1977 Start: 3/24/2005 An~ge 4/1/2005 Rig Release: 4/1/2005 Rig Number: · batß ... From- To Höurs Task·· Code< NPT pha$é· . .Oéscriptiþn· ofOþératipns· 3/30/2005 19:00 - 20:30 1.50 CEMT P TIEB1 Mix & pump 40 Bbls Hi-Vis sweep. 5 BPM @ 2000 psi. Recovered cmt from sweep. Pumped 460 bbls til hole cleaned up. No Losses noted. 20:30 - 21 :00 0.50 CEMT P TIEB1 Set Back Kelly. Pull & stand back 5 stands of DP. Blow down lines. 21 :00 - 22:00 1.00 CEMT P TIEB1 Cut & slip 84 I of drilling line. Service rig. 22:00 - 00:00 2.00 CEMT P TIEB1 POOH & LDDP. 3/31 12005 00:00 - 03:30 3.50 CEMT P TIEB1 Con't to POOH & UD 31/2" DP. UD total of 288 jts. 03:30 - 04:30 1.00 CEMT P TIEB1 POOH & UD BHA #3. 04:30 - 06:00 1.50 CEMT P TIEB1 Pull wear bushing. RID DP tools. Clear & clean rig floor. 06:00 - 08:30 2.50 RUNCOMP RUNCMP PJSM wlcrew, Baker Packer rep, Nabors Casing rep, Co. man on running order, etc. RU Torque Turn equipment. P/U 4-1/2" 12.6#/ft, L-80 TC-II tailpipe ass'y and packer. Baker-Lock all connections below packer. TC-II connections torqued to 3850 ft-Ibs. 08:30 - 20:00 11.50 RUNCOMP RUNCMP Run 4-1/2", 12.6#/ft, L-80 TC-II completion as follows: 4-1/2" WLEG 4-1/2", 12.6#/ft, L-80 TC-II pup 4-1/2", 12.6#/ft, L-80 TC-II pup 4-1/2" HES "XN" nipple - 3.725" no-go 4-1/2", 12.6#/ft, L-80 TC-II pup Full joint 4-1/2", 12.6#/ft, L-80 TC-II tubing 4-1/2", 12.6#/ft, L-80 TC-II pup 4-1/2" HES "X" nipple (3.813" ID) with RHC sleeve pre-loaded 4-1/2", 12.6#/ft, L-80 TC-II pup 4-1/2", 12.6#/ft, L-80TC-1I pup 7" x 4-1/2" Baker S-3 perm packer 4-1/2", 12.6#/ft, L-80 TC-II pup Full joint 4-1/2", 12.6#/ft, L-80 TC-II tubing 4-1/2", 12.6#/ft, L-80 TC-II pup 4-1/2" HES "X" nipple 4-1/2", 12.6#/ft, L-80 TC-II pup 148 joints 4-1/2", 12.6#/ft, L-80 TC-II tubing 4-1/2", 12.6#/ft, L-80 TC-II pup 4-1/2" HES "X" nipple 4-1/2", 12.6#/ft, L-80 TC-II pup 45 joints 4-1/2", 12.6#/ft, L-80 TC-II tubing 4-1/2", 12.6#/ft, L-80 TC-II space-out pup Full joint 4-1/2", 12.6#/ft, L-80 TC-II tubing 4-1/2", 12.6#/ft, L-80 TC-II pup pinXpin FMC 12" x 4-1/2" tubing hanger All connections Torque-Turned to 3850 ft-Ibs. Jet Lube Seal Guard pipe dope. 20:00 - 20:30 0.50 RUNCOrvP RUNCMP Tag up @ 8678'. P/U 2' & space out completion. M/U hanger & landing jt. 20:30 - 00:00 3.50 RUNCOrvP RUNCMP R/U & displace well wI heated fluids by reverse circulating. Pumped 290 bbls of 1 % KCI, followed by 250 bbls of inhibited seawater. 3 BPM @ 200 psi. 4/1/2005 00:00 - 00:30 0.50 RUNCOrvP RUNCMP Land hanger. P/U 102K, SIO 85K. RILD8. 00:30 - 02:00 1.50 RUNCOrvP RUNCMP R/U Hot Oil & test lines. Freeze protect well by reversing in wI 150 Bbls of diesel. 3 BPM @ 500 psi. NOTE: attempted to bullhead diesel down tbg: pressured up to 2000 psi after 3.3 Printed: 4/4/2005 8:29:20 AM ~) ) Bþ EiXPLOBATIONREÇEIVED Rage5ø!5 ........> > .. ..... .. ..... . ... ........ . ...... ... .. ..... .. d .. . ... ..... . ..... ...... . ........ AP R222005 .... . . . ·..():p~ré1tiorl~SummarY.·Flepø~~.. ..... ... ........................ ......... ................ .... . .. . ..... · · ··^,.ške OilR.GasCons.Comm.s~'ofl . Anchorage Spud Date: 12/28/1977 End: 4/1/2005 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 09-20 09-20 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/24/2005 Rig Release: 4/1/2005 Rig Number: Date From'-To Hours Task Code NPr Phase .". . .., . [)esëriptiön of Öperations 4/1/2005 00:30 - 02:00 02:00 - 03:30 03:30 - 04:00 04:00 - 06:00 1.50 RUNCOMP 1.50 RUNCOMP 0.50 RUNCOMP 2.00 RUNCOMP RUNCMP bbls pumped. RUNCMP R/U & allow diesel to U-tube down tubing. RUNCMP Drop ball/rod. LID landing jt. R/U & test lines to 4000 psi, OK. RUNCMP Pressure up tubing to 4000 psi & set packer. SI & Test for 30 min. Bleed off tubing to 2000 psi. & SI. Pressure up on annulus to 4000 psi, SI & test for 30 min. Bleed off test pressure. Both tests pass. Set TWC in hanger and test to 1000 psi. ND BOP stack. NU FMC adapter flange (13-5/8" x4-1/16"). NU 4-1116" CIW tree. Pressure test tubing hanger void to 5000 psi. Pressure test tree to 5000 psi. Secure well and cellar. Release rig at 12:00. Prep for move to Badami. 06:00 - 07:00 1.00 RUNCOMP RUNCMP 07:00 - 08:00 1.00 RUNCOMP RUNCMP 08:00 - 10:30 2.50 RUNCOMP RUNCMP 10:30 - 11 :30 1.00 RUNCOMP RUNCMP 11 :30 - 12:00 0.50 RUNCOMP RUNCMP Printed: 4/4/2005 8:29:20 AM ') ') ...........,..."',..'..,.........,.,.,..... w·,..·...··.·,..··....·...·,..·...,w·.··.."'·····..·,···· RECE/VEd~~~~t: APR22 2005 =~~ase: Ahilk~U;I& G .. .... . . · .. ... ... .......,.......",:.,,,,,...,,,...,..,...,..,....;.,,,;.;,"~,Cons.Comm¡s8i'·'··· Anchora On POST RIG WORK ge 03/25/05 N/A 04/01/05 Nabors 4ES Well: Field: API: Permit: 09-20 Rig Workover Prudhoe Bay Unit 50-029-20261-00-00 177 -041 04/09/05 PULLED BPV, PULLED B&R AT 8572' SLM. PULLED RHC AT 8576' SLM. D&T W/3.5" CENT & SAMPLE BAILER TO 9012' SLM. WORKED DOWN TO 9053' SLM. RUN 3.5" LIB TO 9028' SLM. MARKS ON LIB. ARE MOSTLY ON THE SIDES OF LIB FROM RIH. 04/14/05 PERFORM BOP TESTS. MU BHA WIJARS, 2 7/8" MOTOR & 3.7" SIX BLADE JUNK MILL. RIH. MILLED THROUGH TIGHT SPOTS AT 8910' AND 8945'. TAGGED FILL AT 9044' CTM. MILL TO 9103' WI FREQUENT FLOPRO SWEEPS. 04/15/05 MILLING WI JARS, 27/8" MOTOR & 3.7" SIX BLADE MILL FROM 9013' - 9175', JUST ABOVE TOP PERF. NO ADDITIONAL PROGRESS. POOH. 4 OF 6 MILL FLOW PORTS PLUGGED WITH RUBBER AND CEMENT. CUT 100' OF COIL. MU/RIH WI JARS AND 3.13" VENTURI. RECOVERED QUART OF CUTTINGS I RUBBER I MISC. MUIRIH WI JARS, 27/8" MOTOR & 3.7" FIVE BLADE JUNK MILL. MILL FROM 9175' - 9212' WI FLOPRO SWEEPS. MILLING IN PROGRESS. 04/16/05 MILLING WI JARS/2 7/8" MOTOR & 3.7" FIVE BLADE JUNK MILL FROM 9212' - 9500', WI FREQUENT FLOPRO SWEEPS. PUMP FINAL 20 BBL FLOPRO SWEEP FROM 9500' AND CHASE OUT TO SURFACE. ACIDIZE WITH 100 BBLS DAD ACID AND 25 BBLS OF MUD ACID. DISPLACE WITH 150 BBLS OF 3% NH4CL. INITIAL INJECTION RATE = 1.3 BPM AT 3700 PSI, 1700 PSI WHP. FINAL INJECTION RATE = 2.4 BPM AT 3450 PSI, 320 PSI WHP. (OR 1.3 BPM AT 1000 PSI, 95 PSI WHP). RDMO. TURN WELL OVER TO DSO TO POI. TREE = cr# 4-1/16 5M WELLHEAD :fMC NSBB 5M ') DRAFT BY TLH A CTUA TOR = KB. ELEV = BF. ELEV = ~---...........__.- ,.- KOP= Max Angle = Datum MD = DatumlVD= AXELSON 54' -. 3888' 26 @ 7209' 9253' 8800' 'ss 113-3/8" CSG, 72#, N-80, 10 = 12.347" 1-1 2683' ~ Minimum ID = 3.725" @ 9021' 4-1/2" OTIS XN NIPPLE WI NO-GO 17" SCAB LNR, 26#, L-80, ID = 6.276" 1-1 8672' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 8673' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.97" 1-1 8694' 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" 1-1 8961' I TOP OF 4-1/2" TBG-PC 1-1 8961' 14-1/2" TBG-~, 12.6#, MN~80, .0152 bpf, 10 = 3.958" J-i 9037' 1 ÆRFORA TION SUMMARY REF LOG: BHCS on 01/11/78 ANGLE AT TOP ÆRF: 16 @ 9188' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 4 9188 - 9202 0 04/07/84 3-1/8" 4 9216 - 9250 0 04/07/84 3-1/8" 6 9275 - 9305 0 11/08/96 3-1/8" 4 9277 - 9317 0 02/14/78 3-1/8" 4 9329 - 9333 0 02/14/78 3-1/8" 4 9361 - 9373 0 02/14/78 3-1/8" 4 9424 - 9454 0 02/20/84 I PBTD 1-1 9612' 19-5/8" CSG, 47#, N-80, 10 = 8.681" 1-1 9662' ~-i 9685' DA TE REV BY COMMS\JTS 01/19/78 ORIGINAL COMPLETION 05/31/86 LAST WORKOVER 04/03/05 ??1 ITLH RWO DA TE REV BY 09-20 I . i ~ ~ I I I I -I I . ~ ~ ) SAfET) Ñ~i:~IPE. APR 2 2 2.005 2035' A,~d.-Ð'Ø"&EtSìa6 t&Q116-,=~~'91i,sion Anchorage 2478' 1-19-5/8" x T' BKR ZXP LNR TOP PKR, ID = 6.29" 1 2496' 1-19-5/8" x 7" BKR FLEXLOCK LNR HNR, 10 = 6.32" 8498' 1-14-1/2"HESXNIP, 10=3.813" 1 8563' 1-17" x 4-1/2" BKR S-3 PKR, 10 = 3.875" 1 8586' 1-14-1/2" HES X NIP, 10 = 3.813" 1 8651' 1-14-1/2" HES XN NIP, 10 = 3.725" 1 8672' 1-i4-1/2" WLEG, 10 = 4.000" 1 8672' - 7" X 4-1/2" PORTED SUB XO, 10 = 3.960" 8694' .. I _ 5~1'ï2" 'X4-1/~t )(0, ID ~·5.53;; 1 8705' 1-19-5/8" X 5-1/2" UNIQUE MACHINE OVERSHOT 8800' 1-1 ESTIMA TED TOP OF CEMS\JT 1 8920'-8925'I-1TUBING PUNCH SET 10/22/03 1 I 8932' 1-15-1/2" BAKERPBRASSY 1 8949' 1-19-5/8" X 5-1/2" BAKER SAB PKR I \ I 8961' 1-15-1/2" x 4-1/2" XO 1 I . 9021' 1-14-1/2" OTIS XN NIP, 10 = 3.725" 1 9037' l-i ELMO TT NO WLEG 1 J: I ~ I JI. I .- .. :- I - ., COMMENTS I -9274' 1-1 FISH - HALF RUBBER ELEMENT FROM WF IBP 9567' l-i FISH - 40' X 4-1/2" TUBING TAIL (06/02/86) 1 PRUDHOE BA Y UNIT WELL: 09-20 ÆRMIT No: '1770410 API No: 50-029-20261-00 SEC 10, T10N, R15E, 3655.56' FEL & 1367.6' FNL BP Exploration (Alaska) ,. ) ~'A" ~i [Æ"'A'. ,(fù,: i,n,l7~' m,'A.", 'lJ' i IY \\ ~[ /Æ'ß\ "I L i :~"~ :rÌJ) : iI' '-, ,a! ", I ,,~U'~ ~~'l" . ) /'77 ~D cf( "~r,l fM,/A'1í¡~ i1]:,lfE Œ) ulJ4Jw lb !\0U AItASIiA OIL AND GAS CONSERVATION COltDlISSION .f I / .7 l ,1 I FRANK H. MURKOWSK/, GOVERNOR 333 w. ¡rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 09-20 Sundry Number: 305-059 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours 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 unless rehearing has been requested. DATED this 1:: day of March, 2005 Encl. SCANNED MAR 1 () 20D5 1. Type of Request: 0 Abandon a Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well LJ?^ J' \¡.J GA- 5 !,-Š (1-005 ) STATE OF ALASKA .J'~-}s RI:Cf:IVeD ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 03 2005 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & G.as Cons. Commission Anchor9 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: 5. Permit To Drill Number 177-041 / 0 Development 0 Exploratory / 0 Stratigraphic IBI Service 6. API Number: / 50- 029-20261-00-00 54' 9. Well Name and Number: PBU 09-20 /' 8. Property Designation: 11. Total Depth MD (ft): 9685 Casing Structural Conductor Surface Intermediate Production Liner 10, Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENTWELL.CONDITI0NSUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9271 9612 9201 None Length Size MD TVD Burst ADL 028327 Junk (measured): 9274 Collapse 101' 2683' 20" 13-3/8" 101' 2683' 101' 2683' 1530 5380 .520 , 2670 9662' 9-5/8" 9662' 9249' 6870 4760 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 9188' - 9454' 8792' - 9048' 5-1/2", 17# x 4-1/21', 12.6 Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer; 5-1/2" Cameo Bal-O SSSV Nipple Tubing Grade: L-80 & MN-80 Packers and SSSV MD (ft): 8949' 2340' Tubing MD (ft): 9037' 12. Attachments: IBI Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 16, 2005 0 Oil/, 0 Gas 16. Verbal Approval: Date: IBI WAG 0 GINJ Commission Representative: 17. I hereby certi~1h1at the foregoing is true and correct to the best of my knowledge. Printed Nam\ ?aVid.Rer /í 0- Title Drilling Engineer Signature ,/ 'j{¡"1...}7.,(.t/ L,/ f'..-(!..J¿I-n.,.. Phone 564-5743 Commission Use Only 13. Well Class after proposed work: 0 Exploratory 0 Development IBI Service 0 Plugged DWINJ 0 Abandoned 0 WDSPL Contact Nick Miller, 564-4746 Date 3/3/05 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance I Sundry Number: 30S-:"'06f Other: Te.;f ßO P [ V, 4'-100 f ~/ " Approved By: I ( Form 1 0-403 Revi~O~ '-- RBOMS 8FL MAR 0 8 Z005 COMMISSIONER APPROVED BY THE COMMISSION Date t!i!:e OR\G\NAL ) ) 09-20i WO Procedure Problem: Well has IA x OA communication due to production casing leak at 3400'./ 1. Set 4.5" Fas Drill bridge plug in the packer tailpipe at 8976'. (Pre-Rig) 2. Punch holes in tubing with E-line from 8651' to 8653'. E-line chemical cut tubing at 8716'. (Pre-Rig) 3. Circulate the well to seawater with diesel freeze protect. (Pre-Rig) 4. MIRU Nabors 4ES. Circulate the well to warm seawater. ND tree (BPV installed and tested prior to rig up) and NU BOPE. Test BOPE to 250 psi (low pressure -' test) and 4000 psi (high pressure test) per BPI AOGCC regulations. /' 5. Recover 5.5" tubing and control lines down to the cut at 8716'. 6. Run 7" 26# fully cemented scab liner from 2480' to 8720'. Pressure test existing // 9-5/8" casing and new 7" scab liner to 3500 psi. 7. RU!l4-1/2" 12.60# L-80 completion and set permanent production packer at 8~~9' . Pressure test IA and tubing to 3500 psi. 8. 9. Set BPV in tubing hanger and test. ND BOPE. NU and test tree to 5000 psi. ,// 10. RDMO. TREE = FMC GEN 1 WELLHEAD = ~. FMC ÃCfUATÕR = ' AXELS()Ñ~' ï<B.'aéj; ,.... """"5'4;'1 BF:aèj; , '" KÖÞ';' " '3888í Max'ÄnQie ~"'26'@'72Ö9i 'òàìùm MD';"" "9253' Datùm wo";';"" 8800' SS ') l13-3/8" CSG, 72#, N-80, 10 = 12,347" 1-; 2683' Minimum ID = 3.725" @ 9021' 4-1/2.' OTIS XN NIPPLE WI NO-GO I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" 1-; 8961' TOPOF 4-1/2" TBG-PC 1-; 8961' 14-1/2" TBG-PC, 12.6#, MN-80, .0152 bpf, 10 = 3.958" 1-; 9037' PERFORA TION SUMMARY REF LOG: BHCS on 01/11/78 ANGLEATTOPPERF: 16 @ 9188' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9188 - 9202 0 04/07/84 3-1/8" 4 9216-9250 0 04/07/84 3-1/8" 6 9275 - 9305 0 11/08/96 3-1/8" 4 9277 - 9317 0 02/14/78 3-1/8" 4 9329 - 9333 0 02/14/78 3-1/8" 4 9361 - 9373 0 02/14/78 3-1/8" 4 9424 - 9454 0 02/20/84 I PBTD 1-; 9612' I 9-5/8" CSG, 47#, N-80, 10 = 8.681" I.., 9662' ~.., 9685' DATE 01/19/78 05/31/86 09/22/01 08/22/03 1 0/22/03 12/04/03 REV BY COMMENTS DA TE ORIGINAL COMPLETION 01/21/04 LAST WORKOV ER 06/05/04 RNlKAK CORRECTIONS 07/12/04 BJfvVKK SET BKR IBP . 02/1 0/05 JAF/TLP TOC/TBG PUNCH/FAST DRL/IBP JLA/TLP PRODUCTION CSG LEA K 09-20 8 ~ ~ [}-l \ / I r 1: I ~ . I REV BY COMMENTS SRB/KK PULL FAST DRILL BP LDK/KK SET IBP JLJ/KAK FISH JLrvVTLH IBP PULLED 07/12/04 SAFE. ,'ìOTES: NO WLEG ON TAILPIPE. 2340' 1-;5-1/2" CAMCO BAL-O SSSV NIP, 10 = 4.562" 1 3400' 1-; PRODUCTION CSG LEAK - 12/04/03 I 8800' 1-; ESTIMA TED TOP OF CEMENT 1 I 8920'-8925'1-1 TUBING PUNCH SET 10/22/03 1 8932' 1-;5-1/2" BAKER PBR ASSY 1 8949' 1-;9-5/8" X 5-1/2" BAKERSAB PKR 1 8961' 1-; 5-1/2" X 4-1/2" XO 1 9021' 1-;4-1/2" OTIS XN NIP, 10 = 3.725" 1 9037' 1-; ELMO TT NO WLEG 1 I -9274' 1-; FISH - HALF RUBBER ELEMENT FROM WF IBP 9567' 1-; FISH - 40' X 4-1/2" TUBING TAIL (06/02/86) 1 PRUDHOE BAY UNrr WELL: 09-20 ÆRMrr No: 1770410 API No: 50-029-20261-00 SEC 10, T10N, R15E, 3655.56' FEL & 1367,6' FNL BP Exploration (Alaska) TREE = FMC GEN 1 WELLHEAO = ~ FMC ACTlJA TOR = AXELSON Ki3.ËiE\ï;" """, "'54; BF. ELEV = KOP= " .. ......... Max Angle = " Datum MD = ... ....".................."....". Datum TVD = ) -) 09-20i Proposed Schematic 3888' , 26 @ !.209' 9253' '''..,..",.... ........ 8800' SS 113-3/8" CSG, 72#, N-80, 10 = 12,347" 1-1 2683' 7" 26# Scab Liner to 8691' 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4,892" 1-1 8961' hop OF 4-1/2" TBG-PC 1-1 8961' 8 L.J . . g -7" 26# Scab, TOL at 2480' 2000' 1"4-1/2" 'X NppIe, ID= 3.813" ~ 14-1/2' 12.60# L-80 Tubing, ID= 3.958" I I 8610' 1----14-1/2" 'X' Nipple, ID= 3.813" I I 8630' 1----i7" x 4-112" Baker S-3 Packer 1 /' 8655' 14-112" 'X' Nipple, 10 = 3,813" I I 8675' H4-1/2" 'x N' Nipple, 10 = 3,725" 1 I 8716' 1-19-5/8 X 5-1/2 Unique Overshot 1 ,.--" I 8920'-8925' I-iTUBING PUNCH SET 10/22/03 1 I 8932' 1-i5-1I2" BAKER PBR ASSY 1 1 8949' 1-19-5/8" X 5-112" BA KER SA B PKR I \ ! 8961' 1-15-1/2" x 4-1/2" XO I 9021' 1-14-1/2" OTIS XN NIP, 10 = 3,725" 1 I I 9037' 1-1 ELMO TT NO WLEG 1 14-1/2" TBG-PC, 12,6#, MN-80, ,0152 bpf, ID = 3,958" 1-1 9037" DATE 01/19"8 05/31186 09/22/01 08/22/03 10/22/03 1 2/04/03 ÆRFORATION SUMMARY REF LOG: BHCS on 01/11/78 ANGLEAT TOP ÆRF: 16 @ 9188' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9188 - 9202 0 04/07/84 3-118" 4 9216 - 9250 0 04/07/84 3-1/8" 6 9275 - 9305 0 11/08/96 3-1/8" 4 9277 - 9317 0 02/14/78 3-1/8" 4 9329 - 9333 0 02/14/78 3-1/8" 4 9361 - 9373 0 02/14/78 3-118" 4 9424 - 9454 0 02/20/84 IPBTO 1-1 9612' 19-518" CSG, 47#, N-80. 10 = 8,681" 1-1 9662' ~-I 9685' COMMENTS DATE ORIGINAL COM PLErION 01121104 LAST WORKOVER 06/05/04 RN/KAK CORRECTIONS 07/12/04 BJMlKK SET BKR IBP 02/10/05 JAF/TLP TOCITBG PUNCH/FAST DRLlIBP JLA/TLP PRODUCTION CSG LEAK REV BY ~ . I: I I -9274' I-IFISH - HALF RUBBER ELEMENT FROM WF IBP 9567' I-IFISH - 40' X 4-1/2" TUBING TAIL (06/02/86) 1 REV BY COMMENTS SRBlKK PULL FAST DRILL BP LDKlKK SET IBP JLJ/KAK FISH JLMlTLH IBP PULLED 07/12/04 PRUDHOE SA Y UNIT WELL: 09-20 ÆRMIT No: 1770410 API No: 50-029-20261-00 SEC 10, T10N, R15E, 3655.56' FEL & 1367.6' FNL BP Exploration (Alas ka) Re: 09-20i RWO ) ) <willton--aubert@âdinin.state.,ù<.us::> Winton, be sure to cc Jody or print a copy of this and give it to her so she can get it in the proper file, unless you have already done so. Merci beaucoup. Winton Aubert wrote: Brian, Upon your request via Form 10-403, the Commission will approve a variance from 20 AAC 25.412 (b), for well PBU 09-20i as described below. Please contact me if you have further discussion. Winton Aubert AOGCC 793-1231 Carlson, Brian H wrote: Winton, As mentioned on the telephone, we would like to do a RWO on Prudhoe 09-20i, but the proposed packer depth is higher than normal. History Well had packer leak, so packer squeeze done 10/27/03. 10/27/03 failed MITIA post packer squeeze due to PC leak at 3400' (Identified on LDL 11/26/03) Proposed RWO Cut and pull existing 5-1/2" above packer squeeze cement top (-8800') Run 7" scab liner and tie from cement top (-8800'MD) to 2400'MD and cement interval. Run 4-1/2" tubing with packer at 8750' MD, with 4-1/2" flush joint tubing down through remaining 5-1/2" tubing. Well Depths Estimated New Packer: 8367'55 (8750'MD) Estimated Cement Top: 8319'55 (8800'MD) Existing Packer: 8509'55 (8949'MD) Zone 4 Top: 8701' (9150'MD) Perforation Top: 8738' (9188'MD) SCANNED! j¡~N () 7 2DD5 Please let me know if you require any further information to determine whether the proposed RWO plan is appropriate. Attached is a schematic for the existing well. «09-20.pdf» Thanks, 1 of2 1/5/2005 2: 11 PM Re: 09-20i RWO ) ) .. Brian Brian H Carlson D5 3/9/14 Production Engineer Prudhoe Bay Waterflood Phone (907)564-5046 Fax (907) 564-5016 John K. Norman <John Normancmadmin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 2of2 1/5/2005 2: 11 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D 2. Operator Suspend D Repair WellŒJ Pull Tubing D Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate D WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 177-0410 OtherD Name: BP Exploration (Alaska), Inc. 54.00 8. Property Designation: ADL-0028327 11. Present Well Condition Summary: Development D Stratigraphic D 9. Well Name and Number: 09-20 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service ŒJ 6. API Number 50-029-20261-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 9685 feet true vertical 9271.1 feet Plugs (measured) Junk (measured) None Effective Depth measured 9612 feet true vertical 9200.6 feet 9567 Casing Length Size MD TVD Burst Collapse Conductor 84 20" 94# H-40 31 115 31.0 115.0 1530 520 Production 9633 9-5/8" 47# N-80 29 - 9662 29.0 - 9248.9 6870 4760 Surface 2653 13-3/8" 72# N-80 30 - 2683 30.0 - 2682.9 4930 2670 Perforation depth: Measured depth: 9188 - 9202,9216 - 9250,9275 - 9277,9277 - 9305, 9305 - 9317,9329 - 9333, 9361 - 9373,9424 - 9454 True vertical depth: 8791.95 -,8818.86 - 8805.4,8875.58 - 8851.54,8877.5 - 8877.5,8904.44 - 8904.44, ~7~C"'ft~1,5.¥~ ~~~'r'Z"f~ 8931.4 9019.11 - 8969.94 ì''' r:: ' t: ~ V t",:., ~i,,",ß Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 27 8961 4-1/2" 12.6# MN-80 @ 8961 9037 Packers & SSSV (type & measured depth): 4-1/2" Baker SAB Perm Packer @ 8949 FEB 2 4 2004 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8800 - 8949 Treatment descriptions including volumes used and final pressure: 10.5 Bbls 15.8 ppg cement @ 1060 psig Representative Dailv Averaae Production or Iniection Data Ala~ka Oil & Gas Cons. Comr~~iss¡on m::horâQ~ 13 Prior to well operation: Subsequent to operation: Oil-Bbl I Gas-Met Water-Bbl Casing Pressure Tubing Pressure 0 I 0 11310 50 1455 Well Shut-in 315 1617 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG D GINJD WINJI:&] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact' ""'-'~àrryCåtron Printed Name Garry Catron Signature Title Production Technical Assistant Phone 564-4657 Date 2/18/04 '(I ~ 200tf nD'~1t\'^' Form 10-404 Revised 12/2003 IIIIIIBfL mJ 2; . 09-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/22/03 MU MHA w/pump through swivel, 5' of 1.56" OD 4 SPF highside oriented tubing puncher guns w/bow spring centralizer. RIH punched tubing holes at 4 spf from 8920. - 8925' w/500 psi on tubing to offset IA hydrostatic. Guns fired, broke circulation by pumping down tubing and taking returns from IA. POOH ASF. Roll tubing and IA over to crude. RIH, tag BP and set 10.5 bbls balanced cement plug in tubing and IA. Estimated TOC - 88001. POOH. Trap 240 psi on tubing. lAP = 315 psi. Well freeze protected to 2500'. Notify DSO of well status. 10/24/03 T/I/0=SI/100NAC. IA Fl @ SURFACE (PREP FOR MITIA FB). 10/25/03 WEll SHUT IN PRIOR TO ARRIVAL RUN 3.5" CENT & SAMPLE BAilER TO 8750'SlM - POOR SAMPLE - GREEN CEMENT. RUN 2.25 CENT & SAMPLE BAilER TO 8766'SlM - EST TOP WAS 8800' SAMPLE OF CEMENT. TURN WEll OVER TO DSO - WEll lEFT SHUT IN. 10/27/03 Mill CEMENT PlUG/ MIT-IA, CTU #5, uMIRU, MIT-IA TO 3000 PSI, GOT llR OF 1 BPM @ 890 PSI. PRESSURE UP TUBING TO 1470 PSI. lOST 30 PSI IN 3 MINUTES, NO RETURNS FROM IA. RIH WITH 3.70" MilL. INITIAL TAG AT 8763' CTD. Mill OUT CMT TO ABOUT THE 5.5" X 4.5" TBG TAil XO 8954' CTMD. «ESTIMATE -5'-10' CMT lEFT ON TOP OF THE BP» --CONTINUED ON 1 0/27/03 WSR-- 10/27/03 T/I/O= SI/100NAC. TEMP=COlD/SI. IA Fl @ SURFACE. FOR CTU. 10/28/03 CTU #5. Mill CMT POST PKR SQZ. --CONTINUED-- JET CMT CUTTINGS TO SURFACE AT 80%. ATTEMPT TO PRESSURE UP ON THE TBG. PUMPED 11 BBl'S. START WHP=580/IAP=170 TBG PRESSURE FEll OFF TO 140 PSI IN 2 MINUTES. APPEARS WE MAY HAVE KNOCKED THE TOP OFF THE BP SO IT IS EQUALIZED. --JOB COMPlETE-- RIG DOWN. WEll FREEZE PROTECTED TO 2500' W/60/40 METHANOL. 11/26/03 lEAK DETECTION lOG. lOGGED BASELINE DOWN PASS AT 120 FPM, WEll SHUT-IN. lOGGED DOWN PUMPING PASS AT 120 FPM, 36 BBlS AWAY DOWN IA AT START. lOGGED UP PUMPING PASS AT 120 FPM, 123 BBlS AWAY AT START. All PUMPING PASSES lOGGED AT 1 BPM AND 1800 PSI. FOUND PROBABLE CASING lEAK AROUND 3400'. All TEMP CURVES OVERLAY BELOW 3500'. TAGGED TT PLUG AT 8959'. DEPTH REFERENCED TO TUBING TAllY AT SSSV. PAD OPERATOR NOTIFIED WEll lEFT SHUT-IN. lEAK DETECTION lOG. lOGGED BASELINE DOWN PASS AT 120 FPM, WELL SHUT-IN. lOGGED DOWN PUMPING PASS AT 120 FPM, 36 BBlS AWAY DOWN IA AT START. lOGGED UP PUMPING PASS AT 120 FPM, 123 BBlS AWAY AT START. All PUMPING PASSES lOGGED AT 1 BPM AND 1800 PSI. FOUND PROBABLE CASING lEAK AROUND 34001. All TEMP CURVES OVERLAY BELOW 3500'. TAGGED TT PLUG AT 89591. DEPTH REFERENCED TO TUBING TAllY AT SSSV. PAD OPERATOR NOTIFIED WEll lEFT SHUT-IN. Page 1 09-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/26/03 T/I/O=VAC/26010. TEMP=SI. LNFT-IA PASSEDI CIT-OA PASSED (EVAL FOR PC WAIVER). IA FL @ SURFACE. OA FL @ 20'. BLEED IA FOR LNFT. BLED IA FROM 260 PSI TO 0+ PSI IN 1.25 HRS. START LNFT-IA. OPEN BLEED TO CALIBRATED BUCKET FOR 10 MIN RETURNING .25 GALS. MONITOR FOR 30 MIN. OAP REMAINED @ 0+. T/I/O=VAC/O+IO. START CIT-OA. PRESSURE OAP TO 2400 PSI WITH 3.5 BBLS OF DIESEL. OAP LOST 200 PSI IN 10 MIN FROM 2400 PSI TO 2200 PSI. RE-PRESSURE OAP TO 2400 PSI. OAP LOST 200 PSI IN 10 MIN. RE-PRESSURE OAP TO 2400 PSI. OAP LOST 200 PSI IN 10 MIN. RE-PRESSURE TO 2400 PSI. OAP LOST 200 PSI IN 10 MIN. BLED OAP TO 0+ PSI. FINAL WHP'S=V AC/O+IO+. 12/27103 T/I/O=VAC/30NAC. TEMP=SI. MONITOR WHP'S (POST CITOA I LNFT-IA). lAP INCREASED 30 PSI, OAP WENT FROM 0+ TO A VAC OVERNIGHT. 01/21/04 MILL PLUG, CTU #4; CONI' FROM WSR 1/20104... STAND-BY FOR SUPPORT EQUIPMENT RIG UP. MIRU DS CTU #4. RIH WITH WFD 3. 625" SIX BLADE JUNK MILL. MILL PLUG OUT AND TAG HARD AT 93601 CTMD. PERFORM INJECTIVITYTEST, 4 BPM @ 1075 PSI. FREEZE PROTECT TUBING TO 2500'. POOH AND RIG DOWN. LEFT WELL SHUT IN. «< JOB COMPLETE.»» FLUIDS PUMPED BBLS 341 Methonal 694 Crude 23 Fresh Water 10.5 Cement 1222 1% X-slk 63 Biozan 10 Flo Pro 2363.5 TOTAL Page 2 lREE= FMC GEN 1 WELLHEAD = FMC ACTIJATOR= AXELSON KB. ELEV = 54' BF. ELEV = KOP= 3888' tv1ax Angle = 26 @ 7209' Datum M) = 9253' Datum lVD = 8800' SS 09-20 I SAFETY NOTES: NO WLEG ON TAILPIPE. (f) 2340' 5-1/2" CAMCO BAL-O SSSV NIP, ID= 4.562" 13-3/8" CSG, 72#, N-80, ID = 12.347" ffiODUcrlON CSG LEA K - 12/04/03 Minimu m ID = 3.725" @ 9021' 4-112" OTIS XN NIPPLE WI NO-GO 8800' -lESllMAT8) TOP OF CEtvENT I 5-1/2" TBG-FÇ, 17#, L-80, .0232 bpf, ID = 4.892" 1 TOP OF 4-1/2" 1BG-PC I 9-5/8" X 5-1/2" BAKER SA B PKR -14-1/2" OTISXNNIP, ID= 3.725" I 14-1/2" TBG-PC, 12.6#, MN-80, ,0152 bpf, ID = 3.958" I 9037' I3.JIIÐ TT NO WLEG PERFORATION SUMMA RY REF LOG: BHCS on 01/11/78 A NGLE AT TOP ÆRF: 16 @ 9188' I\bte: Refer to A"oduction DB for historical perf data SIZE SPF INTER\! AL Opn/SQZ DATE 3-1/8" 4 9188 - 9202 0 04/07/84 3-1/8" 4 9216 - 9250 0 04/07/84 3-1/8" 6 9275 - 9305 0 11/08/96 3-1/8" 4 9277 - 9317 0 02/14f78 3-1/8" 4 9329 - 9333 0 02/14f78 3-1/8" 4 9361 - 9373 0 02/14f78 3-1/8" 4 9424 - 9454 0 02/20/84 9612' FISH - 40' X 4-1/2" TLEING TA IL (06/02/86) [§ê] 19-5/8" CSG, 47#, N-80, ID = 8.681" I DATE REV BY OOMMß\JTS DA1E REV BY COMMENTS 01/19/78 ORIGINAL COM PLETION 01/21/04 SRBIKK PLl. L FA ST DRILL BP 05/31/86 LAST WORKOV ER 09/22/01 RN'KAK CORRECTONS 08/22/03 BJM/KK SETBKR IBP 10/22/03 JA F/TLP TOC'TBG RJNCH/FAST DRUIBP 12/04/03 JLA/TLP PRODLCTON CSG LEAK PRLDl-úE BA Y UNIT WELL: 09-20 PERMrr No: 1770410 AR No: 50-029-20261-00 SEC 1 0, T10N, R15E, 3655.56' FEL & 1367.6' FNL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well 1-01/J-19 \ ?So -0 ~ ..,.... U-02A q "'3 .;:;¿"2.. ~ D.S.09-20 of -Ol..j " W-17 XS?-- ~~ ~ G-15A c '<; .- :2. ,J...1 01-33 <"1 - J;!.. ;::J. D.S. 2-24 <; \" r"r- Q-07A ì '-("Y')...~ MPS-26 ;::)ë' ~ ... f) tQ \ MPK-21A n~n-~"" I () ~ MPS-16 :ç¿lr)~ -nlcÞJ - Job # 10662975 10708038 10674403 10621748 10564495 10568434 10560320 10572013 10563066 10621740 10563067 Log Description Date LDL LDL PSP LDL TEMPERATURE PROFILE RST -SIGMA RST -SIGMA SCMT SCMT SCMT USIT SCMT 12/04/03 12/09/07 11/26/03 11/28/03 07/11/03 04/15/03 11/10/03 04/21/03 05/30/03 11/01/03 05/31/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: --- ~ ~ ~.-" -. -X"""'C'\ \J ;.., ..\.....- '- '-- ç'): ~~ "'^ - , , , ~(;AIJ\~NE[,':' DEC 3 @ 2003 Blueline NO. 3068 Company: 12/11/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 1 1 1 1 1 1 Color Prints ( CD 1 1 I ):J ~ ~/ <...¡ J~ ~ êL) 2 2 2 2 2 J Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 R'I,L- .'" ~i!\ ¡'ED ATTN: Beth :i.,,- f '> ~-- ~ Y: : ¡¡ , "1¡, ~- \.,J'L- j . ~ Received by: D E r:: l2-2O.O ~ Ala3k~ OI¡ (\ Gas C~r.s. Commisoo:m !;(çhC1rt~ge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / Drill Site 09 06/06/O3 John Cubbon Chuck Scheve Well[09-08 P.T.D. I 1760700 Notes: Well109-10 P.T.D.I i 760820 Notes: Well109-20 P.T.D,I 1770410 Packer Depths (ff.) I Type test I P I Test psiI 21031 Pretest Initial 15 Min. 30 Min. casin~l 3001 24401 24201 24201 P/FI I Type testl P I Test psil 20831 I CasincjI 1001 24601 24501 24501 P/"FI P I I Type,nJ.I s I~,~1 ~'"""'1 8'5631 Tubingl 1150[ 1150[ 1150[ 1150[ Interva~ 4 I Typetest~ P I Testpsil 2141l I Casin~ll 360l 23001 3801 I P/FI F Notes'. LLR of 0.8 BPM at 2300 psi. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: Test Details: Tests were 4 year MITIA's for UIC compliance. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test dudng Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 AUG 0 4 2003 2003-0606_MIT_PBU_09-08_10_20.xls FYI: MITIA Forms Subject: FYI: MITIA Forms Date: Thu, 12 Jun 2003 22:19:39 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> To: "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us> CC: "Rossberg, R Steven" <RossbeRS~BP.com>, "Engel, Harry R" <EngelHR@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com> Hello all. Attached are several MIT reports for recent 4-year MIT's conducted on injectors. All passed except 09-20, currently under evaluation. Note we've had email problems recently, some of these may have already been sent. Let me know if you have any questions. <<MIT PBU 01-11 06-12-03.xls>> <<MIT PBU 13-19 06-12-03.xls>> 14-27 06-12-03.xls>> <<MIT PBU 09-08,10,20 06-06-03.xls>> Joe Anders, P.E. / John Cubbon Well Integrity Engineer, BP Exploration, Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com (Alaska) Inc. <<MIT PBU [-~MIT PBU 01-11 06-12-03.xls Name: MIT PBU 01-11 06-12-03.xls '1 Type: Microsoft Excel Worksheet (application/vnd.ms-excel) I ~_)MIT PBU 13-19 06-12-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel)i ~-)MIT PBU 14-27 06-12-03.xlst Type: Microsoft Excel Worksheet (application/vnd.ms-excel)l · ]Encoding' base64 '[ Name: MIT PBU 09-08,10,20 06-06-03.xls I-)MIT PBU 09-08,10,20 06-06-03.xls] Type: Microsoft(application/vnd.ms_excel)EXcel Worksheet tEncoding: base64 1 of 1 6/25/2003 3:10 ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: FROM: P.I. Supervisor DATE: June 6, 2003 SUBJECT: Mechanical Integrity Test BPX DS 9 PBU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL P.T.D. ] 176-070 Notes: P.T.D.I 176-082 Notes: WellI 9-20 P.T.D. I 177-041 Notes: P.T.D.I Notes: P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. · ~e,~i.I ~ I*'v'~- I~4~ I~'~ I~° I~° I~° I~° Type test I ~ I lestpsil 2~0a ICasin~I 300 I 2~0 I 2420 I 2420 I ~ I*'v'~' I~ ITMI~°° I~°° I~°° I~°° Typelnj'IP ITestpsil 2083 I Casingl 100 I 2460 I 2450 I 2450 I Type test Typelnj'I P ITestpsil 2141 I Casingl 360 I 2300 I 380 I I P/FI FI Type test _ I IType I nj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G -- GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs DS9 and witnessed the routine 4 year MIT on wells 9-08, 9-10 and 9-20. The pretest tubing and casing pressures were observed and found to be stable. The pressure tests were then performed with the wells 9-08 and 9. 10 demonstrating good mechanical integrity. Well 9-20 failed to pressure test and has an apparent casing leak. An injection rate of.8 bbl per minute was established at 2300 psi. The tubing and outer annulus pressures remained stable at 1150 psi and 10 psi throughout the test. When the pump was shut down the IA pressure fell rapidly back to 380 psi. The condition of this well was discussed with Jim Regg and it was allowed to remain on water injection pending farther diagnostics. ~o~.~ M.I.T.'s performed: _3 Number of Failures: 1 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0606_M IT_ PBU_09-20_cs.xls 6124/2003 09-20~Verbal Notification Subject: 09-20 Verbal Notification Date: Mon, 28 Dec 1998 10:57:21 -1000 From: "PRB Problem Wells" <P 1041 @mail.aai.arco.com> To: B lair_Wondzell~admin, state.ak.us Blair, following is the current status of 9-20: a. T x IA and IA x OA Pack-offs passed Positive Pack-off tests <12-21-98> post-Sealtite Treatments Note: Seal-tire Representative was flown up to Prudhoe in early December from Louisiana to treat Pack-offs on 9 wellheads. b. MITIA (ARCO in-house) Passed 12-24-98 to 3000#. In summary, the initial Tbg Pressure= 0#, IA=3000#. !5 minute readings were Tbg=0, IA= 2910 (90# drop), 30 minute pressures were Tbg=0, IA= 2860# (total drop 140#). c. Combo MIT- T x IA and MIT-T Passed (ARCO in-house) 10-14-98 with TTP in hole. Plug is still in hole. d. Verbal (attached below) from 8-18-97 states "an MITIA failed, T x IA Comm exists, and well has been restricted to WI since '95" (See attached file: 09-20 Verbal 08-18-97.doc) PLAN 1. Re-install injection line spool (by Drill Site Maint) 2. Verbal to State with intent to re-start PWI (by Prob Well Specialist) 3. State Witnessed MITIA, if required by State (by Downhole Diagnostic ~ Crew). Last State witnessed MITIA was 7-2-96. 4. Wireline to pull Tbg Tail Plug. ~ 5. Drill-site Operator bring Back-on-line on Produced Water Injection ~ (only) FUTURE PLAN 6. Drill-site Engineer; determine if MI is warranted 7. DSE/PWS submit Sundry to State for MI re-start 9. Drill-site Maint; prep work for Back-on-line At this time we are only interested in the PLAN steps #1 through #5. ACTION: Please let me know what the "AOGCC RESPONSE" is to our Plan. Cheers, and Happy Holidays, S Schudel Name: 09-20 Verbal 08-18-97.doc Type: Winword File (application/msword) [-)09-20 Verbal 08-18-97.doc Encoding: base64 Description: Word 6.0 Windows/Mac 1 of 1 12/28/98 11:22 AM Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2781 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk 05/13/03 Color Well Job # Log Description Date Blueline Prints CD NK-14 ~ C{ tp' O(~ SBHP SURVEY 04/20/03 1 NK-08A ~-O ~ .O?..ci SBHP, SURVEY 04/19/03 1 INK'20 I['c~'~ ~ i ~ ! SBHP SURVEY 04/20/03 1 NK-21 [C~,G~-~'~r'~3'~"'~ SBHP SURVEY 04/19/03 1 NK-07A ~ t. (~L,, '~ SBHP SURVEY 04/21/03 1 ~4-18/S-30 i~.~. it ~t PSP GLS 04/18/03 1 1-33B/L-24 .~t~5, ~55 LDL 04/19/03 3-45/M-29 i ~,'~ -©,~ J INJECTION PROFILE 03/27/03 1 .... D.S. 15-47 I c1~..5 ~t"l ~ LDL 03121/03 1 D.S. 17-11 ! 1~{..,~.L.~ GLS 04~27~03 D.S. 18-14A lqc"~. OO""~ LDL 04~03~03 D.S. 13-29L1 ~..O'~,C~ PRODUCTION PROFILE 04/06/03 1 D.S. 1'8-03A I.c~Z..~ -- ~.~ ~ LDL 03~27~03 1 D-05 ~-'tO, OO ~, PRODUCTION PROFILE 04/13/03 D.S. 9-20 %"]'"]. ~..~. [. INJECTION PROFILE 04/15/03 1 E-13A I ct '1, ~ ~ "Z.., SBHP SURVEY 04124/03 D.S. 1-28 J~ ' O~.~ CHFR 03/31103 1 D.S. 4-18 I~,~: ?~.~,~-----3 FLOWING BHP & TEMP 04/13/03 1 J-23 ~ ~ ~ · O ';~ -~ J LDL 04/25/03 1 N-20A [~ ~ i ~ ~- CHFR 04/10/03 1 D.S, 1-34 I ~(.~ "'l I ~-{' CHFR 03/29/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T,O: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Bivd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received by: ~ ~--~~ INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA IHJECTIOIV ORDER #4 DATE: 08/18/97 TIME: 9:00 A.M. NOTIFIED BY: Keith St. Gemme AOGCC CONTACT: REASON: Injection Well _09-20_ Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 Jack Hartz DISCUSSION: ~ Well 09-20 is a WAG injection well that has possible tubing X 9-5/8 communication. ~ The well failed an MITIA on 8/14/97 and a liquid leak of 1 GPM at 2500 psi was established. ~ The well is currently SI. ¥ The well has been restricted to water injection only since tubing X 9-5/8 communication through the SSSV control line was partially repaired in 4/95. PLAN OF ACTION: 1) Set tbg tail plug to secure wellbore. 2) Test integrity of tbg, inner, and outer annuli. 3) Run leak detect log to.identify tbg leak point(s) if warranted by MIT results. AOGCC RESPONSE: 1) Fax summary of verbal notification to AOGCC, Attn: Mr. Blair Wondzell 2) Proceed with plan of action. 3) Notify AOGCC when a remedial plan has been identified. Sundry Notice Req'd at this time? SIGNED: Problem Well Specialist YES tttt NO ttxtt Orig: Problem Well Specialist, Ortiz / Smith, PRB 24 cc: Wells Superintendent, Lemon, PRB 20 Area Operations Supervisor, Shoemake/Smart, PRB 20 Mike Bill, ATO 1528 FS 3 DS Supervisor, Blackburn / Shumway, PRB 13 FS Superintendent, Roach, PRB 15 Ted Cahalane, ATO 1586 09-20 Well File (Revised I0/30/92} t DATE: 8/14/97 ANNULAR COMMUNICATION TESTING MECHANICAL INTEGRITY TEST TYPE: MITIA to 2500 psi for De-watering. I I . '* II II II1'1~ I, I1,, ,HI ,1'-- . Well Status: TBG: CONTROL: INITIAL PRESSURE DATA INJ TYPE: 165O IA: 860 OA: BALANCE: 65o WELL: MIT: ... S~ g-20 PRE-TEST PREPARATIONS BLED IA OA FROM TYPE OF FLUID AND VOLUME BLED: PSI TO PSI HI:tS MIN IA / OA FL@ NS/SF TEST PRESSURES TIME TBG IA OA COMMENT~ 9:0'7 ,.1650 500 ' 650 START PUMPING TIME 9:15 1650 2500 800 START TEST 9:30 1650 2300 800 4 bbls .. 9:35 1650 2500 800 START TEST 0:50 1650 2300 800 10:00 1650 2500 800 START TEST 10:15 1650 2300 800 i0:30 1650 2100 800 TOTAL VOLUME PUMPED; 7 bbls of melhanol FINAL PRESSURES TBG: 1650 IA: 100 OA: 50o OBSERVATIONS / COMMENTS FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! - FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION -I" "'[-- -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING, - NOTIFY DRILl, SITE OPERATOR OF TE~iT RESULTS, VOLUME8 PUMPED AND STATUS~__ ~ELL. Witness- KLM/KDP STATE OF ALASKA ALASK,~ .... 'LAND GAS CONSERVATION C MISSION REPORT ,JF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 407' FSL, 274' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1245' FNL, 1583' FWL, Sec. 12, T10N, R15E, UM At effective depth 1362' FNL, 1621' FWL, Sec. 12, T10N, R15E, UM At total depth 1370' FNL, 1624' FWL, Sec. 12, T10N, R15E, UM Repair well Other 5. Type of Well Development Exploratory Stratigraphic Service OR!GI XAL 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-20i 9. Permit number/approval number 77-41 10. APl number 50 - 029-20261 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9685 feet 9271 feet Plugs(measured) PBTD Tagged @ 9349' MD (11/8/96) Effective depth: measured 9349 feet true vertical 8947 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 258 Sx AS II 101' 101' Surface 2629' 13-3/8" 4200 Sx Arctic Set 2683' 2683' Production 9608' 9-5/8" 1000 Sx Class G 9662' 9252' Perforation depth: measured 9188 - 9202'; 9216 - 9250'; 9275 - 9317'; 9329 - 9333'; 9361 - 9373'; 9424 - 9454' true vertical 8791 - 8805'; 8818 - 8851'; 8875 - 8916'; 8928 - 8932'; 8959 - 8970'; 9019 - 9048' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8961' MD; 4-1/2", 12.6~, MN-80, PCT @ 9010' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 8949' MD; Camco BaI-O SSSV @ 2340' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. RECEIVED DEC 0 4 1996 Representative Daily Average Produchon or Imectlon Data Anch0rag0 OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 21369 -- 1816 21560 -- 1715 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas.._. Suspended__ Service Injec'~r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_--~,~_ ~, ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 n~.' . IWP SUBMIT IN DUPLICATE 9-20i PEIRFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1 1 1819 6: MIRU & PT equipment. 30' of perforations as follows: Added perforations: 9275 - 9277' MD (Z2) Reperforated: RIH w/perforating gun & tagged PBTD at 9349' MD, then PU & shot Ref. Log: BHCS 1/11/78. 9277 - 9305' MD (Z2) Ref. Log: BHCS 1/11/78. Used 3-3/8" carriers & shot all perfs at 6 spf at 60 degree phasing at balanced pressures. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. RECEIVED GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9493 Company: 5/31/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk ,D.s. 2-19 ~l-, ~ ~'~,! DUAL BURST TDT-P .... 051695 I 1 D.S. 4-31 ~---0?'c// CNTG 051495 I 1 D.S. 5'25 ~c/'[31 PRODUCTION PROFILE 051795 1 1 D,S, 9'20. 7 ~ Y~ INJECTION pROFILE 051 495 1 1 D.S, 11 '29 ~- O$~-- DUAL BURST TDT-P 051595 1 1 .D...;.S. 18-10 ~,-! ~ iCHEMICAL CUTTER 051895 I 1 , ,,, ,,, SIGNED _ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Alaska Oil & Gas Cons. Commission Anchorage DATE: STATE OF ALASKA AL,~ ~ ' AND GAS CONSERVATION CC ~IlSSION REFer,, oF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 407' FSL, 274' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1245' FNL, 1583' FWL, Sec. 12, T10N, R15E, UM At effective depth 1362' FNL, 1621' FWL, Sec. 12, T10N, R15E, UM At total depth 1370' FNL, 1624' FWL, Sec. 12, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-20 9. Permit number/approval number 77-41 10. APl number 50 - 029-20261 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9685 feet 9271 feet Plugs(measured) PBTD @ 9324' MD (8/21/94) Effective depth: measured 9324 feet true vertical 8915 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 258 sx AS II 101' 101' Surface 2629' 13-3/8" 4200 sx Arctic Set 2683' 2683' Production 9608' 9-5/8" 1000 sx Class G 9662' 9252' Perforation depth: measured 9188-9202'; 9216-9250'; 9277-9317'; 9329-9333" 9361-9373'; 9424-9454' true vertical 8791-8805'; 8818-8851'; 8877-8916'; 8928-8932'; 8959-8970'; 9019-9048' Tubing (size, grade, and measured depth) 5-1/2", L-80, 17#, PCT @ 8961' MD; 4-1/2", MN-80, 12.6#, PCT @ 9010' MD Packers and SSSV (type and measured depth) Baker SAD pkr @ 8949' MD; Camco BaI-O SSSV @ 2340' MD 13. Stimulation or cement squeeze summary R Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 21207 48089 Tubing Pressure 1582 2898 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil Gas Suspended Service Injector 1 7. I here, by certify that the foregoing is true and correct to the best of my knowledge. Signed /,} , '~ Title Engineering Supervisor Form 10-4C~ Rev 06/15/88 ~/ I P4q/1R ~R.c:; c.c.' K7 .IWP SUBMIT IN DUPLICATE 9-20i DESCRIPTION OF WORK COMPLETED POLYMER & SURFACTANT INJECTION TREATMENT FOR MI DIVERSION 4/27/94: RIH & tagged PBTD at 9430' MD. 5/1 3/94: MIRU CTU & PT equipment. RIH w/CT to bottom, then PU & pumped gelled sand slurry containing 6850 lbs of 20/40 mesh sand, and 200 lbs 100 mesh sand, to isolate the open perforation intervals located at: 9277- 9317' MD (Z2) 9329 - 9333' MD (Z2) 9361 - 9373' MD (Z2) 9424- 9454' MD (Z2) Ref. Log: BHCS 1/11/78. Made a final top of sand plug tag at 9250' MD. POOH w/CT. Rigged down. 5/28/94: RIH & tagged top of sand plug at 9257' MD. the sand plug to 9255' MD. POOH w/bailer. Made bailer runs & dumped CaCO3 w/Soap to cap Rigged down. 6/23/94 - 8/7/94: An MI Foam Diversion Project to improve injection conformance was performed as follows: RIH & tagged top of sand plug at 9255' MD. Started pumping Polyethylene Oxide Polymer & Chevron Chaser Surfactant directly into the PWl flowline, to pass through the open perforation intervals located above the sand plug at: 9188 - 9202' MD (Z4) 9216 9250' MD (Z4/3) Ref. Log: BHCS 1/11/78. Injected continuously at 150 to 250 gallons per day of Polyox and 1000 to 1250 gallons per day of Surfactant, with the well on PWl injection at 5000 - 6000 BWPD (until 7/18/94), then continued w/chemicals injected at 140 to 180 gallons per day of Polyox and 640 to 1040 gallons per day of Surfactant, with the well on PWl injection at 2000 - 5000 BWPD until the treatment ended 8/7/94. 8/1 1/94: RIH & tagged top of sand plug at 9270' MD. 8/19/94 - 8/20/94: RIH w/CT & jetted sand plug from wellbore to 9346' MD, to uncover open perforations (above). 8/22/94: RIH w/CT & jetted fill from wellbore to hard bottom at 9346' MD. Placed the well on MI & obtained a valid gas injection rate. RECEIVED NOV-' '1 199q Aiaska Oil & Gas Cons, Commission Anch0r~ ,: ~uest r~X} W, international Airport Road Anchorage, Al( 99tS18-1199 ATTN: Shenie NO. 8931 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant t 3001 Porcupine Drive Anchorage, AK 99501 9/14/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1'-18 -"'(~"' ~.~c,~ PROD PROFILE (8-31-94) 1 1 D.S. 3-21 ~-~_~ "' I \.~" PROD LOG (8-27-94) 1 1 D.S. 9-20 MI INJEC PROFILE (8-28-94) 1 1 D.S. 11-23A . ~ / D.S. 11-23A I ~1 PERF RECORD (8-30-94) 1 1 ' JEWELRY LOG (18-28-94) 1 1 D.S. 14-37 ~0~ ~- I ~'~ PROD PROFILE (8-26-94) 1 . 1 D.S. 15-02 ~- ~-' PERF RECORD (8-29-94) 1 1 SlG Please sign and retum one cop of this transmittal to Sherrte at the above adding. Thank you. DATE: GeoQuest 500 W. International Airport Road Anchorage, AK 99618-1199 ATTN: Sherfle NO. 8945 Oompany: I Alaska 011 & Gc~ Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/21/94 Field: Prudhoe Bay Well / Log Description BL RR Sepia RF Sepia Mylar D.S.4-03' ~\ '~ J)g PROD LOG (9/4/94) 1 1 D.$.7-13 ~'c/C- ~ ' TUBGOUTREOORD(9/1/94) 1 1 D.S.9-20 '~"'7 ' ~/ I MI INJEOT PROFILE (9/5/94) 1 1 D.S. 13-33 ' ~"2---""' l(~ PROD PROFILE (9/3/94) 1 1 D.S. 14-5A c~'2...--(~ J iPROD PROFILE (9/1/94) .. 1 1 D.$. 14-24 ~' ~, ~-~ ! .. PROD PROFILE (9/3/94) 1 1 D.S. 16-31 ~'2~" '7,_~ PATOHSETREOORD(9/6/94) . 1 .1 .... , . sign and return on~ copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. P.O. Box 100360, Ar, chorage, AK 9-20 ~-\% ~- ~ 9-29 9c>_ \ \ \_ ~ 9-33 ~,-t~,t ..... £ 11-6 ~ 11- ~-~ -~ 16ST1 , ~~ - ~ 12-26 ~.%- u~, ~R 13-28 04-27-94 02-19-94 04-11-94 04-20-94 ! ~"lnject Profile i/" Vertilog ! ~"Perf Record I t 5ll 1~ 5I! 511 Sch Sch Sch i ~'Perf Record 1, 5" Sch , 04-15-94 i ....Leak Detect 1, 2"&5" Sch 04-26-94 I /Perf Record : 1 5" Sch , ~ Sch 04-t9-94 i /"Completion ~ i 14-09B Sch 4-09B 4-40 5-7A ~ 15-7A ..... ~' 15-32 -- ,,!. 16-18 18- 26ST1 i 18-27 05-01-94 ]/Injection Profile 04-23-94 i / Patch 04-21-94 1 ~" Production 04-11-94 i / TDT-P 04-10-94 !~, CTU Conveyed 05-01-94 Sch Sch Sch Sch 1 ,/ Patch /CTU Production I ~ PDC & Static Sch 04-18-94 Sch 04-22-94 Sch 04-23-94 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1,2" 5" ! 5II ~CTU Production Sch 99510.~ ~, DS#6-22A the correct depths are Btm. 10473/Top 10465 DS#9-19, the correct APl# is 50-029-20260-00 DS#18-28ST1 the correct APl# is 50-029-223'29-00 Number of Records: 53 · DeGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska Mobil Please acknowledge receipt by signing and returning a copy of transmittal. Date: ARCO AlasKa, Inc, Is a Subsidiary of Atlant~cRIchfleldCompany ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, horage, AK Transmittal #: 94023 99510,~ ~ Subject: ARCO Cased~_HaJe._F-ina~ -- From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution lweilNumber iL°g(M-D-Y)DateI Tool Type i RUn,scale C°ntract°r °t~,- F~ f 1-24A l 12-24-92 PFC/GR '7~--~ ~ PWDW ~ 01-24-94 Static pre~emp 1,5" Sch ~ ~ ~3-1 ~ 1-30-94 ~ Pe~ Record 1, 5" Sch ~ ~3-1 ~ 2-5-94 ~ CNL 1, 5" Sch ~ ~7 ~ 3-20A ~ 2-2-94 ~ Peal Record ~- ~ ~ 3-21 ~ 2-4-94 ~ Compi R~ord ~- ~ ~ 3-25A ~ 2-4-94 ~ CompI Record ~- ~ ~ 3-27 ~ 2-3-94 ~ Prod Profile ~q-~o~ ~ 3-32 ~ 1-25-94 ~ Bridge Plug ~-~ ~ 4-5 ~ 1-26-94 ~ Tubin~ Cu~er ~,~ ~ 4-~2 ~ 2-2-94 ~ CompIR~ord ~ 1,5" Sch ~~% ~'4-46 ~ 2-6-94 ] USIT/Cement ~ 1,5" Sch "~~4-46 ~ 2-6-94 ~ PDC&Jewerly ~~ 9-9 ~ 2-7-94 j Leak Detec 1, 2"&5" Sch ~ 9-9 j 1-26-94 Leak Detec ~ ~ 9-11 { 1-24-94 Brid~e Plu~~l, 5"~{~ Sch ~- O~ 9-13 ~ 1-29-94 ~ Bfid~e Plu~ ~- ~ 9-20 1-24-94 Mi Inj Profile 1, 5" Sch ~- ~ 9-34 ~ 1-25-94 ~ Bdd~e Plu~ ~ 1, 5" Sch ** 11- ~ 2-3-94 b~ Bridge Plug~ 1, 5" Sch ~-:~ 11-17 ~ 2-5-94 Leak Det~ 1, 1"&5" Sch ~l~ 12-16A ~ 2-2-94 Peal R~ord 1, 5" Sch ~- ~ /14-2B 2-3-94 USlT/Cement 1, 5" Sch ~14-2B ~ 2-4-94 Pe~ R~ord 1, 5" Sch ~- ~[~ ~ 14-31 [ 2-4-94 Prod Profile 1, 5" Sch ~%- I~ ~ 15-9A ~ 2-6-94 Peal R~ord 1, 5" Sch ~ q~ 15-22 ~ 2-6-94 Ped R~o~ 1, 5" Sch ~5- ~ 16-7 ~ 6-16-92 Casing ColOr ~- 5~ 16-22 { 2-3-94 Gasl~suwey ~ ~ ~ 16-29A j 1-31-94 Prod Log * n mo, ** DS~ 11-16ST1 the correct API~ is 50-029-21581-00 Number of Records:32 John E. DeGrey ARCO Alarm, Inc. I$ · Subsidiary of AtlantlcRIcMleldComl~ny ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-3-94 REFERENCE: ARCO CASED HOLE FINAI. S -~'-~.1-11 12-18-93 ~?- 9-_~___1-18 12o12-93 ~~-22 12-03-93 1-25 12-17-93 ~~-6 12-05-93 2-22 10-22-93 ~33-4 12-20-93 -36 12-11-93 4-1 12-06-93 -1 lA 12-13-93 ~'~. _4-23A 12 - 14-93 *~:-? u 4-31 12-11-93 4-41 12-14-93 5-28 12-10-93 6-2 12-20-93 6-16 12- t 5-93 ;9-1 12-5-93 '--k9-1 12-9-93 9-20 12-19-93 .... 9-29 12-13-93 ~-36A 12-17-93 ~-36A 12-17-93 ~~9-51 12-07-93 ¢~1-12 12-06-93 ' ~ll-13A 12-14-93 ~~I- 12-5-93 1~- 17 12-4-~3 .~Q~I 6-23 12-10-93 ~Z.~~i 6-29A 12-18-93 ~~18-29A 10-19-93 CNL (£fl) 1 o2-ZO-,ice~wO Run 1, 5" Leak Detect )5?i~q }T~,n'p/9,-e~0r ~ 1, 5" Peff Record ~eO -1050o ~ 1, 5" Prod Profile / Peri Record ~OiB% -t~U~c ~ 1.5" ~ (dep~ co~ected) ~ 1, 5" Inj Profile ~o )~¢m~c¢S~ ~ 1, 5" Peff Reco~ I ~qO ~/ZZq O ~ 1, 5" Peff Record ~O --~ ~ 1, 5" Peff Record ~ 9~ c ~ - ~ ~ ~ 1, 5" Dual B~st ~T-p (~] ~ 1, 5" Prod Profile ~h,', ?~.:~;~6~':~':::.":'~:~~,'',.~ ~ 1, 5' Perf Record ;'~'5~.:. -'-~'~ 2 ~ 1, 5' Dual B~st ~T-P ~L;3 ~ ~ 1, 5' Prod Profile f-: ~ak Detect J.? ~ Detect/',:~ ~.'~ '~' ~' !.% ~j) . ~ ' ~ -~ ~"~ ~ak Detect ~ CNL]c~' Du~ Bmr ~T-P~GR Prod Profile ~v,~ rod ~G Cutter Peff Record ~ (dep~ co~ected) ~ 1, 5" Please sign and returnee atta/ched cgpy ~ ~r~ceipt of data. rtECE VE ) / John E. DeGrey APPROVED ,' ATO-1529 Trans# 94002. # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct well name is 4-1 lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 The correct well name is 18-29A and the corrected APl# is 50-029-22316-01 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~FINALS ~:~- E?... 3-9 ~10-6-93 3-29 ~4-~ /10-6-93 ~q,--' ~ 2. 3-31 ~10-5-~3 3-32 ~0~ ~0-5-93 ~- ~ 3-33 ~0-10-93 4-4 ~-~ ~0-9-93 ~-~ 4-12~ 10-2-93 4-24 i~- ~0{ v~10-10-93 _7~_6~2¢-445 ~ 9-30-93 - 10-1-93 6-12A c{)._ ~q ~9-29-93 10-1-93 10-6-93 10-9-93 10-9-93 /10-4-93 /10-3-93 - 10-7-93 ~10-1-93 12-22 ~O /9-28-93 /13-20 ~0-2-g3 ~-~ ~13-20 /10-10-93 14-3~ ~B*~[X~-25-03 14-3 ~-28-93 ~tZ~ 14-32 ~10-2-93 15-22 ~-~ ~9-30-93 ~-~O16-17 ~10-8-93 16-22 q0~ ~0-~0-~3 10-8-93 *** 17-16 ~'~ ~0-3-93 , 17-21~;~ ~10-4-93 Perf Record Run ReJff~, e. aar d Run Prod Profile/<~ 1 ~k~e I ,~-~>/~ Run Perf Record lll~-~l~7 R~ Perf Record ~ -~ R~ Completion R~ Pe~ Record R~ Inj ~offie ~al~e~/~l~ R~ ~ak ~tect ]~]~~/~ R~ ~od ~offie(a~m ~%~1 ~/~R~ Perf Record ~ ~- ~ 1~3~ R~ Perf Depth Control/C~,/ccc. Completion Leak Detect / ~'Prod Proflle/~ /Completion ~ Prod Profile 1-~ ~Dual Burst TDTP Leak Detect/~ Leak Detect{5~c~ Inj Profile ;~,~ Dual Burst TDTP D~a.ta. Patch Setting lnJ Profile CNTG/GR/CCL HLDT~ RlccL_ Prod Completion Completion Prod Profile Inj Please sign and return th~ attached copy as re_ceipt of data. RECEIVED BY ~~ Have A Nice Day! $onya Wallace ATO-1529 # CENTRAL FH,ES # CHEVRON #BPX # STATE OF ALAS~ The correct APl# for 1-22 is 50-029-20848-00. The correct APl# for ll-16ST is 50-029-21581-00. The correct API# for 17-16 is 50-029-22286-00. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOI.~ FINALS ~2-8 -17 -5 -14t ~-20 ~.5~9-36 ~?~_.~_9-42 ~ ~ 11-1A ~1-1A q2,--IlO 1-13t 1-108I ~ 2-7A 1-8-93 InJ Profile R~m 1-10-93 Gas Entry R~m 11-23-92 Prod Profile Rrm 1-9-93 InJ Profile R~n 11-24-92 PITS Run 12-4-92 Prod Profile R~m 11-19-92 InJ Profile 11-22-92' lhunp-in Profile Run 1-12-93 Collgr/Ttlbing Patch Run 12-3-92 GR/Collar Run 12-3-92 Prod Profile R~n 12-3-92 GR/Collar R~n 12-6-92 PITS Run 12-10-92 CCL/Jewelry Run 1-8-93 GR/Collar Rl~n 4-28 1-8-93 Prod Profile. Ru_n 7-1~5 11-22-92 Static Temperature R~m Please sign and return the attached copy as receipt of data. RECEIVED B¥___~~__~__~'~~ Have A Nice l~y! Sonya Wallace ATO-1529 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco 1, 5" Camco Trans# 93037 # CENTRAL FILES # CJtEVRON . D&M # LUCiIX,E JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA~ · m aoRE CEIVED The correct APl# for 4-14A is 50-029-20310-00. Alaska 0~ & Gas Cons. Commission Anchorag~ A J::.'. (::: 0 A I... A,*:,' K A: ]: N E:., P, O, BOX 'i A N C l.-t 0 ~ A G F' A L A S K A 1-. R J::-' F: E F;.: E.{ i'..i. C.: E · A R C 0 C A ,<:-: E£ TD H 0 L E F' ]: N A L. '7 7-4 7-7A 7..--i 0 9-i 4 c;, .... ~ ~' .. ~ ..- '7.' A i 4 .... ~ 7 4 ....i9 4..- :':' 8 4 "- ,:': 0 3"-~ 4 5:- ~ 6 TEMF' F'F:ODUCTZ Oi, J. PROF'.[ I_!: F" ]: 't"S F' R 0 D U C T :!: 0 N F' F,' 0 F' :[ I.. i:: (.';. F,' :[ N ..J E [.': T :[ 0 N F' F;,' 0 F: :[ I_ E :i: N J ;£ C T ]: 0 N F:' f;.'. (:)i::' ]: 1.. E: ]:NJECT:[ON F'F,'OF i' L_E :i: N J E C T l' 0 NF" R 0 F 11_ Iii: F'RODUC T :r ON PF;,'OF :1: LE F' R (3 D U C T ]: 0 N F:'R 0 F:' I L. E: TIE M P F'ERF BRE.:AK-I)OWN :_?ij~:VE:Y PRODUCTION F'ROF:[I_IE F'RODLICT 1~ ON PROF I I_E, LEAK DE1'IEC:T ! ON F'LE:ASI:': ,.'.:'If'5i'./: AND F,'F-ZTLIF;:.N THE ATTACHED COPY AS.: RECE]:PT OF' DATA. I--lAVE: A N]:C;E i) AY! ,':'AL.f...Y HOFF:'E'CI< EF;.: A T 0-- i '5 '2 9 JUL c ,, Alaska Oi~ ii, Gas Goos. · Ancho~g~ DISTRIBUi'ION CENTRAl_ FILES .CFtEVRON D & M ,. " F' "'" E¥I'ENSION EXF. L uF.'.e-~T I ON EXXON MARATHON MOBIl_ · '~ P H i I.. I.. :[ F' $ I::'B I,,JE:L.L.. FIt_ES F.'. & O ~- BPX -.-'"'$ T A T E 0 F: A L. A 2." I< A TEXAC:O (:.: F~J J"'*i L: ....... i..; i::~ I'1 I...: I...I (::: A Fi t.::: i:.'; ,':':'~ r'i t:'-: '] C A f'i (::: (J 'A <'-'l t.; ') i:::: A r'.-i <:: (:'; A f'~ (::: 0 C :'::', i'i C 0 C A f'i C (i C A i"i I'-'; 0 C Ait C :) i:; A f'l C 0 C A ii C: 0 C: A H C :) C A ?.i C 0 ,7 ARCO AI_ASKA, ZNC~ F'.O,, BOX i00:560 ANCHOF:.AC;E, ALASKA 995i (.'.', iD A T E · 6 ,." 20 / 90 RF'F:'ERFNCIE' AF;.:CO CAZED HOLE FINA[.£' i-.''.'~' "~ .-:- '"-~ ,q -- ':;' O F'F;,'OOLJCT]:ON F' F;: [i I'-:' ]: L. E: SIJRVE:."T' RLIN i ~':'" o .--.-., 6 - 3.-,~,-:', TEMF'ERATUt-?E LOG · " -~- .' "-,, .... ', 9-4 6-,'5-'.-7'0 TEMPERA]"UFi'.E LC)f:; RtJN i , 5" o _ ,:~ ........ 5" ,. .., 6-Lz,--':?,':; ]"IEMPERATJ IRE SLJt;:.VEY j;..'l 9-6 6-5-90 TEMPERATURE: £:LJ!:;.:VEY RUN i , ':":." 9-9 6-4-9¢:, TEMPERATURIE LOC- RUN t, 5:" 9-'~, i 6--4-o,''-'',. , .., TEMPERAT~ ....... ~RE t_6)(; I:;.:~ li"-.~ i , "'¢." ':-.'~.- i, ::q.._. 6.-4-9,:.:;, TEMF'ERATtJRE SURYEY. RUN, i , "~'.,- · ".:.'- '::' 6) 6---.3- 9 (::, T E M !::'E R A T U F;.'.I'Z LOG F.'. LJ i'4 · .,~.. ~ ,. '.,'-"-':'., ,.,.. ;. A-4-':-:-';:;.. , ,.. "rF:':MPERA"I'tJRE, SUF;.'.VE:f RUN. i , 5" c._...::,,-:-,. ,_.~- ,..,.': ...,..-~... _ c.;,,-::~, .., 'i'EMPEF;.:ATLIF;..'IE LC)i:.; RL. i'..I t , '=-'"..,. i 2-4A <,-:5¢)-90 LEAK DETF'CT:[ON F.:UN i ':~'" i2;--7 .,':'.". - '~ ,':', -- c.;' O,. ,, ,, TtENF:'/SF']:Ni'-!EF;.'. 6/L. S'IJRVEY. RUN i, '::"".... C ~q H C 0 C. A ?.'i C 0 f';: A i:'i C 0 C A f,t C 0 C A ¢,i C 0 C A ri C 0 C Ait C 0 C A i"~ C 0 C A i~ C 0 C :q H C ,":) CAMCO C A i~'i C 0 Pt_EASE SiGN AND F;,'ETURN THE A't"TACHED COF'Y A/.¢ F;:I::'CEIF'f' OI:: DATA, I-:.,::. _. [-:. '~' "--"' D T.q y OA¥! JUN 1! 2 1990 . SA i._ L Y H O F'F'Er'_:I,.': E:F.'.Alask 0il & Gas Cons. commission AT O- i '.52 9 / nctmmge APPROVE- ~' "i' F;.'. A N 5' :~ 90226 DISTRIBUTION '"' CENTRAl_ I:'- I LES C 1.'t E V R 0 N ].:,&iff · "' E"'XTEN$ I ON EXPLORAT_I_' ON · '11' =,T- EXXON HAI:;.'.AI'H 0 N ~ MOBIL '"' F'H :[ I_[_ :[ F',~ F'B WE:L[_ F']:I..E,S' '"' BPX '11" STATE OF ALA:?KA T E X A C 0 Ri---CE Z ViED BY H A V [.i: A N l C': FZ D A"'~" ! MAR - 8 !99'0 Alaska Oil & Gas Cons. CommiSs'tO~ Anchorage 0 F- i) A T/.'.,. i) I S' T R I B U '¥' i f'J N · "' CEN ~ i;.'Ai FILES ~r ~ . "" C: I-.i E V R ri N · ".,,. ,_ r':".< T E i"..~ Z¢ Z O N, .. .. EXF'LORATION · '~ EXXON MARATHON · "- Mi'~BZL ~' P H i L. L I F' F' (':: WELL R & D '"' ' B F;' X '* $"1' A"i" E 0 .... ]" E ¥ .";:', F: fi '!1' ., · . ~ ...... AL. ASK A ~tRuu ALASKA F'~ O. BOX i ANCHORAGE, ALAZKA DATE' t~-4-88 REF'ERENCE~ ARCO .,m~ED HOLE F'INALS i O/i '-~ -.-', U.=, FLLJID I)EN$II"Y i 0-24-88 CNL-GAMMA i O-i 9-'88 VERTiLOG i0/i-3/88 TEMP SURVEY i ~-24.-88 COLLAR i0-27-88 CCL-PLUG S'ETTZNG i ~-27--88 CET ,~_'~o_oo COLLAR/F'ERF' 9-i6/i7-88 COLLAR/F'ERF 9-1 6-88 COL_L_AR/F'ERF i ~]-5-88 PR.C)I)UCTION PROF'II_E i'3'-3-88 INJECTION F'ROFILE 9-22-88 INJECTION PROF'ILE 9-26-88 PRODUCTION F'ROFILE i~-i-88 PROI)UCTION PROFILE i 0-23-88 CNL-GAMMA 9- i 9-88 COLLAR/F'ERF i 0-7-88 GAHMA-COLLAR i 0-9-88 GAMHA-'CCL i ~3"-8-88 COLLAR 9-3'3-88 PRODUCTION PROF'ILE 9-i 4-88 COLLAR/PERF i (~ - 2 - 88 P I T 3' i C:'- 2',;'- 88 COLI_AR/[:'FRF GN AND RETLJR.'N i"~:Z-A'f'T~-,CHED C O P Y RECEIVED BY_ HAVE A NICE DAY! ,.',HLL~ HOFFECKER ATO-i 529 TRANS AF'F'ROVED DISTRiBUTiON CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL RUN '? ~';" RtJN i, '5' RUN t , 5" R~JN i, 5' RLJN t , 5" RUN i, 5' RUN t, ~" R UN i , S" RLJN t , ~ ' RtJN t, ~' RLJN i , 5' RUN ~, 5 ' RUN ~ , ~" RUN 3, 5' RUN ~, 5" RUN ~ , 5' RUN ~ , ~' Rtj N i , ~ ' RUN i , D' RtJN t, 5' RUN i , D' R (JN i , ~ ' RUN t, D' RUN t , ~ ' AS RE:Ck:.iF"f' OF' I)A'i'A. .. Anchorage PHILLIPS F'B, WELL FILES -,,-'" SAPC ~ STATE OF- ALASKA .~- ~.,- I'EXACO CAMCO A i'l_A£ A 'r L A 3' C A ¢i C 0 A 'r L. A ::-;' $CH ~' C'.' H (:.:-. E A R G E A R GEAR C A M :J 0 C A M C 0 C A M C 0 C A M C O C A i'i C 0 A'i-I_AS GEAR: C A id C 0 C A M C 0 C A H C (] C A M C O C A M C 0 A 'i L A ,? THE:SE LOGS HAVE TI'tE WRONG AP1 NOS ON 7-33 t5:'0'-029-'2 t 8(:'9 i =": i r.", A =~ (:).-. A ":) O -.- 9 ;:~ ~: r:", i A i _~,. ~ .... .., . :.., ,.._ · ~ .,.. ~ ... -- ,.~, '1" FI E Pi, 'f' H F= C' 0 R R E C 'i' N 0 $ A R lie · A n c h o r a g e, A l a .'.; I.,' a OATE: July 6, t987 REI:'r..!:I-"(t.ENCE: ARCO Ca~ed He, lc:, F'i na L F:'teaxe ~ign and i::' I. o p ,. F:', L ~ ( C C L. / g R / I"11::'/'1' E: H F:', ) I::' L c, p. F:'., I .... ( C: C;I.. / C; R / H F'/'r E M P, ) I::' i. op. !::'. L. ( [;[;L./gFi:/HF'/'I'EHP, ) F'er 1:', Record F'erf~ Record F' I. op, F', L. ~ ( C..CL./(-,r:e/I-tF'/TEHF' ~ ) Per f, Record PerT., R'ecord F' L o p, P. I_, ( H e m o r '.-/ .5,' p i n, ) F' t. o p. F'. L. ( M ti, m c, r' ¥ S p i n. ) (, ¢.L. re'l:u, rn 'i:h~ I:~!~,'ar-:t,.,O.~ [~:opy ~' receipt of I:;,'U. YI t , Run 1 , F;~un I , Run 2, F:.un t , Run t , Run t, R u n 'i , Ru.n t , R u n t , Received By ..i~,! J. HAVE A NZCE DAY! ~-daS.<~ 0it & Gas (::~.~.. Ro~anne F'eek A 'l' 0 -" t :~' ''~ o TRANS ~87344 ~. AI.-,p roved ................................................................................ D I S T R I B U T :[ 0 N ii 15" 5" 5" 5" !.5" 5" 5" 5" !5" · ,-'"' C~-.',,¥'~tra L F"i Le~ · "'.,, C.'. h e v r o n I) & M ~ F x x o n Ha r a '1' h on ,,.'"' Hob i L ~La..s'l<a, Inc: Box r a g e, iq L a DATE]: September 26, t986 REFERENCE: ARCO Ca.s'ed HoLe Final ~ S-i(~ 9-.i8-86 $t'ep Rate Inj, Profi Le/GR Run i, ~4-'t 9-.2t-86 Produc:(ion Profi Le Run i, 5" Camco ~-4-"'9 9-.t0-86 Temp, Log/lnj, F'rofi Le Run t, 5' Camco '4-9 9:t5-.86 Inj, F'rofi Le Run t, 5" Camco _ ~ 5 ' C a m c o ~4-. t (') 9-.' t ~-.. 86 'T'¢, m p L o ~ R u n t , ~4-t() 9-.tS-86 In j, Profi Le Run t, 5" Camco ~9-i2 9-.lt/i ''~ 86 Spinner/Inj. Pro fi Le Run ~-t2 9-.1t /i 2--86 Temp, I. og Run 3, 5" Camco ~9-'.i2 ~-tS'-86 Temp~ Log Run i, S' Camc:o ~~-i7 9--.tt-.86 In.j~ F'rofi le Run l, 5" Camc:o ~9-..i7 9.-.ii.-.86 Temp~ Log Run i, S" Camco 9-' ''~ ~.S 9-'20-86 Inj F:'rofi Le Run i, 5' Coreco ii--2 s~ ~4 o Camco .-' -,::,6 ,S'pinner/Temp, S'urvey Run i, ~i . ~' ' C m m c o i i ~ 9-.2~/2t-.86 Sp inner ko~ Run i, ~ii--ii 9--- t '3/ i 4--.86 ,S:pinner/F'roclu. ci'ion F'rofi Le Run 2, 5" Camco "~i6-2 9-t5-86 Temp, Log Leak De'teciJon Run i, 5' Camco F:' I. e a :~'e z,' i gn an d r e~ th c~:"~' a ch/~ d c o p F~'.ec e i vecl By. ......._..~zrz~_ _. ,/.~,/... Z'"~~Z .,r- (.~--~' ~4..,/~ HAVE ~ NICE~/ '- ,, ~ /~ ~A{aska 0}{ & Gas Go~,~. R o ~ a n n ~,A:'e e I-: / ' ....... Anchorage ATO- t TRANS .~:86597 I) ItTRIBUTION ,,-'"' Cen'tra L F:'i le~ · ,~ Chevron -..'"' E x t e n _s i o n E x p L o r a t; i o n · ..~" Exxon Marathon -..'"' Mob i l -,.'"' Phi L lip $ F'B We L L F'i Le~ R & D '"' Soh i o '1~' · ,. State of Aia_~ka '"'..- Texaco ~' STATE OF ALASKA ALASK/-~ OIL AND GAS CONSERVATION ~OMMISSION /i'~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Welt ? OIL [] "GAS [] SUSPENDED [] ABANDONED [] SERVICE I~x Water Injector . , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-41 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20261 ~,. Location of well at surface 9. Unit or Lease Name 407' FSL, 274' FWL, Sec.1, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1245' FNL, 1583' FWL, Sec.12, T10N, R15E, UM 9-20 At Total Depth 11. Field and Pool 1370' FNL, 1624' FWL, Sec.12, T10N, R15E, UM Prudhoe Bay Field , , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 54' RKBI ADL 28327 12. D.ate .Spudded 13. Date T.D. Reached 14. Date C.omp., Susp. or Aband. J 15. Water Depth, if offshore 16. No. of Completions 1 2/28/77 01/12/78 1/19/78~I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9685'MD,9271 'TVD )61 2'MD,9201 'TVD YE~)~ NO []I 2340 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run SP/DIL, BHC, Cal iper/GR, FDC/Cal iper/GR, CNL/CCL/GR, Mul ti shot 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:~ 94.0# 1II-4U Surf 101 ' ~,0,, 258 sx AS II ,_ 13-3/8" 72.0# N-80 Surf '2683i 17-1/2" 4200 sx AS cmt 9-5/8" 47.0# N-80/S00-95Surf 9662' 12-1/4" 1000 sx Class G ,,, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) *9424 ' -9454 'MD 8792-9033 'TVD 5-1/2" 9078 ' 8?:9 ' *'9188 ' -9202 'MD *'9216 '-9250 'MD 26. ACI D, FRACTUR E, CEMENT SQUEEZE, ETC. ..... 9361 '-9373 'MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9329 ' -9333 'MD ~/~ 9277 ' -9317 'MD . .. *New perfs shot 2/30/84 w/4 spf. **ltl~,~ r~r,~:~ el~,~,l- h_/l"~--./~h~ ,.,il, ~.~.1: . ..... r .......... · ~ ~ ' "~ ' ~1-'' · 27. PRODUCTION TEST ,. Date First Production I Method of Operation (Flowing, gas lift, etc.) I 3/13/78 ,Water niector . · Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAs-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO N/A TEST PERIOD J~ , , Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,Jr 28. CORE DATA .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None - Form 10-407 * NOTE: Well was perforated 2/14/78. Well was worked over 5/31/86. (DAM) WC1/11t~ubmit in duplicate ,,/ Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. i '. 30. , ', ,, GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad1 er'ochit 9150' 8755' NA 0/W Contact 9497 ' 9090' Base Sadl erochit 9524' 9116' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ([~ ~ ~~, Title Associate Engineer Date // INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALa:~ka, Inc. P.,O~ Box ~C~(-)S60 Anchorage, ALma-kin 995~ .0 DATE· Ju£y ~ ~ ~t986 REFERENCE' ARCO Ca.sed HoLe l=inat. 9---20 ':3...-25-86 C.o L L~¥'/t::'er f Run t4-4 5-24-86 G, ol. Lar/Per f Run t 5" · I::,' u r,~ I...inda l..lu Lce ATO- t 529 "; 8 TRANS' ~:864~. f~e ~ l" Gear DIS'TRIBUTION · "' C'. e n t: r a L F i I.e.~; · "'... C. h e V i~ 0 n D & kl · ,,."" E x ~. e n .s i o n E x P 1. o 'r a t' i o n · '~ E x x ,'", n · 1:1' ... · ,. M o b i I. · ,.'"' Phi LLips' F'B Wet. I. F:'i Les' R & D '~ ~: o h i o · "'.,- ..,,~'~'~ t'e of A l.a.',~ka '"",r't" e x 8 C: 0 .... STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMrv, _31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate ~,, Pull tubing Alter Casing ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 10C)~0 Anc. hnran_e.. AK 99510 4. Location of well at surface 407'FSL, 274'FWL, Sec.1, T10N, R15E, UM At top of productive interval 1245'FNL, 1583'FWL, Sec.12, TION, R15E, UN At effective depth 1362'FNL, 1621' FWL, Sec.12, T10N, R15E, UN At total depth 1370'FNL, 1624'FWL, Sec.12, TION, R15E, UN 5. Datum elevation (DF or KB) RKB 54' (above MSL) 6. Unit or Property name Pr,,ahn~ Ray I~ni ~. 7. Well number 9-20 8. Approval number 76 9. APl number 50-- 029 -20261 10. Pool Prudhoe Bay Oil Pool Feet 11. Present well condition summary Total depth: measured 9685 feet true vertical 9271 feet Effective depth: measured 961 2 feet true vertical 9201 feet Casing Length Size Conductor 80 ' 20" Surface 2683 ' 13-3/8" Product i on 9634 ' 9-5/8" Plugs(measured) 9044' (Bridge plug in tailp Junk (measured) None Cemented Measured depth 258 sx AS II 101'MD 4200 sx Arctic Set 2683'HD 1000 sx Class G 9662'MD ~ue Verticaldepth 101'TVD 2683'TVD 9252'TVD Perforation depth: measured 9188' true vertical 8792 ' - 9454 'MD - 9033'TVD Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail ~ 9078' Packers and SSSV (type and measured depth) SAB pkr @ 8949'MD & BAL-O SSSV ~ 2340'MD 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well Histo~/ w/Addendum) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associ ate Engineer Date ipe) (DAM) SWO/056 Submitin Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or welt is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon comp[edom report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska County or Parish Field Lease or Unit Prudhoe Bay Auth. or W.O. no. T tie AFE AS0758 Operator WWS #1 ARCO Alaska, Inc. Spudded or W.O. begun Complete 5/28/86 5/29/86 Date and depth as of 8:00 a.m. 5/30/86 5/31/86 North Slope Borough ADL #28327 Completion Accounting cost center code State Alaska Well no. 9-20 50-029-20261 A.R,Co, W.I. ~Total number of wells (active or inactive) on thist Icost center prior to plugging and I 21.66% Jabandonment of this well Date IHour I Prior status if a W,O. 5/28/86 ] 0330 Hrs. Complete record for each day reported 9-5/8" @ 9662' 9044' WLM (BP in tailpipe), NU BOPE 9.4 ppg NaC1 Accept rig @ 0330 hrs, 5/28/86. 9-5/8" @ 9662' 9044' WLM, ND tbg spool 9.4 ppg NaC1 NU & tst BOPE. Tst 9-5/8" csg. POOH & LD 5½" tbg & SBR. Chg rams to 3½" & tst. Pull 9-5/8" packoff leaving btm ring & seal in head. ND tbg spool to retry remaining portion of packoff. 9-5/8" @ 9662' 9044' WLM, TOH, LD DP 9.4 ppg NaC1 ND tbg spool. Rn new 9-5/8" packoff & NU tbg spool. Tst packoff & BOPE; OK. RIH w/fsh'g tls on 3½" DP, latch onto fsh, CBU, POH & rec'd fsh. Tst csg to 2000 psi. TIH w/3½" DP, TOH & LD DP. 9-5/8" @ 9662' 9044' WLM, RR 6.8 ppg Diesel in tbg Chg rams to 5½" & tst. Rn 204 its, 5½", 17#, L-80 LTC AB Mod tbg w/Bal-O SSSV @ 2340', PBR @ 8932', SAB pkr @ 8949', TT @ 9078'. Circ 100 bbls diesel dn tbg. Tst tbg & ann, ND BOPE, NU & tst tree. RR @ 1930 hrs, 5/31/86. Old TD Released rig 1930 Hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing INew TD IPB Depth 9612 ' Date IKind of rig 5/31/86 I Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Pump size. SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable corrected The~O~ correct S' nature ,' .- .. For f;rm preparation a~tribut,o~, ~ see Procedures Manua~tion 10. Drilling, Pages 86 and 87. IDate ITitle 6/13/86 Drilling Supervisor ADDENDUM WELL: 5/24/8.6 6/03/86 9-20 RU GO. RIH w/BP to 9035' CCL (top of plug @ 9044'/btm @ 9046'), log up to 200', POOH. RU perf gun, RIH, shot w/4 SPF f/8840'-8842' & 8840'-8842', POOH, RD GO. Displ hole to 9.4 ppg NaC1. RU Otis, pull safety vlv dummy. RU DA, RIH w/3½" OD tbg cutter, found tbg plug 1 jt high @ 9040' WLM, XN nipple @ 9018' WLM. Att to cut tbg w/o success, POH. RIH w/3½" OD tbg cutter, shot @ 9037', sat dn on plug indicating TT still in place, POH. RIH w/3½" OD tbg cutter, shot @ 9035'. RIH to 9200', log compl jewelry, POH, RD DA. Turn well over to Production. Drilling Supervisor ~ D~te STATE OF ALASKA .... ALASI,, OIL AND GAS CONSERVATION COMN 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing ~_ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P .0. Box I {')o~ign An~_hr~rane _ AK 99c~1 fl 4. Location of well at surface 407'FSL, 274'FWL~ Sec.1, T10N, R15E~ UN Perforate -- Pull tubing 5. Datum elevation (DF or KB) RKB 54' (above HSL) 6. Unit or Property name Pr~,rlhn~ Rnv Iln-i'r 7. Well number 9-20 8. Approval number 76 9. APl number 50-- 029-20261 Feet At top of productive interval 1245'FNL, 1583'FWL, Sec.12, At effective depth 1362'FNL, 1621' FWL, $ec.12~ At total depth 1370'FNL, 1624'FWL, Sec.12, T10N, R15E, UN TION, R15E, UM TION, R15E, UM 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2683' Production 9634' 9685 9271 9612 9201 feet feet feet feet Size 20" I 3 - 3/8" 9 -5/8" Plugs (measured) 9044 ' Junk (measured) None Cemented Measured depth 258 sx AS II 101'MD 4200 sx Arctic Set 2683'MD 1000 sx Class G 9662'MD (Bridge plug in tail ~ue Verticaldepth 101'TVD 2683'TVD 9252'TVD Perforation depth: measured 91 88 ' true vertical 8792 ' - 9454 ' MD - 9033 ' TVD Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail @ 9078' Packers and SSSV (type and measured depth) SAB pkr @ 8949'MD & BAL-O SSSV ~ 2340'MD 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure . 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well History w/ Daily Report of Well Operations ~ Addendum) Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 ~ Title Associate Engineer Date ipe) (DAM) SW0/056 Submitin Duplicate ARCO Oil and Gas Company Daily Well History-Final Report "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. required upon completion, report completion and representative test data in blocks provided. The "Filial Report" form may be used for reporting the entire operation if space is available. Spudded or W.O. begun Complete Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit I Weil no. Prudhoe Bay ADL #28327 I 9-20 Auth. or W,O. no. IT t e AFE AS0758 I Completion WWS #1 50-029-20261 Operator J AR.Co. W.I. ARCO Alaska, Inc. ] 21.66% IOate 5/28/86 5/28/86 5/29/86 5/30/86 5/31/86 Date and depth as of 8:00 a.m. Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well J our I Prior status if a W,O. I 0330 Hrs. 9-5/8" @ 9662' 9044' WLM (BP in tailpipe), NU BOPE 9.4 ppg NaC1 Accept rig @ 0330 hrs, 5/28/86. 9-5/8" @ 9662' 9044' WLM, ND tbg spool 9.4 ppg NaC1 NU & tst BOPE. Tst 9-5/8" csg. POOH & LD 5½" tbg & SBR. Chg rams to 3½" & tst. Pull 9-5/8" packoff leaving btm ring & seal in head. ND tbg spool to retrv remaining portion of packoff. 9-5/8" @ 9662' 9044' WLM, TOH, LD DP 9.4 ppg NaC1 ND tbg Spool. Rn new 9-5/8" packoff & NU tbg spool. Tst packoff & BOPE; OK. RIH w/fsh'g tls on 3½" DP, latch onto fsh, CBU, POH & rec'd fsh. Tst csg to 2000 psi. TIH w/3½" DP, TOH & LD DP. 9-5/8" @ 9662' 9044' WLM, RR 6.8 ppg Diesel in tbg Chg rams to 5½" & tst. Rn 204 jts, 5½", 17#, L-80 LTC AB Mod tbg w/Bal-O SSSV @ 2340', PBR @ 8932', SAB pkr @ 8949', TT @ 9078'. Circ 100 bbls diesel dn tbg. Tst tbg & ann, ND BOPE, NU & tst tree. RR @ 1930 hrs, 5/31/86. Old TO Released rig 1930 Hrs. Classifications (oil, gas, etc.) Oil INew TO ]PB Depth 9612' Date I Kind of rig 5/31/86 I Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Sadierochit Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production ~i :~ ~ ~i~ ; ~ ~ ~ ~.~ ~;~ Oil on test Gas per day ,, ,, Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected sT.h en~atuOVe"ls correct see Procedures Manua[.._i.~a~tion 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 5/24/86 6/03/86 9-20 RU GO. RIH w/BP to 9035' CCL (top of plug @ 9044'/btm @ 9046'), log up to 200', POOH. RU perf gun, RIH, shot w/4 SPF f/8840'-8842' & 8840'-8842', POOH, RD GO. Displ hole to 9.4 ppg NaC1. RU Otis, pull safety vlv dummy. RU DA, RIH w/3½" OD tbg cutter, found tbg plug 1 jt high @ 9040' WLM, XN nipple @ 9018' WLM. Att to cut tbg w/o success, POH. RIH w/3½" OD tbg cutter, shot @ 9037', sat dn on plug indicating TT still in place, POH. RIH w/3½" OD tbg cutter, shot @ 9035'. RIH to 9200', log compl jewelry, POH, RD DA. Turn well over to Production. Drilling Supervisor STATE OF ALASKA ALASK,-..~IL AND GAS CONSERVATION COMM, .,ION APPLICATION FOR SUNDRY APPROVALS feet~~ 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ?~. Alter casing Time extension ~ Change approved program ~' Plugging ~ Stimulate FF Pull tubing '~ Amend order :-: Perforate "' Other 2. Name of Operator ARCO Alaska, Inco 3. Address P. 0. Box 100360 Anchora,qe, AK 99510 4. Location of well at surface 407'FSL, 274'FWL, Sec.1, TION, R15E, UM At top of productive interval 1245'FNL, 1583'FWL, Sec.12, TION, R15E, UM At effective depth 1362'FNL, 1621'FWL, Sec.12, TION, R15E, UM At total depth 1370'FNL, 1624'FWL, Sec.12, TION, R15E, UM 11. Present well condition summary Total depth: measured 9685 feet true vertical 9271 feet Effective depth: measured 961 2 feet true vertical feet 9201 Casing Length Size Conductor 101' 20" Surface 2683' 13-3/8" Production 9662' 9-5/8" Perforation dePth: measured true vertical 5. Datum elevation (DF or KB) 54' RKB (above HSL.) 6. Unit or Property name Prudhoe Bay Unit 7. Well number 9-20 8. Permit number 77-41 9. APl number 50-- 029~20261 10. Pool Pr'udhoe Bay 0i] Pool Plugs (measured) None Junk (measured) None Cemented Measured depth 258 sx AS II 101'HD 4200 sx Arctic Set 2683'MD 1000 sx Class C 9662'MD True Vertical depth I 01 ' TVD 2683 'TVD 9252 'TVD 91 88' - 9454 'MD 8792' - 9033'TVD Tubing (size, grade and measured depth) 5-1/2" 17 O# N-80 LTC AB-MOD 8900'MD RECEIVED MAY ! 4 1986 Alaska 0il & Gas Cons. Commission Anchorage Packers and SSSV(typ and measured depth) .a er 9-5/8" s^ epac er e 8950'. Otis RQY SSSV ~ 2193'MD 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch¢,~ 13. Estimated date for commencing operation May 25~ 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~ Title Associ ate Engineer Conditions of approval Approved by (RML) SA/035 Commission Use Only Notifycommissionsorepresentativemaywitness I ApprovalNo..~,~+~ [] Plug integrity j~BOP Test [] Location clearance ~.~:~-,~:.~V~. -:.· :. ....... ? ~ -~ ~,~ ~i' by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate DS 9-20 WORKOVER PROCEDURE Workover Fluid: 9.4 ppg NaC1 BHP: 3950 psi @ 8854'TVD Procedure: 1. Set plug in tailpipe. 2. Shift sliding sleeve open. 3. Circulate 9.4 ppg NaC1 brine. 4. ND tree. NU BOPs. 5. Pull and lay down tubing. 6. Replace 9-5/8" packoff. 7. RIH with new 5~1/2" tubing and SSSV. 8. ND BOPs. NU tree. 9. Pull plug in tailpipe. RECEIVED MAY 1 4 1986 SA/O35a:tw BLOWOUT PREVENTER DIAGRAM ROTARY KELLY BUSI'IIN~ ROTARY BE&MS FLOW NIPPLE 13-5/8" 5000# W.P. A NNUt.~I~ 13-5/8" 13-5/8" 13-5/8" 5000~ W,P. 50009 W.P. 50005 W.P. 811'4~ER SffOm. BLINO R, MI MU0 C. qOII ¢1K)88 OVER IPOOL (as required) WELLHEAD MATT BOARD8 · "RAOEN#E&i)' ' MAY 1 4 1986 Alsska Oil & G:~s Gons~ Commission A~lchoro.ge RML 5~6~86 ARCO ALaska, Inc. P.,O. Box t0(~360 Anchorage, Alaska 995t0 DATE' March ii, t986 REFERENCE' ARCO Ca_~ed HoLe Final 9"-'.~O ~ _o-~_o~ ~p inner 9-22 ~-2S-86 Spinner/Inj. 5" 9-24 ~ ~--i-85 ACBL/VDL./Y i g/GR Run o _ o '-, ~ ~ - 3 - 8 ~ 5" , ~., .~ Prod~ Logging ~Jvc, Run 9-.27 I -5-85 [;R/5'p inner 5" 9-28 i -5-85 6R/,?p inner 5" ...... fl 5.' 9- 29 i 2'-- i 5- 8 =¢ P D K I ,::.) 0 R u. n i .,- ...... ~..--- ._ F~CBI_/VDt._/.?ig,/(;R Run I 5 11-.-t2 t-9-..85 CF'5' Run t 5" i°-'°9.~. ~. t l.--~-.84.. CCL/Perf Record Run t 0 t' i_~: Ot DA DA Ot i5 Ot i~ t) A D A (:.; o .? c I"~ F:' t. e a :; e ~,~ i g ~ a n d r e .1: u r n 4: h e a t +. a c h e d c o p y a s' r e c e i p t o f d a t a, Received By ............................. - HAVE A N I CE D A~~ Irma C. ar Lin ATO-t 429F TRA N,:? .... o ~ ~,.,,.. t 9'7 D 13' T R t B U T I 0 N Central Fi [e~ C h e v r o n D & M Extens'ion Exp[oration Ex xon Marathon Mob i [ Phi I.L ips' F:'B We I. L R & D ..:. o h i o Z'fa te of Texaco F:' i J. e A La.ska ARr'n Ata~k~, Inc F'. O. Box i Anchorage, A DATE' January 7, i986 ,~- - .,~-~,-.... R~ F E F,,..,-~,..E ARC[) Ca :;ed FioLe Fin,s~s' I>~; o-S t°- °'':;- p, ~: ..... ~ b,F;.:./,S.'p ] ¥',nF.,r L.c'.,9 Ru.'n t '""" · ,,l.-.... ~ .; ... _.~ D;? ~:'-i= i 2-20-8Y i r.,j ec* '=" . _~ , ion Profi Le/3pJ'nner R,..n i _:. D~'. m--T,,.'.':,. ,_,. i2-.2i-o~'~... 'l"emperalur~:,/~:p. ._ iht, er L.o?, Ru'n 'i ... C a fiic C g.~ ~;I C C., F'J. ea-_.-:e sJg'n and rei'u;-n 't'he ai't:ached cop:,' a:.-.. ,eceipt' oi:' 'J,~'!'..~, l:;,'ece i vecl By HA\."E A NICE DAY! i<eLl, y McF'a;-La'nd ATO--i 429F DI3TRIBUT]:ON :Ce'n±ral Fi [es" : Chert on D & ri .Ex"l:.e'n~ion Exp Lorai'io'n E x x on Moh i~ [ F'hi LLip~ F:'B WeL l.'F:'i Les F;.: & D Sohio 5"'t'a't'e of A[as-I<a T e x ~ C: C, ARCO Alaska, Inc~ Post Office [::sox 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 5, 1985 Reference: ARCO CH Finals · ~6-3~~~ Spinner 8-22/23 Spinner 8-21-85 9-20 Spinner 8-22-85 14-35 Epilog 5-11-85 15-10 Temp log 8-28-85 'Run 1 5" Camco 1 5" Camco 1 5" Camco 1 5" DA 1 5" Camco RECEIVED Please s b~;.ign ashcan. _~~~p .~_ , as c o t . Received ( ~~ ' '"' (,-,) ~,~a b,~ & L~ ~.~s. Commission Pam Lambert ATO 1429C Trans 305 Chevron Phi 11 ips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon Sta te~f.. Alaska Mare thon Texa co Mob i i ARCO Alaska. Inc. iS a Subsidiary of Atlanticl~i'~fi~'~'' ....... ARCO Alaska, Inc. .' Prudhoe Bay E~' .eering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 .Permit # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS 17-10 Permit # 81-97 Dear Mr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb R ECE I VED Attachment s JAN 2 5 lg05 cc: Sohio Alaska Petroleum Company Alaska Oil & Gas Cons. C0mmlssl0rl Anchorage ARCO Alaska, Inc. Is a Subsidiary of AflantlcRIchfleldCompany STATE OF ALASKA ALASKA DIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LL][~] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 407'N & 274'E of SW cr Sec. 1, T10N, R15E, UM 1245'N & 1583'E of NWcr Sec. 12, T10N, R15E, UM 1370'S & 1624'E of NW cr Sec. 12, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 54' RKB 6. Lease Designation and Serial No. ADL 28327 7. Permit No. 77-41 8. APl Number 50- 029-20261 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 9-20 to water injection service. The well is part of the Flow Station 2 waterflood project. The well began receiving water on Jtme 14, 1984. 14. I h¢.r~.hV/~rtifyt~~oing is true and correct to the best of my knowledge. Signed ~/.,A . . _ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by_ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO A L,:.'.,:'.-'.:ka, Inck:-~.~ 1::' 0 T:,' (::, x 'i '~ (~ ,-', 6 (D A n ,::: h ,:::, r a g e, A L a .s k a 9 9.5 t e :. ;':: ,:: .:':- :'.': .'."!: i '::'.I T'i a i'l CI ...T':' :I; $ T R I B',_,"v, :l: C,' N Chevron Hob i I. I) & i'4 Ho l:':i I. Iii: & F:' ti-;: x I:) L ,:::, r a t i o n ,~;' e r v i c e :~ F:' h i L I. i t:) .s' 1!:' x 't' e n .s' i o n E x I:) I. o r a t i o n F:' r ~..~ cl h ,:::, e B a 'x' W,..-,:, I. I. I:T.x xon I'.;. ,.'!.~ D 5 e t' 't y .%' o h i o Ma r' a 't: l",, ::',n State of A La~.sl.(a J:: i J. ,;.:-." :!!: ARCO ALa.'¢ka, Inc. I::' .. CI. Bc, x Ancl',o'Fage, ALa.ska 99~ DATE' Octobe'," 2, i984 R E F' E R IE N C E · A R C 0 C a .s- e d Hole F'inaL.s' D,. Y., i .... i A o...,, i 9 "--84 C: t::' ."';' / ,'.';' p i n n e r F;,' u r, i'.:5" D ,? .-z .. R u n i ':~" , , ,:_,-2.::.. 9--.-9----84 Cl':;":.:/~:;:p inner .., D %' 3 '~ i ......c~ ... 8 -P, a ..... ~" / "::" .....CF ~',, 5'p inner I:;,'ur, i , D,.5:, S-24 9-S-84 CoLLar/F'erf Log Run i/2 D,SI, '5: .... i ' 8-Z,i .... 84 Di ff l'emp Rut, i 5" o · . R u ~-~ i ':~" D .. Z~'. :.--i 8-.-:3 i -,,4F:'I ,.x i d Dens' i t y .~. I") S', 7 4 "" RUrl i 5:" .... - .~;-- i (:,-84 C o L [ a 'l- /I::'e r f L. o g D.,,"_-?, 7-4 9...-.5-84 CI:';:/5'p inner IN:un t '5" = I: .'.' II ...,' D ~ ....... , ..,. ;.:~. ...... , ~:., ,' .... 4 c,, ..... :::_ o ,, P. i f f "f',"-', m F-:' F;.'. u r, i D~,..?, g: ..... iS' o,...., i 6_84 Di ff Temp I..;':,..g Run t ..;':~" D.., ;~ , g: .... i .,. '=: 8 - S £:, .-.. 84 C o n i.. i n u o u ~' 5; p i n n ~.:,.. r /F I. o I. o ::l_ F;,' ,~.. n 2 5" D~ ,~J: , 9 .... i ..,, ~"' ' ~'' i::'.. - ,;..":' ..4- .... (::':.: ,-'.'..., C o r, i.. i n u ,::.', u. :.'..; ;ii: I:, i n n e r / 1:: I. o I. o g R u n i '.:5" D S' 9..--2,"~, 'i" -- i o ,.) R u n i "::" .... ,. .... ::., 4 ;~: i::' i n n e r -~' D '~' , ..... .. ,=... i ~'."; .... i i '/'-9.---"~;.-.. ::::: 4 D i f 'f "F e m p L.. o g R u r,i 5" L, F ~ / .,. I..' i R u 'r; i 5'" ",'~. Y i a-Si/ "'-..2(.) .... 84 ..... "" :~ .... ;",net ... ~ , · ~ D z~., i 6 ''~ - "" ''~ '-" ~ ..::, ';, -.,...'--o 4 D i f 1:' T e ;,;1::. R u n t HAVIE A NICIE DAY! I<eLI. y Mc:F:'arLand A'F 0 .... i 4 2 9 F G 0 (.';. 0 '..5" G 0 G f..'l (.; (:.'l (:';, 0 GO E 0 0 't' i .s' l;I .,., I't i) A C a m c o I) A (:.;..r.) G 0 ':::" [;: F'I ....' ... G 0 i:.;, 0 D t S' "F R I B U 'l' I 0 N Chevron I) & N ExpLoration Services Exten~ i on Exp Lc)rat ion Ex x on Ma r a '~ h on Mob i L Mobi L [it & F' Phi L !. i p.s F:'ruclhc, e Bay WeLl. R ,.& I) $ohio - State of ALaska ARCO Atas'ka F'.O. Box Anchorage, Ataska 99.5 i 0 DATE' £eptember t2, t984 REF:ERENCE-Z' ARCC! C@_s'ed Ho l.e Fina L~ D.$, 4-'7"~ -~"%,"'"'7-26-84 Temperature Log D $ 4-20- '7-''~ . , ~8--84 Tempermture Log D~. 6-6 ~" 8-4-84 CH CNL D~5', 9-28 ......,--3-.-26-84 Temperature L. og D~ ~4.--~ _8--3-84 FI. uid Den.stiy ~'"8 t ~ 8 I'/NLL./GR I)~5'. ~4-t6 - 4 DD D.~. ~4-24.-- 5 t7 84 5'p~nner Log D.~'. ~6-2 ~ 7--29/S~--.84 Inject ~on Prof~ ~e Log R ~t n 1 Run t r- .n t Run 2 Run t 5" 5" 5" '5" 5" 5 ' 5" ~--ign and return the attached copy · ~ " t o'f data. a:~ r~.:.ce i p TRANS' ..."z"~m .~ 'Il' ~.., -%-' DI~'TRIBUTION Ch eYr on Exploration 5'ervice~' Ex'l'en~-ion ExpLoration Exxon Getty Ma r a t h on Mob i l Mobil E & P Phi I lip:s F'rudhoe Bay WeLl. R&D $ohio State of Ala~'ka Fri Les ARCO Alaska, Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, 1984 Reference: ARCO Cased Hole Finals D.S. 2-17~/ 5-23-84 D.S. 7-19--- 6-15-84 D.S. 9-14 ~/ 7-20-84 D.S. 9-15 7-20-84 D.S. 9-16 7-21-84 D.S. 9-17-"-' 7-21-84 D.S. 9-20/ 7-19-84 D.S. 11-7J'- 6-15-84 D.S. 13-27 6-2-84 Basket Flowmeter Spinner Spinner Spinner Spinner Spinner Spinner CN/MSN/GR Diff Temp Run 1 5" Camco Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" DA Run 1 5" GO ~Please sign and data. return the attached copy as receipt of Kelly McFarland ATO-1429F Trans. #302 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Ge tty Marathon Mobil E & P C~;,~:~, Comrnfs~/0n ":~f~ r.:'~'q ~ Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9 Water Injectors Permit Nos: 76-70, 76-82, 77-7, 77-25, 77-36, 77-37, 77-38, 77-39, 77-40, 77-41 Enclosed are the Sundry Notices for Change of Well Status for the proposed Drill Site 9 Water Injectors. Very truly yours, D. F. Scheve DFS:SDC:kg Enclosures cc: SOHIO Alaska Petroleum Co. STATE OF ALASKA ALASKA~ .AND GAS CONSERVATION CC ¢IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL [] OTHER [] 2. Name of Ol~erator 7. Permit No. ARCO Alaska, Inc. 77-41 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 407'N & 274'E of SW cr Sec. 1, T10N, R15E, DM 1245'S & 1583'E of NW cr Sec. 12, T10N, R15E, UM 1370'S & 1624'E of NW cr Sec.'12, T10N, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 54' RKB 6. Lease Designation and Serial No. ADL 28327 8. APl Number 50- 029-20261 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To IndiCate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] .Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and !;live pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25,t05-170). ARCO Alaska, Inc. proposes to change Well 9-20 status from oil producer to water injector. It will be operated, as part of the Prudhoe Bay Waterflood Project. Se,, -- t,~o.I RECEIVED JUN 1 41984 Alaska Oil & 8as Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~~,.~',~'~ Title R8cjional l~,ngin88r The space belo~ for comm/issi°n use Date Conditions of Approval, if any: ORIG N,~I. SIGNED BI LONNIE t. $11TII Approved by. COMMISSIONER Approved Copy .Re, turned .... By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay E,,~lneering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 10, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-14 DS 9-17 DS 9-18 9-2o Permit No. 77-25 Permit No. 77-38 Permit No. 77-39 Permit No. 77-41 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/la Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 9-14,17,18,20)W4-3 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany MAY I 6 i984 AlasKa Oil ~-% g~:;s Cons, Commission ~ -' STATE OF ALASKA ~---, ALASt.. OILAND GAS CONSERVATION ~:;¢IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ Water Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-41 3. Address 8. APl Number P.O. Box 1003607 Anchorage, Alaska 99510 50-029-20261 4. Location of well at surface 9. Unit or Lease Name 407'N & 274'E of SW cr, Sec. 1, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1245'S & 1583'E of NW cr, Sec. 12, T10N, R15E~ UM DS 9-20 At Total Depth 11. Field and Pool 1370'S & 1624'E of NW cr, Sec. 12, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 54' RKBI ADL 28327 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 12/28/77 1/12/78 1/19/78 (2/14/78 Perf'd)I -- feet MSLI 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9685'MD,9271'TVD 9612'MD,9201'TVD YESXE] NO []I 2200 feet MD Approx. ]900' 22. Type Electric or Other Logs Run SP/DIL, BHC, Caliper/GR, FDC/Caliper/GR~ CNL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE -TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# Weld H-40 Surf. 101' 30" 258 sx Arc¢~.~¢~ TI 13-3/8" 72# Butt N-80 Surf. 2683' 17~" 4200 sx Arc~p~ ~m~ 9-5/8" 47# Butt N-80 Surf. 9662' 12~" ]000 ~× C~.~ c. & S00-95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) '9424-9454' MD (30') 8792-9033' TVD 5~" 9079' 8955' *'9188-9202' MD (14') *'9216-9250' MD (34') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9361-9373' MD (12') DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9329-9333' MD (4') 9277-9317' MD (40') *New perfs shot 2/30/84 w/4 spf. **New perfs shot 4/06/84 w/4 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/13/78 Future Injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO N/A TEST PERIOD I~ . ... OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 0il & 6,% Cons. Commission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 9150' MD 9497' MD TRUE VERT. DEPTH 8755 ' TVD 9090' TVD 9116' TVD 30. 9524' MD FORMATION TESTS Include interval tested, pressure data, al fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" ARCO Alaska, In¢ Prudhoe Bay ~:h~lneering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 9, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-14 DS 9-17 DS 9-18 DS 9-20 Permit No. 77-25 Permit No. 77-38 Permit No. 77-39 Permit No. 77-41 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/la Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 9-14,17,18,20)W1-3 ARC(', Alaska, lnc, is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA .- ALASKA ~. _ AND GAS CONSERVATION CC ,VIISSION SUNDRY NOTICES AND REPORTS oN WELLS DRILLING WELL [] COMPLETED WE!L~ [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 407'N & 274'E of SW cr Sec. 1245'S & 1583'E of NW cr Sec. 1370'S & 1624'E of NW cr Sec. 5. Elevation in feet (indicate KB, DF, etc.) 54' RKB 1, T10N, R15E, UM 12, T10N, R15E, UM 12, T10N, R15E, UM 6. Lease Designation and Serial No. ADL 28327 7. Permit No. 77-41 8. APl Number 50- 029-20261 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations X~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 4/6/84. RU perf unit, pressure tested equipment. RIH with gun #1, flowed well, shot 9230-9250' MD 4 spf (Ref: BHCS 1/11/78), shut in well, POH, all shots fired. RIH with gun #2, flowed well, shot 9216-9230' MD 4 spf, shut in well, POH, all shots fired. RIH with gun #3, flowed well, shot 9188-9.202' MD 4 spf, shut in well, POH, all shots fired. RD. Secured well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .... Title Reg'i°nal ~,ngineer The space below for Commission use Conditions of Approval, if any: Approyed by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office B?~--360 Anchorage, .a 99510 Telephone 907 277 5637 April 26, 1984 Reference' ARCO Cased Hole Finals /- D.S. 1-25J 3-18-84 / PFC/GR D.S. 3-19f 4-7-84 x~' Collar/Perf D.S. 3-22J 4-7-84 ~ Collar/Perf Log D.S. 3-23~'~-4-7-84'''' Collar/Perf Log D.S. 5-9 .... ~' 4-8-84-/~ CFS/Temp Survey D.S. 7-16~ 3-10-84/~ EPL D.S. 9-14'''~ 4-6-84~~/~ Collar/Perf Log D.S. 9-17"' 4-6-84/~.~ Collar/Perf Log D.S 9-20~-~4-6-84/' Collar/Perf Log D.S. 9-21/~ 1-11-84~ ACBL/VDL/Signature/GR D S. 9-23~ 3-8-84/' ACBL/VDL/Signature/GR D S. 9-25~ 4-2-84~ 'Epilog/Sandstone Analysis D S. 12-26~..2-19-84~ ACBL/VDL/Signature/GR D S. 12-27~3-6-84 / ACBL/VDL/Signature/GR D S. 12-28~ 3-28-84 ~ ACBL/VDL/Signature/GR D S. 12-28~ 3-30-84 Collar Log (used to cut tubing) ---D S. 13-11 4-4-84~ Collar/Perf Log ~_D S. 13-11 4-4-84/~ Diff Temp 5" DA Run ALL 5" GO Run 1 5" GO Run ALL 5'i GO Run 3 5" GO Run 1 5" Sch Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" DA Run 1 5" DA 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" GO Run 1 5" GO R~n 1 5" GO ~-. s. 13-98 iD S 13-98 D S 13-98 D S 13-98 ID S 13-98 ! D S 13-98 I D S 13-98 ~D S 13-98 ~}D S. 13-98 D S. 1'3-98 5-8-83 / Epilog/Carbon-Oxygen 5-pass overlay5 3-16-84/~ CPL/GST/DIL (3 runs) w/listing 5 no date"' Epilog/overlay avg. CO, SI/CA, SW 5 11-12-83'" Epilog/Carbon-Oxygen 6-pass overlay5 no date ~ 2-13-84' 2-19-84~ 2-18-84' 3-30-84 ' 2-14-84" 2-16-84 ' DA Sch DA DA Epilog/Compare Induction Curves 5 DA Epilog/Carbon-Oxygen 5-pass overlay5 DA GST Inelastic & Stations Run 3 5" Sch GST Capture & Activiation Run 3 5" Sch CH DIL Run 11 5" Sch CH CNL Run 4 5" Shc CH DIL Run 10 5" Sch ~ 13-98 · D.S// 14-32~ 4-1-84/~ Collar/Perf Log Run 1 5" GO S. 16-5 ~ 3-10-84/' Completion Record Run 2 5" Sch ~Please sign and return the attached copy as receipt of data. Prudhoe Bay Well Files Have a Nice Day! DISTRIBUTION Mobil Mobil E & P Phillips Kelly McFarland ATO-1429F Chevron D&M Trans. #171 Dallas Drilling Ext. Exploration Exxon R& D Getty Carolyn Smith Sohio Marathon State of Alaska ARCO Alaska, Inc Prudhoe Bay c,,=,neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 16, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-16 DS 9-20 Permit No. 77-37 Permit No. 77-41. Enclosed are Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/WT/la Enclosures cc: SOHIO Alaska Petroleum Co. File 100.0 MAR 2 ~aska Oil & Gas Cons. Commission An~J~,orage ARCO Alaska, Inc, la a Subsidiary of AtlanticRIchfleldCompany ~- STATE OF ALASKA --~' ALAS~¢' . ,)IL AND GAS CONSERVATION ,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILXE] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-~] 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or Lease Name 407' N & 274' E of SW cr, Sec. 1, T10N, R15E, UM (Surface) Prudh~e B~y At Top Producing Interval 10. Well Number 1245' S & 1583' E of NW cr, Sec. 12, T10N, R15E, UM (Top Prod) D.q At Total Depth 11. Field and Pool 1370' S & 1624' E of NW cr. Sec. 12. TION. R15E. UM (TD~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 54' RKB AD:' 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/28/77 1/12/78 1/19/78 (2/14/78 Perf'd)I -- feet MSL 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9685'MD 9271'TVD 9612'MD 9201'TVD YES [] NO [] 2200 feet MDI Approx. 1900' 22. Type Electric or Other Logs Run SP/DIL, BHC, Caliper/GR, FDC/Caliper/OR, CNL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94f~ H40 Surf. 101 ' 30" 13-3/8" 72# N80 Surf. 2683' 17~" 9-5/8" 47fA ' NS0 Surf. 9662 ' 12~" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) '9434- 9454'MD (20') 9017-9033'TVD 5½" 9079' 8955' '9424- 9434' MD (20') 9109-9017 'TVD 9361-9373'MD (12') 8958-8968'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9329-9333'MD (4') 9028-9032'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9277-9317'MD (40') 8877-8916'TVD N/A *New perfs shot 2/30/84 w/4 spf. 27. ' PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/13/78 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 3/4/84 4.0 hrs. TEST PERIOD ~- 464 1876 412 35°I 4043 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1435 375 24-HOUR RATE I1~ 2784 11,256 2472 31.7° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ^l.~ska. 0ii & 0~.s Cons. O0mrnis;ion Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~ ~/~ Title Regional Engineer INSTRUCTIONS General: This 'form 'is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Im Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 16, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-16 DS 9-20 DS 12-12 Permit No. 77-37 Permit No. 77-41 Permit No. 81-83 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, DFS/WT/la Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchl'leldCompany STATE OF ALASKA ALASK, .)IL AND GAS CONSERVATION C vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE-"LLX~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-41 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20261 OTHER [] 4. Location of Well 407' N & 274' E of SW cr, Sec. 1, T10N,R15E,UM(Surface) 1245' S & 1583' E of NW cr, Sec. 12, T10N,R15E,UM(Top Prod) 1370' S & 1624' E of NW cr, Sec. 12, T10N,R15E,UM(TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 54' RKB I ADL 28327 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-20 12. 1 1. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate BOx To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Rroposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 2/20/84. RU perf uni't, pressure tested equipment. RIH with gun #1, flowed well, shot 9435-9455' MD (Ref: BHCS 1/11/78), shut in well, POH, all shots fired. RIH with gun #2, flowed well, shot 9425-9435' MD 4 spf, shut in well, POH, all shots fired. RD. Secured well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~//j~/~~/_~ Regional Engineer Signed .... _ _ _ ,, _ _ Title ' The space below for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date .............. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Prudhoe Bay E-r, gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 19, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 Permit No. 75-76 DS 9-12 DS 9-2 Permit No. 76-16 DS 9-13 DS 9-3 Permit No. 76-35 DS 9-14 DS 9-4 Permit No. 76-40 DS 9-15 DS 9-5 Permit No. 76-47 DS 9-16 DS 9-6 Permit No. 76-48 DS 9-17 DS 9-7 Permit No. 76-58 DS 9-18 DS 9-8 Permit No~ 76-70 DS 9-19 DS 9-11 Permit No. 76-84 DS 9-20 Permit No. 77-7 Permit No. 77-8 Permit No. 77-25 Permit No. 77-36 Permit No. 77-37 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File PI(DS as above)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfleldCompany STATE OF ALASKA ALASK,, .)IL AND GAS CONSERVATION (. ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-41 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20261 4. Location of W'ell 407'N & 274'E of SW cr Sec. 1, T10N, R15E, UM 1245'S & 1583'E of NW cr Sec. 12, T10N, R15E, UM 1370'S & 1624'E of NW cr Sec. 12, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) / 6. Lease Designation and Serial No. 54' RKB ~ ADL 28327 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number DS 9-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] {Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add Perforations on DS 9-20 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9188-9202' MD 9216-9250' MD Ref: BHCS 1/11/'78 Subseanent Work Beported ,.,j_~ on Fo;fa iqo./~ ;D~te& ~9_/ ~ Alaska 0il & Gas CorlS. CoJnmisston 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ......... _ ~ Title Regional Engineer The space below for Commission use Date Conditions of APproval, if any: BY H~,,~R¥ ~,~!. KIIGLEil Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Prudhoe Bay C.~lineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 14, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 9-16 DS 9-20 Permit No. 77-37 Permit No. 77-41 Dear Mr. Chatterton: Attached are Intention Sundry Notices for work to be performed on the above-mentioned drill sites. Sincerely, Donald F. Scheve Regional Engineer DFS: la cc: J. C. Dethlefs J. R. Schuyler D. Smiley Sohio Alaska Petroleum Co. Well File, DS 12-19 & 20 ARCO Alaska, Inc, Is a Subsidiary of AtlanflcRIchfleldCompany ...... STATE OF ALASKA -- ALASK/-, _.,IL AND GAS CONSERVATION C .,1MISSION SUNDRY NOTICE, S AND RE, la'ORT$ ON WELLS 1. DRILLING WELL [] COMPLETED WFLL:~ OTHER [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4, Location of Well 407'N & 274'E of SW or, Sec. l, TZON, R15E, DM (Surface) 1245'S & 1583'E of NW cr, Sec. 12, T10N, R15E, UM (Top Prod) 1370'S & 1624'E of NW cr: Sec. iL2: T10N; R15E; UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' _~ ADL 28327 7. Permit No. 77-41 8. APl Number 50-029-20261 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate X~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS !)-20 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Interval:: Zone 2A 9425-9455' MD Ref: BHCS/GR 1-11-78 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Regional Engineer Signed ~ ~~',,/---~, ~ ,~,~,~'~. Title The space below for Commission use Conditions of APproval, if any: Approved by. Approved Cop'/' Returned COMMISSIONER By Order of the Commission Form 10-403 Rev, 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company North Ala:" istrict Post Office .,ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations En§ineer April 3, 1981 Reference: ARCO Cased Hole Finals D.S.4-4 Pe'rf & Collar Log Run 1 2" D.S.13-3 Perf & Collar Log Run 7 5" " . TDT Run 1 5" g~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #163 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLi-' SOHIO MARATHON CHEVRON ARCO Od and Gas Company is a Division of Allanl~cR~chfieldComp,]ny ARCO Oil and Gas Company North AI~~-'-'~' Oistrict Post Off ,ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 6, 1981 Reference: ARCO Magnetic Tapes & Listings D.S. 1-9 1731/81 _ (:~)~' S. 9-20 . 2/19/81 D.S. 12-5 12/20/80 D.S. 16-3 2/20/81 Tape #61273 Tape #61354 Tape #61275 Tape #61425 ~~Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #112 DISTRIBUTION' NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany EXXON MOBIL GETTY .. PHILLIPS M/qr~ l ]. i!i'Sjd,.~. ,.~ SOH I 0 ~/~ska 0ii ¢, ~as Oons. 6°mrnission MARAT H ON An(;hor~e CHEVRON Anchor::.. ,!,~ ~;k?. $9510 Tclephon.:~ ~j'.?7 277t,-r~-'~.~ ~ August 30, 1979 Reference' Enclosed are Cased H01e Logs for ARCO wells' D.S. 1-6 7-9-79 Spinner D.S. 2-7 5-20-79 Spinner ~.,$~.~=~l.:~ 6- 3- 79 Spinner ~!i:'~j~i~ ~ 6-17-79 Spinner D.S. 13-1 8-5-79 Spinner D.S. ].3-2 8-2-79 Spinner D.S. 14-4 8-1-79 Spinner' D.S. 5-16 6-16-79 Spinner Floxmneter D.S.. 7-2 6-28-79 Spi]mer Flox~neter [~13 7-7-79 Compensated NeUtron GR ase sign and return the attached cop)' as receipt of data. Ve~/ truly yours, K. J. Sahlstrom NoTth Engineering TI~/INS~XII TI'AI, it 3 0 2 DISTRIB[H'ION North Geology l!x xon Dr i 11 lng blob i ] Eng. bfanager Getty R & I) So]~J.o Geology ~laratt~on State of Alaska PhJ~llips I) & M Chevron Post O,Uice ~.~_O~x 3~0 Anchora.'.5 ska 995i 0 Telephone ted7 2;"7 5637 August 10, 1979 Reference- Enclosed are BHP Buildup and Flow Profile Surveys/ Pressure Buildup Test Analysis Results for the following ARCO wells' \ D.S. 9-6 11/29/78 /~/~ ,~ D.S. 9-15 10/22/78 / D.S.' 9-1 5/13/79 ! P.S. 9-1~.10/20/7g s. 9- s Please sign ~ retu~ the attached copy as receipt of data. ~ ' Very truly yours, R. A. Bell/nger North Engineering . ~ ,,:, ~ - RFS F:NC, - l--i. ENG - ..... ~-ENG 3 GEO[ -- STAT T~:C STAT T~C ", FILF: TRAN~ffTTAL # 261 DISTRIBU3'ION North Geology Kxxon. Dr i 11 ing Mob i 1 Eng. Manager Getty R & D Sohio Geology Marathon State of Alaska Phillii~s D & M Chevron Post OffJo~ox :380 Anch or--~ 'askn 395'I 0 Teleph .... ) 997 277 5637 August 9, 1979 COMM ~ COMM cOMM I E. NG 2 ENG 1 GEOL ' CEC)L / .... s T TEC "T,%T Reference' ~closed are Cased Hole Logs of the following ~CO wells' 7/31/79 ~~ 6/24/79 D.S. 5-16 6/25/79 NGI-15 6/30/79 Spinner Survey Run 1 5" Hydro Log Run 1 5" Continuous Flow Survey 5" 'Run 1 Continuous Flow Survey 5'.' Run 1 CNL 2"& 5" Please sign~f~ return the attached receipt copy as of data. ~/ Very t}~ly yours, R. A. Bellinger North Engineering TRANSMITTAL # 259 DISTRIB[fi'ION North Geology Drilling F~g. Manager R&D Geology State of Alaska ]:~xxon Mob i 1 Getty Sohio ~Iarathon Phillips Chevron Pos[ Office Box 35.0 ' An chore, g e, '"~'",09510 Telepho~'~e ,- .,;,, 7 5837 March 16, 1979 Reference' Enclosed are the following cased hole logs' DS 4-2''~'' Diff. Temp. 9/~5/78 DS 4-12v" CCL 12/01/78 ~~ Spinner 12/ 3/78 DS 9-13~- Cont-. Flow 6/ 3/78 DS 14-3 ~'" CNL 11/28/78 DS 7-6 -~' CBL/VDL 11/20/78 DS 9-9 ~' Diff. Temp. 9/18/78 DS 9-16-~/ Cont. Flow 6/ 2/78 DS 9-19'~ Cont. Flow 10/24/78 DS 3-7~ Cont. Flow 8/29/78 Please sign and return the copy as receipt of data. ~'~ '¢?~/~¥ Sincerely, ~× V.G. Reimers North Engineering TR&NSMITTAL #99 North Geology Drilling ..., F~g. Manager R&D Geology State o~ Alaska DISTRIBUTION f!x~orr Sohio Mobil Marathon Phillips Ci~evron Getty Nor~.h ,a. laska "~' Post Office l-~___...,~,d0 Ancl'~o,"age, Alaska 99510 Yelephone 907 277 5637 February/ 16, 1979 Reference' Enclosed are' the following Pressure Surveys' DS'l-18 DS 4-12 DS 4-13 DS 6-3 DS 6-4 DS 6-5 DS 6-7 DS 6-8 DS 7-2 DS 7-4 DS 7-5 ,. DS 9-20 Static.Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey static Survey Static Survey Transient Survey 12/26/78 12/1/7.8 12/3/78 11/23/78 11/23/78 12/6/78 12/10/78 12/11/78 12/16/78 12/19/78 12/21/78 ]2/4/78 Please sign and return the copy as :receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL # 73 DISTRIBUTION North Geology Drilling Eng. Manager R & D Geology State of Alaska D & M ,, ~ ,'ri .41ask,i ()il ~ I;.:,,~ 'Exxon Sohio Hobil Harathon Phillips Chevron Ge~y Dece~P.~er 5, ~78 [~. Donov~n Jackson Atlantic P~d~ieid Co. P.O. B~-x 360 ~mcb~rage ~ Alaska 99510 Dear Our trau~itta! records sh~.~ tbmt ~e did not receive copies cf fo!!~?~tng well logs fr~u P~udhoe Bay Unit %.~lls~ at the tis?e original !c~3 transmittals to~.k place. Please tr~.'~it tl%m fol!c~ing logs at youa- early c~v~ce. PBU DS 5-10 Cc~s2. Neu'krcn Form~.ti~ Density 5" sepia PBU DS 5-12 Du~.ILndu ~cui~ Lat~_ro!cg PBU DS 9-12 C~7p. Fo~ation E~_nsi~ ~ Fo!~mti~ 5'~' sepia 5~' ~"~.,~ l~'~e prh~t you for your at ~ten~ ticn to ~:~is ~at ~ter. SLncerely yo'ars, Levor~ Petroleum C~olog~t AtlanticRtchfieidCompany i',~orth American Producing Division North Alaska~rict Post Office L Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 9-13 Permit No. 77-8 DS 9-14 Permit No. 77-25 DS 9-15 Permit No. 77-36 DS 9-16 Permit No. 77-37 DS 9-17 Permit No. 77-38 DS 9-18 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Dear Sir: Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB: lr Attachments SUBMIT IN D~. ~,CATE* STATE OF ALASKA ~s~ st ru('[ions on OIL AND GAS CONSERVATION COMMITTEE ii · I i i i i i WEL~ cOMPLETION OR RECOMPLETION REPORT AND LOG* ' la. TYPE OF WELL: 'on, ~ ~ ~ " '~ ' ' W ELL ~ ELL DR Y Other b. TYPE OF COMPLE~ON: W~:LL OV~a rx n.~CK n~sva. Other Perforated 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. BoX 360 Anrhorm~a_ Almgkm g.qqlll 4. LOCATION OF wELL(Report l~ation cIearly~n~ in accordance with any State requirements)* At su~ace 407'N & 274'E of SW cr Sec. 1, T~0N, R15E, ~ At top prod. interval reported below At total dep~451S & 1583'E of ~ cr Sec. 12, TiON, R.15E, ~ 1370'S & 1624'E of NW cr Sec. 12, TiON, R15E, UM 5. API NU3RJSi1UCAL CODE 50-029-20261 6. LEASE DESIGNATION /MND SERIAL NO. ADL 28327 ~, IF INDIA.N, ALLOTTEE OR TRIBE NA/%IE 8. UNiT,FA/laM OR LEASE NAME Pr,,tthmo. Bay Unit 9. Wt~LL NO. D,q 0-20 (21.-12-10-15) ,0. =~E~ ~D PooL, o= wi~gFudhoe P ru___jho e_~B~y_F i e] d.-0j 1 _po~ 1 11. SEC., T., tL, M., (BOTTOM HOL~' OLU Ec~rlVE) Sec. 12, TiON, R15E, UM 12. P~II/VIIT NO. 77-41 13. DATE SPUDDED 12-28-77 la. TOTAL DEPTH, MD & TVD IlS, PLUG, B~C'K MD & TVD~0. IF lV~JLTIPLIg COiVLPL., I 21. / / I-IOW 1VI2kNY* I ROTARY TOOLg 9685'MD 9271'TVD / 9612'MD 9201' TVD[ Single 22. PRODUCING INTERVAL(S). OF T~.IS CO1VIPL~TION--TO~, BOTTOM, NAME (MD AND TVD)* I14' DATE T'D' RF-JkCttED [~5' DATE COMF(~L~l~)~ABAN-D'1-12-78 1-19-78 2-14-78) [16' ELEVATIONS 'DF' RKB' I~T' GR' ETC)*II?' ELEV' CAS1NGttEAD54' RKB 9188'MD 8792'TVD 9523'MD 9115'TVD Top Sadlerochit Base 8ajlerochit INTERVALS I)R[LI,ED BY All I cA,,,~ TOOLS ,2'3. %VAS DIRECTIONAL SUIIVEY MADE 1 24. TI~PE ELECTRIC AND OTHEI{ LOGS RUN ,, 8P/DIL,BHC,:CALIP,,ER/GR, F~C/,CAnZPER/GR, CNL/CCL../GR ~' CASING RECORD (Report all strings set in w~ll) 20" 94#Welded 13-3/8" [72# Butt [ N-8012683' _ 0-5/8" A7# a,,tt [ N-S01q662' : 12-1/J"' I Isoo-gsi ....... 26. LINER RECO~ 2~'." PERFORATIONS OP~ ~O PRODUC~ON (interval, size and number) } 9361'-9373' 9329'-9333' ' · "" 927.7'-9317' w/4 shots per ft 30. PRODUCTION CISM~,NTING RECOILI) I A?,'IOUN'F PULLED 258 sx Arcticset II cmF 4200 sx Arcticset cmt 1000 8x Class G. cm~ / 27. TUBING SIZE DEPTI{ SET (2iD) ~ PACiiE~ SET 5-1/2" , 9079' ] 8955' ACID, Si:OT, F;~A2';'I ~}~ C~'~SENT SQUE'J~Z~, ETC. DATE FIRST PI~ODUCTION I PI~ODUCTION lX¢EI[iO'D (Flowii~g, ga3 11£~, primping--size and type of pump) ]V~;I;;LI.. ~F[ATUS IProducing or ~3-78 [ ,Flowing I Producing D~TZ OF T~ST, [~OUES TEST~ [C}!OXE SiZE [PI%OD'I¢ FO.~ OI~BBL. '~-~S~AiCF. 5VATE~BBL. '[ / I ]TE3T FLOW,[>~S8. TUBING 1}CASUN O PRESSUREt~-~AT~ [[CALC~T~OI~BBL. IGAS--'rvICF' lW~-BBL[ llO1L GRAVITY-~I' (CORR.) t TES'F WITNESSED BY _ RainjaaEed .... ~3.'I hereby certify that the foretming and attached information is complete and correct as determined from all-available records / // -- *(See Instructions and Spaces [or Additio.a[ Data on Reverse Side) INSTRUCTIONS General: This form is designed for ~ubrn~tting a complete and correct well complet,on report and log on all types of lands and leases in Alaska_ Item: 16: Indicate which elevation is used as reference (where not otherwise s¼ovvn) for depth measure- merits g~ven ~n ether spaces on this for~ and in any att,3ct~r~,~enls. Items 20, and 22:: If this well is completed for separatc prcduction from more than one interval zone (multiple completion), so state ~n ~tem 20, and ~n ~te,~ 27 show the prcduc~r~g interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). i 34. SUMMAIiY OF FO~MATION T~S'I"~.S 1N('LUI)IN(; INTERVAL TESTED, I~}tE'-%S'URE DATA ~ ~C'~VERI~ OF OIL. GAS, 35. G~GIC MARK~ WATER AND MUD NAMg "MfiAS. ~t ~u~ V~T. , ' ...... ,, , ~ ~ ~1~ ,~r , r ~ ~ ,1' aB. CORE DATA. Aq'I'ACII iIRIEF' D~&RI~i~6~S O? LITIIOLOGY. POROSITY, FRAc~RF~. A~P~N* ~t~ ~ND I)ETECTED ~IIOWS OP OIL. G~S OR WA~{. i i , l, 111 i '1 ~ i , ,, ,.an ~ c ;-,.c):iield Corn party North Arnerir :}ducin9 Division North Alaska ..... ¢ict Post Office Box 380 ..... ,.~ ~, Ar~chorage, Alaska 99510 5~e 29, 1978 ~iclosed are prints of the following Ope]~oe Logs' D.S. #I-15 DIL Z" BCS 2" D.S. #2-11 DIL 2" D.S. #4-12 DIL 2" BCS 2" D.S. #5-7 DIE 5" D.'S. #5-12 DIL 2" D.S. ~5-13 DIL 2" D.S. #9-19 DIL 2" BCS 2" ~..~ ~D.S, 9-20 . ~ Please sign and return attached copy of tr~smittal as receipt of data. Very truly yours, ?- .....r~¢erations Engineering Transmittal.#833 Alaska District Eng_inec-~-' TRANSMITTAL ['o' Frolll ' J. A. Rochon/R. A. Logue herewith are the following for the subject well' ~//~)~/~ J/fi/- !~un No. Scale Xerox Sepia . . Acid or Fracture Treatx~ent Log · BHP Buildup & Flow Profile Sm~ey Borehole Geometry Log Carbon Oxygen Log Casing Collar Log Cement Bon.cI Log Compensated Neutron Log - ~ased Hole Core Analysis - Interval Core No. Core Description (a~iC) - Intm~al Core Description (Cony.) - Core No. 'Directional Survey- - Single Shot Engineering Production Log Fluid Analysis .... ~-~ Fluid Density Gamma Ray Location Plat Monthly Well Test Data Mud Log Perforating Record State Reservoir Pressure Report 'Surveillance Reports Temperature Log Transient Pressure Surveys TVD Logs -- Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Formation Density Log - Borehole Compensated Sonic Log - Porosity Log t-receipt Acknowledged By: pl. ease Return Receipt To: Ms. R. A. Logue Atlantic Richfield Company P. O. Box. 360 Anchorage, Alaska 99510 Date' BL Line ,AtlanticJ:{ichfieldCompany North America.~.n Producing Division North Ala.'~ 'trict Post Offic~ ,~ 360 Anchorage, Alaska 995'10 Telephone 907 277 5637 February 28, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 POrcupine Drive Anchorage, Alaska 99501 Subject- D.S. 1-5 (23-9-10-15) Permit No. 70-40 D.S. 2-2 (23-30'11-15) Permit No. 70-35 D.S. 9-17 (43-1-10-15) Permit No. 77-38 D.S. 9-18 (43-2-10-15) Permit No. 77-39 D.S. 9-19 (34-12-10-15) Permit No. 77-40 ~'~'~-~1 12-10-15)Permit No 77-41 Dear Si r' Enclosed please find our Sundry Notice of-Subsequent Report detailing the work done on the above-mentioned wells. Very truly yours, Frank M. Brown D~strict Drilling Eng~nee~ /am EncloSure RECEIVED ,MAR - 2 1978 Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & °'Subse~luent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20261 6. LEASE DESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~' O,L I~1 GAS I--1 WELL I,.~.1 WELL L.-J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360; Anchorage, AK 99510 DS 9-20 (21-12-10-15) 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL At surface 407'N & 274'E of SW cr Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 1, TION, R15E, UM 14. Check Appropriate Box To Indicate Nature of Notice, Re Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, TION, R15E, UM 12- PERMIT NO. 77-41 )ort, or Other Data NOTICE OF INTENTION TO; SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SNOOTING ORACIDIZlNG ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Perforate (Other) (NOTE.' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations @ 0730 hrs 2/13/78. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd. intervals 9361'-9373', 9329'-9333', 9277'-9317' w/4 shots per ft. All perf'd depths referenced to open hole BHCS log of 1/11/78. Ran Amerada press bombs. Flowed well. Ran & set ball valve. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept @ 2130 hrs 2/14/78. -. ~6. I hereby certify that the foregoing is true and correct ,¢ T,TL~District Drillin9 Engineer DATE 2/28/78 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY= TITLE DATE See Instructions On Reverse Side North Alaska District Engineering TRANSMITTAL To' · - . From' J. A. Rochon/D. R. Jackson Date' Febriary 14,1977 . Well Name' D.$. 9-20 · Transmitted herewith are the following for the subject well' Run No. Scale Xerox BHC Sonic/Caliper Log --i-----BHC Sonic/Caliper - Gamma Ray Log 5P' BHC Sonic/Gamma Ray Log' Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Co~p?sated Neutron-Formation Densit~~ Core Analysis - Interval Core No. Core Description (SWC) - Interval, \ Core Description (Cony.) - Core No. Directional SurVey - Gyro Single Shot b~ltishot Drill Stem Test - Test No. baal Induction Laterolog Formation Density Log Formation Density Log/Gam~a Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog b~dlog - Interval San'~le Log (A.R. C6.') - Intenrai Synergetic Log T~rD-DIL TVD-Porosity Log 1 \ Sepia BL Line t ea I ea i ea J ea Receipt Acknowledged For: Date' Attn' ~,.,~. :Pono'van Jad:son Please retmn receipt to: Atl~tic ~chfield Co, any North Maska Engineering P. O. Box 560 ~chorage, Alaska 99510 #776 North Alaska District ]h~gineerS.ng T RAN S ?.i I TTAL ' · . · · . Sepia BL Line... · : . ..... r-; : '- ~;. . -.. Transmitted herewith are the f611owing foil the subject'we!l"/f~/~~. ... .. - . "- ' Scale' Xero~ Run No.. .. . BHC Sonic/Caliper Log ' '-. ..... BHC Sonic/Calipe9 - Gam,,na'Ray Log ' BHC Sonic/Gamma P~y Log --'~'-- Caliper/CCL .' :. Cement Bond Lbg/VDL "' -----Co.npensated Formation Density L~g' --. Compensated Neutron-Formation Dens%ty ... Compensated Neutron Log ....... Core Analysis - Interv. al · ' Core' No. · . . (:ore Description (SWC) - Interval Core Description (Cony.) - Core No. .:. Directional Survey..- Gyro' ... Single Shot ·. ~ltishot Drill Stem Test.- ;fcst No. .- ......... · Paal Induction Laterolog. ... Fm~atio~ Density Log ' ............. Formation Density Log/Gamma Ray. ........... Gamma Ray/CCL ........... _ Laterolog Location Plat . '' ........... Microlog ............ Nudlog - Interval Sample Log (A.R. C6.) - Interv'dl Synergetic Log . ]¥D-DIL --- · 'lTD-Porosity Log--'.' liccdipt Acknojfledged For' I)a t e ' l~].c:aso retuim receipt to' Attn' Atlantic RlcltfJ. eld Company North Alaska Engineering P_ O. Box 360 dcRichfieldCompany North Ameri~roducing Division North Aiask ;ici Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 31, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 9-20 (21-12-10-15) Permit No. 77-41 DS 1-14 (21-7-10-15) Permit No. 77-77 Dear Sir- Enclosed please fi nd Drilling History and well s. a Completion Report along with the Multishot Survey for the above-mentioned Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure -- SUBMIT IN .'~ ,~" .'E STATE OF ALASKA ....... thor m- st ruc[l(~lls ol~ revez >'e side,, OIL AND GAS CONSERVATION COMMITTEE ii i i i WELk cOMPLETION OR RECOMPLETION REPORT AND LOG* I I II ~ Il n ~. TYPE OF WELL: on, ~ ~s ~ WELl. WELL ~ DRY Other h. TYPE OF COMPLE~ON: W E I.I. OV ER E N BACK RESV R. Other __ NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Al( 99510 4. LOC^TraX Or WELL (Report location clearly and in accordance with any State requirements)* At surface 407'N & 274'E of SW cr Sec. 1, T10N, R15E, UM At top prod. interval reported below 1245'S~p&~~t tot~ 1583'E of NW cr Sec. 12, T10N, R15E, UM 1370'S & 1624'E of NW cr Sec. 12, T10N, R15E, UM 5. API NU~ZI~I~ICAL CODE 50-029-20261 6. LF~ASE DF-,S1GNATiON A_ND SEi~TLAL NO. ADL 28327 · 7. IF INDiA.N, A.L, LOT'FE~ Oll. TttJB~ i'4A.RLlil 8. UNIT,FA2~M Oi~ L~k~E NAME Prudhoe Bay Unit ' DS 9-20 ~?1-12-10-15 ) 0.~. ' ~mLZ.:~'~ooL, o~. wqupc ~T Fruu~oe Bay pi e i fl Prudhoe 0i~ Pool 11. SEC., T., R., M., (}3OTTOM HOI-~ OBO EiCTIVE) Sec. 12, T10N, R15E, UM 12. PE~NiIT NO. 77-41 E~EVATIONS tDF. RKB, t{'1', GR, ~]TC)* 17. 91LEV. CAS1NGtlE/~D 12/28/77 1/12/78 1/19/78 "KB 9685'i~D 9271'TVD P~ODUCINO !N~RVAL(S), OF ~IS COMP~TION--TO~P, BOSOM, NAME (MD AND ~)' ,23. %VAS DIRECTIONAL ~ SUI~VEY MADE Top Sadlerochit 9188'MD 8792'TVD Base Sadlerochit 9523'MD 9115'TVD 24.TY?E ELECTRIC A_ND OTH1Et~ LOGS RUN SP/DIL, BHC/CALIPER/GR, FDC/CALIPER/GR, CNL/CCL/GR _ ~i' ' - cASiNG I~ECdRD (ae~ort aU strings set in well) C~S~4G SIZE %VEZGHT, LB,FT. ~ G~ADg I DEPTH SET (MD) HOLE SIZE ] CLMLN'rlNG IIECOt~ ?~).qOUN'T PULLED 20" 94~ Welded[ H-40 [ 1'01''~ ' 30" 258 sx Arcticset II cmt 13-3/8" 72~'Butt' / a-8o I 26a ' ' ~1 1 -1/2 14200 sx Arct~cset cmt., 9'5/,8" , 47~ Butt ] N'-80~ 9662' 12-1/4" 11000 sx Class a cmt . .... 1soo-9 , I ' , ...... 5-1/2" 9079' ' 8955; 28. PERFOrATiONS OP~ T6 PRODU~ON (Znterval, size and number) 2~ ACID, SlgOT. Fi;AT'I gI{E, C~AENT S~UZI,?ZP], ETC. N/A 30, PI~ODUCTION DATE FIRST Pli©DUCTIOlXI N/^ DATE OF TEST, FLO'W, TUBING 31. DISPOSITION OF P~ODUCTION MILI[i©:D (Piowi~g, ~;85 lifa, pamping~size and type of pump, .. CIiOXE SiZE [PP, OD'N FOR OI~EBL. ads (Soid, used )'or ruer, vented, etc.) IV, I>]LI., [{'I'ATUS ( Producing or G,KS--R'iC*Ic. WATEIt--I3BL. ] CiAS-OII~ ii.Ti'lO I 1, W~k~--EBL. ] OIL GRAVITY-~I (CORR.) I 1 ITE 8'1' WITNESSED 32. LIST OF ATTACHMENTS Drillin~ History, ~ult~shot Survey 33. I hereby cert~y that the foregoing anti attached ~nformat~on t~ complete and correct as determhmd from alU~vallable rec.rds SIGNED ~L,~~~ TITLEDistrict Dril 1 ing_~e__er D,W~.; ..... *(See Instructions and Spaces [or Additional Data on Reverse Side) 3___.1/!8_ INSTRUCTIONS General: This form is designed for submi'ting a complete and correct ,,,,,,ell completion report and tog on all types of lanJs and leases in Alaska. Item: 16: indicate which elevation is used as reference (wheFe not otherwise shov¥,:~) for depth measure- ments given in ether spaces on this form anc:l in any attach?.~ents Items 20, and 22:: If this well is completed for separ,~tc- production from more than one ~,'~terval zone (multiple completion), so state ~n item 20. and in ite,,~ 22 show the prcJuc~r~..~l interval or intervals, top(s), bottom(s) and name (s) (if any) for only the intervu! re~)orted ir~ iter'~ 30. Submit a separate report (page) on this form, adequately identified, for each add~ior~al interval to be seperately produce.J, show- ing the ack. Jitionat data pertinent to such interval. It®m26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , , 34. SUMMAI{Y OF FORMATION TF~'I'$ IN('LUDIN(; INTERVAL TF_.STED, t'RIg,KSUIZE DATA AND 'RF-,COvERIF~ OF OIL. GAS, 35. G I!2OL,OG I C M ARKKI:k~ WAT,tm2. AND MUD NAMIE 38. CORE DATA, A'I'I'ACII nHIEF D~R~I~.ONs O'~ LITIIOLOGY. POnOmTY. F[IAC~R~. ~D I).~t'ECTEI) SIIOWS OF OIL, GAS DRILLING HISTORY DS 9-20 (21-12-10-15) API 50-029-20261, ADL 28327, Permit No. 77-41 Spudded well @ 1630 hrs 12/28/77. Drld 17-1/2" hole to 2720'. RU & ran 13-3/8" csg w/shoe @ 2683'. Cmtd w/4200 sx Arcticset w/add. Installed & tstd 20" pkoff. Tstd csg. Drld cmt & 10' new form. Tstd form. Drld 12-1/4" hole to 9645' Dropped multishot. Ran SP/DIL, BHC/CALIPER/GR, FDC/CALIPER/GR. Drld to 9685'. RU & ran 9-5/8" csg w/shoe @ 9662', FC @ 9620', upper FO @ 2402', lower FO @ 2522'. Cmtd w/lO00 sx Class G cmt. Did 2nd stage w/300 sx Arcticset cmt. Did Arctic pack job. Rev mud out w/fresh wtr & displ fresh wtr w/CaC12. Ran CNL/CCL/GR. Ran gauge ring & junk bskt. RU & ran 5-1/2" compl assy w/shear sub @ 9079', Baker SAB assy @ 8955', sliding sleeve @ 8835', RQY nipple @ 2200'. Dropped ball & set pkr. Pulled dummy valve. Displ CaC12 w/diesel. NU & tstd xmas tree. Ran CCL/Dummy Gun. Reran dummy valve. RU for long term press tst. Released. rig @ 1230 hrs 1/19/78. A PETROLANE COMPANY REPORT of SUB-$URFmCE D ]RE C T ] D ~I~1 £ SURVEY ATLANTIC RICHFIELD COMPANY #9-20 WELL NAME PRUDHOE BAY LOCATION JOB NUMBER A178 RO196 ' TYPE OF SURVEY MULTI-SHOT DATE 1-16-78 SURVEY BY KEVIN DURLING OFFICE ALASKA .TLANTIC RICHFIELD COMPANY WELL DS 9-20 !AGNETIC MULTISHOT SURVEY []ECLIi1ATION 31 DEGREES EAST ~ADIUS OF CURVATURE METHOD OF COMPUTATION K B FCLEV ~ FT "bf:~PUTED .... FOR-'-'~'A'~T~.~'~fi'WRiPSTOCK BY F M L[NDSEY AHD 'AS~OC[ATE~ ALL CALCULAT!ONS PERFOkMED ~Y ! [~. H ELECTRONIC CO~v, PUTER TRUE )EPTH ANGLE DEPTH SEA DIREC DI STANCE D N DEG, DO6 LEG R E :5 SEVER ITY SECT!ON ANGLE DEG/_iOOFT D!~ ~_C~E D M 5 ..... 5 .... ~ ...... 'b- .............. 510'~ ........ ;-~'~-;'oo .... s47'"-Ob£ ..................... b-;'~'o'"~ ................... r-;co w o.oo 2735 0 45 2734.86 2680.86 534.00E 1~.04 S 17.03 E 24.81 ~ $29 0 45 2828.d5 2774,85 544.00E 16,99 ~ 17,~0 E 26.03 2922 0 45 2921,8~ 2867,84 $51,00E 19.~1 $ 1~.70 E 27.25 3015 0 45 30].4,e3 2960,83 54 ~202 2 15 3201,78 3147,78 52 3295 5 15 3294,57 3240.57 53 3388 8 15 3386,92 ~3~2,92 53 3481 11 30 3478,53 342~,53 54 3574 13 0 3559,41 3515,41 55 S 0 0 0 W 0,000 0,00 S 43 S 43 S 43 S 46 59 59 E__ 0,045 lO,!!. 21 17 E 0,016 24,67 8 57 E 0,139 ~5,90 20 36 E__0,098 27'!.0. 28,29 4.00E 20,64 S 19,60 E 28.46 S 43 31 15 i,OOE .............. 21.5R-S ............... 20.24-E' ............. :' ..... 2'9''81 S 42 46 3.0OE 29,72 5 24.01 E 36.21 S 38 56 5 ~.-OoE ........... ~:.~4 S ......... ~.o.04-'~ ............ 4~.10 s S7 4S 36 7,00E 50.94 S 40.38 E 65,00 S 38 24 19 O,OOE 64,01 S 55.16 E 84.50 ~ ............. E 0,098 E 0,'269 29.67 E 1,330 32,1~. E 3,227 38,20 E 3,226 49,10 E 3,539 64,99 E__1,621 84,3~ 3668 14 15 3660.76 3606.76 549.00~ 75.39 S 71.99 E 106.44 S 42 33 50 E 1,331 3761 16 30 3750.42 3696,42 S49.00E 94,57 S 90.60 E 130,97 S 43 46 23 E 2,419 _}_~.~..~ !9__0 .....3~3~,9_9 ......}7~4.e9. 549,00E ....... 1!$.17 S ....... ]!2.00..E ........ !59,22.._}.._~6_._92 9 E 2.688 4227 21 30 4187,04 4133.04 4320 21 0 4273.72 4219.72 4413 21 0 4360,54 4306,54 ~!.3~ 21 .....30 ...... ~!00,~2 .......40q6.52 _. S48,00E .... 175.97 S49,005 201.55 SSOeCC~ 22~.z+4 $50.00E 244 .~7 ~P~ .... ~ ....0 ~79~5~_439_~.~5 ..... 549.00E ........ 26c,.C2 4786 19 30__4710~Q___.~..,.90 .... S4.7,00~ ......... ~29,42 S ...... 33C_.7~: .... E ........... _~56,5_!___5__~_'.7____3_2 17 E _~ ....... ::.~:.?.?5___E_ ........ 68_,_7__..~4 S 47 32 8 E 105,99 189,04 222.~.! 0,394 0.39~ 289~. 0.000 o.ooo 0,551 480L%~. TRUE DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 D M DEG, DOG LEG S U R E $ SEVER! TY _~IIQ~_. ANGLE D EG / kO_QF T. D_X ~TA~C_g D M 5 5159 19 0 5062.78 5008.78 544.00E 416.32 S 44~.01 E 611.58 S 47 5 59 E 5252 19 45 5150.51 5096.51 S45.00E 438.32 S 469.63 E 642.~0 S 46 58 29 E ~-'~--~6--~0 ..... '~- ..... -5'~'7~97 ....... 5"i'8~',97 ...... S4~";'OOE .............. 2~60',8-1 S ........... 2~'9~79'--~ ............... ~7~,99 S 46 51 ~2 5811 19 15 5676.07 5622.07 S40.OOE 578.86 S 5905 20 0 5764,61 5710,51 539,50E 603,13 S 61~,24 E 863,71 ........................................................... .......... 5091 21 0 5939.11 5885.11 S37.00E 653.43 5184 22 0 6025.64 5971.$4 $36.00E ......... 6~0.d3 5277 23 0 6111.56 6057.56 $36.00E .... 709.62 5370 24 0 6196.85 6142.85 $36.00E 739.02 .%.463 24 0 6281.81 6227.81 535.C07_ 770.41 5557 24 0 .5367.68 6313.68 S35.00E 801.73 5650 24 30 6452.47 6398.47 S35.00E 833.02 S 47 30 13 E S 47 25 7 E 0,000 o.3~ 541.~L. 0~0 0.269 609 .......... 0,816 0.297 664e66 0,368 696,28 0,364 728.30 0.000 760.00 0.368 791,72 0.815 822,91 0.800 0.184 886.24 S 655.41 E 927.62 S 45 13 4 E 1,110 678.69 E 961,32 S 44 54 35 E 721. o ..... E ......... lo .18 .... S-- 4 .... 17 .... E 749.37 E 1070.58 S 43 58 35 E 765.30 E 1105.36 S 43 40 5 E 7i~7.21E 1146,14 S 4~ 22 49 E 918,80 1.086 952.88' 1,075 988,46 1.o7 0,437 1063,34 0,000 110] i~ -' 5743 25 0 6536.93 6482,93 %8~6 25 15 6621.13 6567.13 ~.9~Q.:.25 .... 0 ..... 6706.~24 .... 1023 25 15 6790.44 6736.44 ?116 25 30 6B74.47 6820.~7 ?269 25 45 6958.32 6904,~2 ?302 25 15 7042.26 698~.26 .................................... ?396 25 15 7127.2B 7073,28 ................................... 7489 25 15 7211,39 7157.39 535.00E 564.92 S35.00E ~97.25 S35,00E 929.96 S35,00E 962.?0 - S36.OOE ....... 994.75 S36.00E '-1027.2~ .-_ 536.0C:E 1092.12 · S36, OOL'. 1124.2! S S0"7.54 E 1184.67 S 43 6 21 E 0,538 S ~32.1') E 1223,77 S 42 50 42 E 0,269 S 555.0,'J E 1263,32 S 42 35 53 E 0.266 S ~7'7.73 E 1302.47 S 42 22 6 E 0,269 S 924.52 E 1382.05 S 41 59 9 E 0.269 S 9~C.05 E 1421.87 S 41 49 3 E 0.538 S 97-t.62 E !461.77 S 41 39 30 E 0.000 S 99&J(34 E 1501.25 S 41 30 32 E 0.000 1178.61 1218,07 1257.95 .1297.40 1337,24 1377.45' 1417,47 1497,22 .-2,0 ~.,':^GF~E.T I c ,< L T..I 5H',,, ]' RECORD OF $L:;~V~'ZY ~iE,~..s.._,__D.g__!?.]L_VF....g_T._I Q_A_....L. .......... _~U[~ ....... DR ! F! ................ TQ T."-',L '.L-O.-G'[~iJ'!}:i. Ai!.E ..s. ................... ..C_ .... .L_.D ..... E U R__E._._,5 ' D E_P_T_..H__~.N.~..L E ........... .D..E_.P.T.M ................ _~EA ....... D IREC ................................................................ D_.I ._S..T._A.~ C.. ~ ....... ANGLE DEG/iOOFT ......... D_ ....... ,.'~_ ............................................................... DE..G..,. ............................................. . D. M S ?552 25 0 7295,5~ ......... 7'~]~i-;'59 .... S3-5't"-05'~ ....... i~i'5[~"'35 S 1017.87 E 15~0,53 5 _7.~.~ ...... ~4 ........ _Q ...... 7.~.~.0,.21 ......7496,21 .... 534.50E .... !~51.B7_.S ..... 10~74.54 ...... g ............. !55~,.~.~._~._~Q__~.A_.!~_. . Q~283 80~9 23 G5 772~.~2 7667.12 S3~.00E 1314..~8 5 1127.10 E 1731.69 S AO 36 26 E 0.266 8143 23 0 7807.41 7753.41 S3fl.OOE 1345.60 S 1147.95 1536,69 _~_~..2~.? ..... g.2 ..... ~ ..... 7. .73.~. ,.. 9 3_ .... 7924.93 833,00E ...... 1.6o5. _~.~_2..:7 .... 2.! ..... 45. ....... 8.065~2~ ........ ~0.!!,24 £83.00~ ..... 14~4. 851.5 20 45 8151.91 8097.91 S31.OOE 8~.9.? ..... g,O.__Q .... _.:~...2~ Q.,_ 9..~ ..... ~_!.~6,03 ...... 83 O. OOE _~7.02.. .... I.. 9_ ........ O ....... _8.327 ,_ 70 ........ ~2_73 · 70 . 8795 18 30 8415.76 8361,76 8888 17 15 8504.27 B450,27 8982 17 0 B594.10 854C.10 _~0_75t 16 .... O_ .... 86[~.27 _8629,27 91(')8 16 0 8772.67 57!~3.67 9261 !6 0 8B52.07 6805.07 9355 15 30 895~.54 8898.54. 9448 15 15 -~042.21 ~'~98~'~ 71 .... ~.'. .............. 9~+1 15 9 -913!.99 _ __9~45 ._1=,_. O. _9232.44_ ~17~ 74 S 11~7.40 E 1840.12 ,5 40 11 13 E 5O 1453.39 1491.59 S2E.OOE 151~.74 S25.00E 1545.49 S23.00E 1571.56 S2i. OOE 1597.22 S18.OOE 1622.12 . S17.00E 1646.51 S16.OOE 1671.!4 SI8,OOE 1695o54 . SI9.OOE 1712.93 (; "~ ~: 1 -/41 · -' v 519.., ,~ ~. .., SiO.OOE 1767.32 S19.0O[ 1777.11 {iO¥TOf.1 !-IOL? CLCSU:~E 2231.87 FEET Al' S 37'!3 37 . S 1206 . 27 E S !224.13 E 1907.88 S 39 54 45 E 1.109 S 1240.74 F 1940.17 S 39 45 16 E 0.808 S ....!2£:5.79_E ......... .!970:~8 .... _.S_.._39.__._~._5 .... 1_0.._...~ _ ..... 1_.,099 ..S ..... 1269.!3 ..... E ........ 1999:50..~5__39 2_3_~..g. E_ ..... 0_,_.6_2_8 s !2~0.74 E 2027.34 S 39 10 41 E 1,357 S ...... !291.11.. E ...... 2 O 53 · 80 ..__S._3..8__ ._ 5. 7 ...... 0_E_ .... .0_, 3_22 S.._ !299.:P2._.E ........ 2078.7~ .... S._38._~2_._27_.E_. 1.__103 S 1~07.63 t 2102.64 S 38 27 iS E 0.296 ~ 1314.91 ~ 2126.43 S 38 .11 48 E 0.296 ,S 1522.37..E ..... 215C.,24 _S._37 57 ....... 3_._E_ ...... Q._5_53 __1.075 1 s 7 4,5 O_ S__ ~ 0 ....... ~.. l__~_.E. ..... o_._2.~9_. _ ~_.a..7.~ ...3_ 1905,91 1938.~1 19~..~ ~..~ 1 _9._9.8_ ,tis _2. 026.,_2 20~2 ,.9_6 2.0..__7.~.._1.0 135'3.!9 .E._. 2i73.~1_5..37 ..... l'J:.,'~,O9 E.. 2!96,~0 5_ 37..~!_.52_E ........... 0._._2.6_9 2_196,_../+9 !'~.4~..%.~ [ 2222.04 s _37 ls 3~ E_ .......... _0,.0.00 ........... 22_22_.04 1'35(.',.23. E .,'?731.C7_ 5_3_...7 ..... .1_.3_._.'_3._7 .... E.. ........ ~..,000 22~._1._.87 _ MEASURED VERTICAL SUB MD-TVD VERTICAL ....... PF__?.TH ................... D_ _[:_ P. T .H_ ...... ..S~.A_...O I.. E.?.~.,R'_E__N._C_~ .............. COR~F:]__c.. T..! O("i .............. T..~.T~:~ ....... C..gORD INA TE S 154 154. 100 0 0 0,06 S 0,06 E -~4 ........................ ~-~'"~. 200 o o ...................................... ~';'z'?'s o.18 E 354 454 454. 400 0 0 0,55 S 0.59 E a54 : ....... ~54, ............... 606 ................... 0 o i;14 $ 1.22 a 754 754, 700 0 0 1.52 S 1.63 E 854 854. 800 0 0 1.95 S 2.09 E 954 954. 900 0 0 2.43 $ 2.61 lO54 lO54. 1154 1154. 1100 0 ' C 3,56 $ 3.82 E 1254 1254. 12o0 0 ' 0 4 20 S 4.51 E 1354 1354, 1300 0 0 4,9G S 5.26 1454 . 1454, 1400 0 0 5,65 $ 6,06 E 1754 1754, 1700 O 1854 1854, 1800 0 1954-- 195~; ......... tg'oo ............. o ............. z'o'5~ .................... 20'~4, ..... 2ooo 'o .................. 2154 21~4~ .......2100 ....... 0 ........... 2~'54 2254-. 2200 ......... 0 ..................... 2354 2354, 2300 0 2454 2454. 2400 2554 10.08 S 10,64 i i', o 3 -s .............. i-i; '5-'~ 12.01 S 12.40 14.o2 ~ ~. o ~' S ............ i 4-;'~'~, 25 ~:,4,. ..................................................................................... 2500 C 0 I(,, 1,~ ;"" ' c ..; ............... iDi~7 ~.22 S 8,80 E ........................... 9o14 5 ................. 9'73 .... ~ -- E E E E E E 2654 2554, 2500 2754 2754. 2700 2~54 2-8%~. ...... 2954 .................. 2954. 29C0 0 305~ ...............]'054, ......... ~000 - ~ ............... 325~ 3254, 3200 ......................... 3~55 3354. 3300 C 3455 .................... 3454, .......3400 .... 2 ................................................... 3559' 3554., 3500 4 ................................................................... 0 C 17.16 S 16.43 (} 0 ]5.24 S 17,17 E -'o ...................... o ................................ ].-~/~2 2 "s ..... fs '" ................... o ............... 2~.39s ............... '-0 ............................. ~:1"-'07'S .......... O 22.89 S 20,51 E __- ' d .................................. 26.~'0 S .......... 22,35 E C .......................... 35;'i--3---S ..... 27"57 a 2 ........................... 47'52 $ 3'7-;0'2 .... E '2 ......................61.70--S .............. 52.4~-'E ,F-~O-D$:-.-9-20 .................................... ~';A,,.:NE T I C',!ULT I SHC.T ~ ' ~..~ ,~. ~' su~'~ sc,~'~'~.'ii; ........................................... " ,~AS~xE~ .... DEP_TH_.AfI. D QTH[R._PA.~A..F0 "' "'~ ~ "' S'. LLE:.,Y cV[:Nt0 ~LT 0 T ~ UE MEASURED VE'R T"I CA'['"-SO¢ .... ~,D-TVD V'fRT I CAL ......... _0.~.~_.5!_! ........................ P ~:~...~"_~.~ ..... S~[ ~.....P z E~_(..2..~ ........................... :. :..: ................................ _ aEr~C~{ ....... CO':.:r~ EC'T I ON TOTAL COORDINATES ~651 36s4. 36o0 ....................... '7 .................................. ...... ~7'6'5 ....................... s-75~-; ............. ~700 ...... lo .............................. · ~ . .' ~* ~.~ ~ 91,40 ..... 7~"~'-?'~ .......................... ~'~-5'~',' .............. 3~00 .............. ~s ................................ 3977 395'~'; ......... 390d ............... 22 ....................................... 4!91 4154, 4100 37 7 192,86 S 202,84 ,42q9 4254, a200 ~5 440-6 .................... ~354~-:- ......... 4BO0 .......... 52 ............................ 7 45 i'~ ....................... 4454~ ............ 4400 .............. b9 ................................... 7 .......................................... 2'67 ~'"53-':S 290,44 ~ 6 ~ 9 4 5 ~'~;' ........ 4'5 o o ........ % ~ ................................... ~ ............................ ~"~'i%-~"~--S' ........ ~i'7-';-~ 4832 4754' .......... ~700 .............. 78 ................................. 4938 4854, 4800 84 6 364,14 5 396,85 ~ ~ ~o ......................... ~0~4; ............ 5ooo ............ '~,S .................................. .......... 53'g:2 ....................... 5254-, ............. 5200 .... 108 ..................... 546~ ~354, 5300 114 6 491~47 5591 5554, 5500 12 5738 5654, 5500 13 5894 5754, 5700 13 ........ 6000 ....................... .5854. ........ 5800'''145 .............. ........ 6107 -.~954, 5°n.,,.~O 15~.. 6215 5054, .......6'000 160 6323 6154, 6100 169 6433 5'254, 6200 179 6542 6354-' ........ 6500" -l~f] ................ 6652 6454, 6400 197 ............ Bra2 ............. -~554. .....6500 2r.)7 ' '- ........ 687J 6654' ......e600 21B ............... 6983 .............. 6754'~ ......... 6700 22.8 7093 6854, &aG0 239 .... -'?2'04 69~54' ........ 5900 2.50 .............. . 7315 7054. 7000 2.6] . 4 7 ~ 7~. -~s s ............ S'~-3-'6'6 NiAGNET I C ~','!ULT I SHOT '~-SORED-'DEP'T~---;~-~-D--'O-THE-R'-'DATA FOR EVERY EVI<N '100 F'E~:T OF' SUB'-'S[{A-DEPTH. TRUE MEASURED VERTICAL SUB I, ID-TVD VE-:r~TICAL :---_~--_] i'D'. E'... ~.i T. ~]'_-_[.-_-_]..--_ ._.--]~i] ".D.:iE' ~. T. '.P.i.'i']-_".~sE A i _D I'Fi F. ERE I,.! ~"E'."i'i.' i.[i:''c o.R-.!~ E.c. T_[. a ~.! ..... :ii]' ] i"_T~ _0_" ~ ~ L]']-_'~. ;(J. ~"R._ ................ ?~6' ................................ 7254-'~ ............ 7200 '-282 ................ ............ ? ~ 6 ...................... 7 ~'5-~ ~ ........ 7..Boo .... 77'5' Y": .................. 7 ~"5 z~' i ....... 7 ~ 00 .............. 7866 7554. 7500 312 7976 765/*, 7600 322 8085 7754, 7700 331 978,89 E 11 1140,44 S 1006,62 E lo ......................... l'Iva';5i-S- lo~.~a E 9 ............................... 1253,22 .... $ 1085,~5 E .... 836~ ......................... 795'~' ............ 79003~8 a 1597"2'1 5 ....... iiB1.86 ..... 84i'0 80'54, ......... 8000 ......... 356 ....................................................................... ~ i'4'3'i~"0~'--5 ........ ~'203,83 8517 815'~', ............. aloo ........ 363 ............................. .7 ............................................. 1~63' ..... 99 $ 122~. 50 8624 8254. B200 370 7 1~95.9~ 5 1243,26 8730 8354. 8300 ........... 8'~35 ........................ ~4~,4. .......... ~4oo ........ ~g~o ............................. B'5'52;, .......... [3.500 ...... 9 9 9 o4g ..................... ~'55~+'o S6oo 149 875~, 8700 25 3 ................... B s"5 ~, .............. s a'o o ...... 356 895~, 8900 46'0 ...................... ~o5~, ......... ~ooo .... 564 9154, 667 9254, 376 5 1526,73 S 1259,96 381 5 1556.87 S 1274,33 E 386 ....................... 5 ............................. 15S5.76 $ ............ i2'8'~-'60 E 390 ~- 1613,93 S 1297,18 E 395 5 162+1145 S 1306,05 E 39S 4 1668.92 ,5 131~.,27 E ~02 ........... .3 .............................. 16v.~. eO"S .......... ]~3 22,4'5-E 405 ~ 1721.91-5 ..........13'3i;22 E ....... 9100 - z+lO ...... 4 ...... 17~,7o~5 S ..... i'32+0;01 E ........ 9200 ..... 413 ............. B ................ 1772.71-5 ........... 1348.7'i'--5 E E CO,--DS-,9-20 ........................................................... ,~4AGNETIC ;<:ULTISHOT SUP;VEY TRUE MEASURED VERT ! CAL SL)B DEPTH DEPTH ,.,,.SEA TOTAL CCORD INATE£ S 2.8,'5 E ,s ................ z i",' 0'.~: 5 19, ~6 E S .......... 1'50.43 .... E ...... s ........ ~+1'1';'5'6 ..... E S 638,79 E S 872,11 E .S ......... i'l 16-.'0 Z~ .... E E .............. ~-66 O-- .............. fg'~'S'; ....... i945, ............................. l'-O-. 51 ................. sO00 ......................... 2999';; .............. 2~45. zo. 5o .........................................4000 ~-c)'7-~'"~ ......... S 921 '.' ......................... -~'4 ~. ~ 7 5000 49'i"2"~ -'"~ e 58'; ............... 378"-/7 ~ o o 0 ......................... 5853';' .......... 579 ?. ............................ 628. ~ o ?DO0 ................... 67'6'9"; ......... 6715 · ....................... 954 ) 27 8000 76-76',- ......... 7622 · ..................... 129 8. Z 7 9000 ............................ ~611'~ .............. 85~7. ............... 1602.12 5 ........1292~96' .J AN-.13 )__.l 91.8 · ................................... : .................. ~ .._ SCALE I "-; ="'"' : ........... ' ATLANTIC RICHFIELD COMPANY ................................................... DRILL SITE 9;-20 -i .............. J ............ : ............ ' -- MAGNETIC MULTi-- SHOT .... , ..... ' ......... '. - m .......... ' ........... ~'- ............... :-' ' ......... · · - I .................. "-~ ........ ............... · ......... ........... - .......... . ; - 4O0O 44OO , ~00 ' 5200 · 6000 6400 6800 7200 ALLARE DEPTHSTvD SHOWN 7600 ,8000 ~200 TVD = 9271' TMD = 9685' .. ..................... ' ........ ' ............. ~ ....................... ". ........ L.V, ERT~ICA L. SECTI'ON. ............................ ~",~.'i .~ ..... .~.~" i"*~'~.'.'"/~'-.-'_'-~'_-i~'-:!i _- .... _~ - 'SCALE. i"=1000' ......... i. '-i'-'.'~ 'i ."' .i' ..... ~-~. . ..... , ........... ATLANTIC RICHFIELD COMPANY ............. ................ 400 '" , .................. DR ILL SITE 9- 2,0 ' ' '- .................... ' ............ : ........ .- .................................. .................. : ............ RADIUS OF CURVATURE ..... ' ' MAGNETIC MULTi- SHOT - · . . .......................................................... . . .......... o ................ . . 28OO 3200 36OO - ~000 ALL DEPTHS SHOWN ARE TVD. 6400 AtlanticRichfieldCompany North American Producing Division North Aiask'" --"trict Post Office ~. J60 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: D.S. 9-17 (43-1-10-15) Permit No. 77-38 D.S. 9-18 (43-2-10-15) Permit No. 77-39 D.S. 9-19 (34-12-10-15) Permit No. 77-40 12-10-15) Dear Sir' Enclosed please find our Sundry Notice outlining our plans on the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosures Form ]0-~,03 ~- Submit "Intentions" In Triplicate REV. l~10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) 2. NAME OF OPERATOR Atlantic Richfield Company :3. ADDR~S OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 407'N & 274'[. of SW cr Sec. 1, TION, R15E, UM , 13. ELEVATIONS (Snow whether DF, RT, GR, etc.) 54' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re [5. APl NUMERICAL CODE 50-029-20261 16. LEASE DESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. Drill Site 9-20 (xx-12-10-15) 10. FIELD AND POOL, OR WlLD~AT Prudhoe Bay Fi eld-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T10N, R15E, UM 12. PERMIT NO. 77-41 ~ort, or Other Data NOTICEOF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLIED OPERATIONS (Clearly stat'e all pertinent cletalls, and give pertinent dates~ Including estimated date of starting any proposed wor'~ Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The downhole safety valve will be installed and tested upon conclusion of job. Estimated Start Date: 2-13-78 i hereby certifY that the foregoing is true and correct SIGNED ~~. ~/f~'~'~"'"~ TITLE District D'rlg. Engineer DATE 1-25-78 (This space for State office use) APPROVED b¥~.-i~?-~~-E~~TIT LE. CONDITIONS OF APt:)ROVAL, iF ANY// Petroleum Emgineer See Instructions On Reverse Side DATE January. 3!..,.. 1978 DEP~ OF ~~ I~ESflIRCES Division of Oil and C=~s ~tion H~fle H. H~ilton . ~/ Chief Petrole~ En~ / v,~ ~. January 18, 1978 Witr~ss BOP Tests, Arco DS 9-20 Sec. 12, T10N, R15E, UM. Pezmit No. 77-41 3!, z by air to ~ ~BaY ~:30~, ~i~g at ~ at 8:00 ~. ~ of ~~ ~wi~ ~ ~st f~~ at ~ 9-20. I ~ pi~ ~ at Wi~~~s by ~~ ~, ~~ for~ ~ ~ 9. ~ I ~i~ at ~ 9-20, ~ ~~ ~ ~~ ~ ~ 3000 ~I. ~~ p~~~ ~~~. ~ ~ pi~ r~ ~ ~i~ ~ ~ ~i~ ~ke ~ ~ ~ 5000 ~I. ~ ~~ ~11 ~ ~e ~ ~~ ~ ~ 5000 ~I. ~ ~-~ ~~s ~~ ~ 5000 ~I. ~ 5000 PSI. ~~ s~ ~~s ~ ~~-~ f]_~g~ ~t ~s~ ~ ~o~ ~ 5000 ~I ~. ~e ~ ~e ~ ~s~ ~ 5~0 ~I. ~~s~ ~ fl~, ~ b~ ~~ ~ OK, ~ ~ ~ v~ ~ ~le. ~e ~ ~ l~~Hy ~~ ~ 5000 ~I. ~ 1~ pi~ ~ ~ ~~ ~ 5000 ~I. ~ bl~_~ r~ ~ ~~ ~ ~ 5000 PSI. ~ ~~r~~ ~~ ~ 2850 ~I. ~ ~~ ~~ ~t~ ~ 2000, 2250, 2~0, 2100 ~I. ~ ~ ~~~ ~~ ~~ ~ ~h ~a~ ~~ ~sf~. ~ pit ~ ~ ~t~ ~~. ~~ si~~ ~ ~ ~ ~ ~. ~ 1~~~ cl~ ~d f~ of ~is. ~~ ~k ~ ~d a ~ ~s. ~J/-__ i_l,= _1978 - 9:00 AM. Keith tkLllard, ~sor c~ DS 9-20, told me ~he dartr Valve was r~paired. I w~nt up to the drilling rig and inspected the dart valve. It was repaired and in good shape. witnessed the BOP tests c~ DS 9-20. ~en I finished tests and the dart valve %ms repaired, the BOP equi~t Attach~t Drlg. Permit No. ??'-XT// Opera tor /~./~ ~-~ Satisfactory Type Inspection Yes No Item ( ~(Location,General (A) ( ) (A) () (x) ( ) (.x)( ) () () () () () () () () () () () () 1. Well' Sign 2. General Housekeeping 3. Reserve Pit-(~open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos .... 8. Hrs. obser 9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment Alas. Oil and Gas Conservation Committ Field Inspection Report Well/Platfm Sec_/_'~._T~_' 'P,/9]~~, U M. Represented by//'/~,/~ ~/?_/_~4z~ame & Number/~_2~'] ,~._-_~2~_~'~ SatisFactory Type Insr)ec'Lion Yes No Item (~N<)_ BOPE'lests (X) ( ) 15 /=2~asing set (a2~]' Te~t fluid-,(~)wtr.([mud (;X) oil (x) ( ) (~) ( ) (~) ( ) l~ (ix) ( ) 19 (x) ( ) 2o (X) ( ) 21 (.~) ( ) 22 (x) ( ) 2~ (K) ( ) 24 (X) () 25 (~ ( ) 26 ($) ( ) 27 16 17 Master Hvd. Control Sys.- psiq N2 btls ~'~e R6mote ~ontrols Drilling spool-=~/~ "outlets Kill Line-Od) Check valve Choke Flowline ( ) HCR valve Choke Manifold Ho. valvs~' flQs2,9, Chokes-~L) Remote ( )Pos. Test Plug-(A~Wellhc~( )cs.o.( )none Annular Preventer,~¥K B1 ind Rams ( ) ( ) 11. P&A Marker (~) ( ) 28 Pipe Rams~-F~, psig ( ) ( ) 12. Water well-( )capped( )plugged (~) ( ) 29 Kelly & Kelly-cockg_?~<~>_'_psig ( ) ( ) 13. Clean-up (~[) ( ) 30 Lower Kelly valve..~-~,,." psig ( ) ( ) 14. Pad leveled . (~ ( ) 31 Safety Floor valves-~V ( )Dart nffo= / Remarks ~/~/4~_ ~'~~ cz,~/-Z~' ~ '~ .z/~z4~- /?~4~.. · ~ - -- Cc: ~,ZF ~/~/~? Not~f~ ~ N days or when reSdy.:~ inspected b~~?/,_:~ Dat~~ A~_la r~ic,RichfieldCompany North Ameri?'*' ~roducing Division North Aiask~ Pos1 Office Bo× Anchorage, Alaska 9954 Telephone 907 ;277 5637 January 10, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 9-20 (XX-12-10-15) Permit No. 77-41 Dear Mr. Hamilton- Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer FMB' ml n Enclosure Form No. P--4 RL"V. 3-1-70 STATE OF ALASKA susMrr lin DLr~LICA'I~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS wI~;LL wELL OTHER ~. NAME OF OP]!:RATOR ATLANTIC RICHFIELD COMPANY 3. ADDRESS OF oPERATOR P.O. Box 360, Anchorage, AK 4. LOCATION O'F WELJ... 99510 407' N & 274' E of SW cr Sec l, TI ON, R15E, UM AP1 NU~[ERICA_L CODE 50-029-20261 6 LEASE DESIGNA~ON AND SEHIAL NO ADL 28327 IF INDIA~, ALOTTEE OR TRIBE NAME 8. L~IT F.~:t}/I OR LEASE NAME Prudhoe BaY Unit 9 WELL NO DS 9-20 (XX-12-10-15) 10 FIELD A~'qD POOL. OR WILDCAT _Prudhoe Bay Field-Prudhoe Oil Pool I! SEC., T., R., ~.. ~O~OM HOt~ OB.rSCTrV~ Sec 12, TI0N, RIEE, UM 12. PE:I~IT NO 77-41 13. RE. PORT TOTAL DEPTH AT END OF MONTH, CHA2'qGE. S IN HOLE SIZE, CASING AIq-oC~ENTIN6 JOBS INCLUDING DEPTH SET A/~q~ VOL~ USED. PERFO~TIONS. TESTS A_N-D RESULTS FISHING JOS~ JU/~K LN HOLEA~ND SIDE-TRACKED HOLE A/~D A.NY OTI~ER SIGNIFICAR~IT ~GES IN HOLI~ CONDITIONS. Report of Operations for the month of December 1977 Spudded well @ 1630 hr 12-28-77. Drld 17-1/2" hole to 2720'. As of December 31, RU & ran i3-3/8" csg w/shoe @ 2683'. Cmtd w/4200 sks. Arcticset cmt w/add. 14. 1 hereby~Y ~tl~at ~ foregoingS:: .~d~ 7~ SmN~D,'/,~"~'~ /'4.,. ,~~~ TITL~ District Drilling Enginee~A~ January lO, 1978 NOTE--Report on this form is required for each calendar month~ regardless of the status of operations, and must bo flied in duplicate with the oil and gas conservation committee by tho 15th of the succeeding month, unle88 otherwise directed. J~ 15, 1977 Prudhoe Bay DS 9-20 (xx-12-10-I5) Atlantic ~ield ~y Pe_~t No. 77-41 District Drilling Engineer Atlantic Richfield Cc~pany P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved applicatic~ for pexmit to drill ~ ~ referenc~l well at a locatic~ in ~ 12, ~~ ION, ~ iSE, ~. ~11 ~les, core chips and a ~d log are ~ required. A dl,~e~l ~.~ny rivers in Alaska and their dra/x~age ~ ~ ~ class~i~ as important for the ~ or migratic~ of ~ fish. Operati~.s ~ these areas are subject to ~ 16.50.870 ~ ~ r~ticns prated ~ (Title 5, Alaska ~]ministrat/~ ~). Prior to ~in~ opera~ you may be con~ by t~ Habitat ~tnr's office, ~ ~ent of Fiji and Game. A6m~h~%stra~ Code, (~ 70) ~ by ~ F~I Water Pollu~icn Control ACt, as ~. Prior e~ ~ q~ra~ you ~ay ~ oon~ by a re59resentati~ of ~he Department of En~tal Pursuant to AS 38.40, Local Hire ~ State ~, ~ ~ D~t of Labor is being not/fied of ~ iss~mnce ~ this pezmit to drill. To aid us in scheduling field ~, w~ ~ ~ia%e ~ ~t~Zing t~s office within 48 hours after ~ ~11 ~ spudded~ We would ~ 'like ~ ~ notified so that a representa~ve of ~ Dl'%~ston may be present to witness test/rig of blowout ~ter equi~ before surface casin~ ~hoe ~ dril~. P' B. ~ 9-.20 -2- June 15, 1977 In ~ event of s~~sion or aband~x~t please give this office adequate ~ notificatic~ so that we may have a witness present. Enclo~are Pepar~m~t of Fish and C~a~, Habitat Section w/o ~cl. De~t of En~tal ~ati~n w/o ~ncl. Divisi~ w/o ~. Form 10-401 REV. 1-1-71 SUBMIT IN TRi tTE [ 's - (Other instruct, on , ,,' , ~ roverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITT '-' ~':'~- PERMIT TO DRILL OR DEEI~EN' : ' - . , ,.~, la. TYPE OF WORK DRILL E~ b. TYPE OF WEI,L OIL GAS ,~%LL ~] WELL [--] OTHER 2. NAME OF OPERATOR . Atlantic Richfield Company DEEPEN r'-] SINGLE [~] MULTIPLE[---] ZONE ZONE 3. ADDRESS OF OPERATOR P. 0. Box 360 Anchorage, Alaska 99510 4. I,OCATION OF ~%LL Ats.a~407,N & 274'E of SW cr Sec. 1, T10N, R15E, UM. A, p~opo~a prod. zo~e 1230'S & 1485'E of NW cr Sec 12, TION, R15E, UM ~3. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 6½ miles northeast of Deadhorse, Alaska 14. BOND INFORSL,~TION: a~Statewide Surety and/or No. Federal Insurance Co. #8011-38-40 API No. 50-029-20261 6. LEASE I)ES1GNATION AND SERIAL NO. ~ADL .28327 7. IF INDIAN, ALLO'ITEE ORTRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. _ Drill Site 9-_2.0 (xx-12-10-l-r 10. FIELD AND POOL, OR WII.DCA 1' 11.SEC.,I, R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, T1ON, R15E 12. ^~ou,t $100,000. O0 t5. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE. FT. (Also to nearest drig, unit, if any) 3795 18. DISTANCE FROSt PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR, FF. 2650 16. No. OF ACRES IN LEASE 2560 19. PROPOSED DEPTH 9970'MD 9292'TVD 17. NO ACRES ASSIGNED TOT.ISWELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START March 2, 19.78 . 21. ELEVATIONS (Show whether DF, RT, CR, etc.) ._.21' Pad Elevation .(Grave!).. 23. PR~ ,POSED CASING AND CEMENTING PROGRAM SI'ZE OF HOLE SIZE OF CASING WEiaHT PER FOOT GRADE . SETTING DEPTH Quantity of cemen! . .20" 94# H-40 . lOi3'+ £irc tn qurf approx 500 sx.. . .17~1/2" . . 1.~-3/g." 72# N-RI3 2700'+_ Circ to surf approx 5500 .sx .. !.2-!/4" 9-5/8" ~17~. N-nh 9842.'+ 2500'* r,m'l- cml,,mn nn lci~ ~ ...... & S00-95 ... - 300'.~- cmt on 9,~ ~*=ge-!2.5+ sx , )00 sx Atlantic Richfield Company proposes to directionally drill this well to 9970'+_MD, 9292'+TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5½" 17# N-80 tubing, packer and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing fluid will be left in all uncement-ed annul i within the permafrost interval. LN .~BOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is tO drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certify that the Foregoing i$ True ~rr_ect ~ DATE TITLE Di stri ct Dri 11 i ng En'gr. (This space for 5.:-~:e office use) DIRECTIONAL SURVEY REQUIRED ~ No CONDITIONS OF APPROVAL, IF ANY: NO.. .... 77-41 MUD'LOG [] YES [~NO OTHER REQUIREMENTS: A.P,I. NUMERICAL CODE ....... APPROVAI, DATE APPOVED BY ~ ~ . TrI'LE Chai.rman ......... ~ *See Instruction On Reverse Side 50-029-202__6_1_ June 15, 1977 DATE_ ,June 15:1977 SEC. t 200' 224,' 250' 274/ EC. I SEC. IZ CERTIFICATE OF SURVEYOR ! HERE BY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION AND ALL DIMENSIONS AND~ OTHER DETAILS ARE CORRECT. Feb,77 ~-~.-~%g ,~.~ . Wells 12,13~ i~ . .. . ~. / / . Surv~or Ab ~UILI WELL LUL. AI ikJI"I.) "YELL No. 12 .AT. LOHG. WELL LAT. LONG. WELL LAT. LONG. WELL LAT. LONG. WELL LAT. LONG. WELL LAT. LONG. WELL LAT. LONG. WELL LAT. LONG. WELL LAT. 70° LONG. i,4.8 70° 14' 46.838"Y 5 94.2' 815.87 148° 14' 06.527"X 718 4,56.54. 7 0° 1Zl.' 45.684/Y 148° 14' 05.804~'X No. 14 70°1 4' 44.53Z"Y 148° 14.' 05,073" X No. 15 4,' 7" 70° 14,, 4,:5.37 Y 14 8 o I 04.352"X Na 16 4' 42.221~Y 70° 148° I 0:5.613 X No. 17 70° 14.' 4' 1.065" Y ! 48° 14' 02.893" X No. 18 70° 14' .'59.910" Y 148° 14'02..176" X No. 19 -mo,.v, 14,8° 14 01.44.2 X No. 2.0 14~ 37.606" Y 14'00.721" X 5 942 699.30 718 4-84.8 i 5 94,2 582..98 718 515.'32 5 942 466.$0 718'541.52. 5 94,2 =549.60 718 570.32 5 942 '232.79 718 598.50 5 94,2. i 16.14 718 626.56 5 942 000.01 718 655.18 5 94,1 883.4.2 718 683.57 ~CO NO. m ....... HVL'No ...... a ~ L"~S~m ~Tm~. ATLANTIC RICHFIELD CO' AS BUILT DRILL SITE No. 9. WELLS No. 12.,13 8~ 14- LOCATED IN PROTRACTED SECTION. 1,T. 10N.,R.! 5 E.,U.M. PREPARED BY HEWITT V. LOUNSBURY & ASSOC. 723 W. Gth AVENUE ANCHORAGE :tALA:~KA DATE FEB. 1977 SCALE I" = 2.00' CHKD BY PC FIELD BK. . ' .. . 1. ~? 1!1 _ . , ' ;;_ ';' . '1 i .~ Il , , ,1 .: ~ - - - : : Yes No Remarks 1. Is the permit fee attached ............... ....... ~<~ 2. Is well to be located in a defined pool .............. 3 .......... Is a registered survey plat attached ...... 4. Is well located proper diStance from property line 5. Is well located proper distance from other wells .......... 2(/~J~ 6. Is sufficient undedicated acreage available in this pool ...... ~a/:~i 7. Is well to be deviated ........... ~ ,,~ ~ 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait ............. ~}~i' lO. Does operator have a bond in force ................ /~<, ll. Is a conservation order needed ................... 12. Is administrative approval needed ............... 13. Is conductor string p~ovided ................... 14. Is enouqh cement used to circulate on conductor and surface 15 Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ............ 18. Hill all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure ratino,~ - Test to .:,~,~ ~,' ;::, psig 20. Has DMEM approved Plan of Operation .............. Additional Requirements' Approval Recommended' Geology'. Engi neeri ng' HWK .~.)~.~ LCS ~,~.:~ RAD ~~ · Revised 11/17/76 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 APPENDIx. ., No special'effort has been made to chronologically" .. organize this category of information. 1. 1 0 0 !) 0 0 0 1 I I I 0 0 0 0 I 'i I I O0 O0 I I O0 0000 ! 1 OQ ooOO il o0 O0 O0 1, 1 O© 06 O0 1 1 o000 OO ! 1 0000 nO I 1 nO O0 11 (10 oo '11 1 I I 11 O00OO() 11 iII 1 000000 77'*~'777'~'~ 77'71777777 77 77 77 77 77 7 '7 77 77 77 77 77 77 000000 00 00 O0 O0 O0 0000 ¢10 0000 0 0 () 0 0 0 00 0 o 00 0000 000 0 l) 0 00 00 O0 o0 000000 o00000 77 77777777 7'777777777 7'7 77 7; 77 77 77 71 77 77 77 77 77 066666 1 t 66~6fi6 11 6 k, I, 1 I 1 66 1.111 66 f)6i~b~6 1 !. 6O666666 1 1. 6~ 66 1 1 66 ~b 1 1 66 66 !. l 66 b~ 1 l ~66~ 1111 o~ot~66 11 I 1 11 1! 3333 3'~ '33 3'3 3333~ 333333 5555555555 5555555555 tt 55 't~ 55 33 555555 ~3 555555 55 55 ~] 55 33 55 ~ 55 55 1~ 55 55 555555 555555 44 44 44 44 44 44 44 44 44 qq qq 44 q4q.~44q444 4444444444 44 44 44 44 44 GGG(; G G G G GGG G G (;GG k IR [J U RRR~< U U ~ H Il [j fl {j U D I') r) D D D D [) ..r) [3 D t) PC, aL t !07i)7,61 ]541 tJ $ K P P C .a. i: [. 1 (.'~ l 07, e~ 1 _.154 j 08:13:!0 08:13:10 I I I I I I II Ii ii. Ii II ii I I II II III, i i'! II i 1 II Il I I PPtr~PPPPP PPPPPPPP PP PP PP P P PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PP gEO. ~296 gATk 2~-~EB-81 22-FKS-81 13:2'1:35 PCCC :I,&SUED 22-~.P::B-8.~ 1 ~:27 PCCC VV VV VV VV VV VV V¥ VV V V V V VV VV uv 'v v RR ~R RR ill!! ! IIIili [ I 1I Ii II I I II ~I' Ii l.IIIII llIIII FF?'FFFF'FFF FF FF F'FFFFFFF FFF'FFFF~ FF FF ¥¥ YY ~¥ ~Y '3296 DATL 0~:10:26 08:13:10 LIS VRPSICJ~,i 15.hr)l 79/0 10707,61 354 'I? APE NAaF;: 61.354 EPVIC~.; ~}Aak: EDi.r TAPF: Cf.INTiiqIJ~TItIN i~(J!4BER: O1 PR[Vlfil}~5 'I.APE NA?~E: RUN I.JNE - LOGGE[) 19-JAN-81. .A]'.~[~ ~JF ['HF~ I'FG WgPg I_)IGI,'IiZEI,) C~lqI ri gel). g DATE: 81/ 2/22 ! 024 ~l YPE O SIZE 1 ENTR~ ~ T fl o 0 0 0 4 I O 8 G A P 1 5 1 3 1 ~ 2 0 0 4 t 6 8 GAP1 5! ~! [~2 ~} 0 4 1 ~2 C U 5 1 40 1 0 0 4 t 6 8 C U 5.1 4 0 2 0 0 4 1 6 8 CPa 51 ]9 9q 0 0 4 1 68 CPS 51 ,Iq 99 O 0 4 I fl8 CPS %1 .]9 q9 0 () 4 1 ~ CPS 51 3q qq 0 0 4 l 08 5 1 t 3 0 0 0 4 1 6 ~ OUTPItT C;P Oi}TPOT GkBb {J UI~P;'IT SIGN OUTPI)T FSiG []I.[iTP tl T T ~,~ B K OUTPUT TNG OUTPUT I~AT {Ju rPuT T!~l,]O PROCESS INDICATORS 96 ! 0. o00 9600. 000 q 5 0 0. n 0 n 9 3 0 0.0 0 q 9 2 0 0 o 0 0 0 ~ 1 O0. 000 gO00, o00 R 900.000 G R T l',t }:3 F, GP, TP, AT Tt~AT GR T N B GP T Pt A T GR GR I'R A 'r GA -999. -999, -999.00n -999 o -999. OOO -q99. O00 200.575 3.419 37,25o 224.569 4.519 I 1.. 800 2e, 7.o58 2. 30.250 305.5.4 o 3.879 0.00 n 0.00 0 6, -1998.500 -999.25O -999. 250 - 1998 -999.25O -999.25O -199~.500 · -999. 250 -q99. 250 GR BO G1R 'IF T H O D G f'~ B U '1 I~''B I< 1; !",'i I) O G R B GH.g l.i :T ~-4 LI G R ~ 'lJ T NIlt} {~ fL ..ri. J GRBU T F ,B K GP, BU "IF R,K -999.000 -999 oO0 -99q:000 -99~.000 -999.000 -99q.000 4~.196 2OB .569 1.0'76 16.954 261.210 0.805 1 t. 486 272.431 0.985 11 O. 58 '7 31 2.731 -O..1 25 ~t25. 000 -O. O01 -¢qq.250 -99q.250 -9qq.250 -gqq. 250 -999,250 -999 250 -999,250 -,999.250 -9<,q.250 6IGM TNG SIGt4 T N G S I G ~4 .1 ~G 5IGI~ lNG T N G T ~4G fig 6IG~ T ~ G V A l.li'~ -999.000 -99g.000 -999. 000 -999. 000 2t.994 540.91'7 37.171 884.068 19.115 675.162 2 '1.0 ,.{ ) 755.622 59.5,,90 1750. 000 -999.'750 -999.250 -99q.750 -999,250 -99q.750 -999.250 FS .1G T FG t~S tG T ~SIG FSIG TFG FSIG TFG ~'S IG T F G FSiG T F G FSiG TFG F'SiG TEG FSiG TFG -999.000 19~.125 -999.000 194.125 21.721 221.375 3'1.548 255.000 16,031 29~.000 26.931 327.5OO 59.185 326.250 -1000.050 326.250 -1.000.050 -999.250 -1000.050 -999.25,) N!AXI~'itI~ P~i~SI. CAI; RECF:iRf) LENGTH: PRLV iUIJS F' ] Lb, I 0 2 4 B ¥ T E S 0 SI. ZE REP CODE 66 0 TOOl, AP1 APl AP1 APl FI, bF, SIZk SA~ REP FT 0 0 O 0 0 4 1 68 GAP[ 51 ~1 32 0 0 4 l 68 GAPI 51 31 32 0 0 4 1 68 Cu 51 40 I 0 0 4 1 b8 CU 51 40 2 0 0 .i 1 68 CPS 51 ,39 99 0 0 4 l OB C[;S 51 ]9 99 0 0 4 1 68 CPS 51 59 99 0 O 4 1 68 C/C 51 42 0 0 0 4 I b8 51 4~ o 0 0 4 1 68 G A P I 51 ~ 1 ~ 2 0 0 4 1. b 8 G A P I 51 3 ? 32 0 0 4 I 6 8 C Il 51 40 I 0 0 4 l ~ 8 C~] 51 40 2 0 0 4 ~ 68 CPS 51 ]9 99 0 0 4 1 68 CPS 51 39 99 ti 0 4 I b~ CPS 51 ]9 99 0 0 4 I 6a C P S ~ I i 9 99 0 0 4 I 68 C/C $ I 42 ~ 0 0 i ! 6~ 5 1 4 ~ 0 0 0 4 1 68 P~OCESS INDICATOR6 9b I 0. 96 O0. O0 0 0%O0. 000 9400.000 9 300. 000 q2Ou. O00 9100.000 8990. ('l 00 S I rr.~G GP, -T fcA I' $ I G H T .H G fRA~I SIGN T !"..i G G R TPAT S 1 G ,v~ TN('; GP TPAT G~ ! 7 ~, 600 287.55] 2. 400 .348.076 297.55] 2.40u 26. o7 ] 34 ~. 076 5,4.05 0 314./~21 ']. 401 529.985 57.050 {7.291 888.993 ]41 .5'~0 8.755 b52.861 5 2.2OO ~'72.5~2 ~.979 26.86~ 794.10 't i 0e. 650 ~94. ~,01 59.5t;0 1749 .Se t -!998.500 -999.250 -999.25(~ -q99.750 -999.250 -Q99.25t~ -999.250 -99q.750 -9qg.?Sq [~SIG GPBIJ 'I F B K t~ T}:'G GEBtt TFBK MOD SIG l'fG GRBd 'l: r4 { iD t-$IG TFG GRBu fSiG GRBU Tt4I. ID ~SIG G }~ ~ ti PSIG TFG Gl<Ed FSIG 'f.' GP, h tl 'fl G 74.032 20'7.756 'I.180 23.~98 1~B.750 74.032 207. 756 ! .180 1. ~1R.750 53.8O8 230.~44 1.483 20.058 236.125 56.804 275.600 1.214 t8.117 269.750 37.578 273.24& I .266 t t~. 0 ] 1 275.000 53.n%o 321.]4~ 1.529 25.R53 328.O00 114.981 229.856 1.6t4 59.1.10 ~25.500 -9q9.250 -9qq.250 -999,250 -1000.050 325.500 -999. 250 -99q. 25O -999. -I -999.250 T NG TNBK GR TNG G~ T~qAI SlGM TNG T NBK TR~'T SIG~ T NG G~ T~'I SIG~ I'NG G~ ~ tG~vi GR TNBis SIGt'4 'l ? A I GH VAGUE ~3.b31 404.485 67.850 403.8'99 1.455 q04.485 67.850 40t.899 1.455 25.069 574.150 70.~00 ]59.035 3.376 37. 005 904. 298 7 'j. 40O 358.535 4.404 !8.890 613.943 50.600 37 3.032 2.875 27.09~ 822.089 t~7.,~50 :]95.4(,; 1 ]. 78<) 42. ~ ~9 727.6~0 0.000 0.000 6.000 -999.750 -999.250 -1998.500 -999.250 -999.250 -999.750 -999.250 -199~.500 -999,250 .gaa 250 M, ~ E M U N '! C FSLG TFG GRI4U Ti; BK FSI. G rFG GRBU TFBK TMUD FSIG T GRBU TFBK TFG G R B U TF'dK BSIG TFG GRBO TFBK fSIG 7FG GRBU F$IG TFG GRBO TFBk BSIG Tf'G G~BU TFBK TMOD FSIG GRBU I'FB~ 'r~OD 25.853 211.875 8.989 121.469 2.389 25.853 211.875 8.g89 1~1.469 2.389 21.490 230.000 68.914 214.094 1.741 37.90'1 258.250 73.159 251.644 1.294 16.165 275.000 49.938 279.175 1.438 27.321 332.000 08.789 317.769 1.642 J6.515 325.500 0.499 ,~25.000 0.002 -I000.050 325.500 -999.250 -g99.250 -999.250 -1000.050 -9~9.250 -999.250 -9~9.250 -999.250 GRPttj ITF BF: i, SIG TFG -999o250 -999o250 -999.250 -999.750 -999.250 -199~.500 -999.250 -999.250 F$IG TFG GRBU T~40D V A L,.., ,...," -1000.050 -999.250 -999.250 -999.250 -999.250 I.,ENGI~t~ [1F F~..CO~.DS'~ 1014 HYTE. S LENGTH f]F LhST t4ECO}~t): gO B'~IES ~ILE T~A]LE~~ 1024 1024 ~, , [';'~Y~J. CAb 1DOS FLLE. NAME: IL~ FOUR gNI) FIVE. B Y T 1;.; S 1 [,)[:;PT ~"T 0 () 0 2 d.F: "[ D T b,! GAP1 51 3 SIGM 'IDTM CU 51 40 1 ~l F'SI.G rDTM CU 51 40 5 Tt'tG TDTN CPS 51, t9 99 6 rFG if)TM CPS 51 3q 7 GR TD~'N GhP.[ 51 ~1 32 I0 FSIG ~?[')'fM CU 5i 40 2 I1 TfqP, N TDTM CPS 51 '3~ 99 12 ['kRK :rD-rs cps 51 3q 99 I 3 t~dG TDT~4 CPS 51 39 99 i5 'PRAT ([f)TF~ C/C 51 49 0 l~ T?IrjD TDIN 51 43 AP1 fflLE SIZE SA?4 REP PROCESS I NDICATURS 96 I 0. 000 96 :,; 0. o 00 95 0 0.0 0 0 94 O0. q '3Or). OuO q200. ql q O 00.09 () 8~9Oo 090 II- G F5 IG :1: F TFG f S ! :o fS!G G~ E TFG TfG T F G F'S1G GH '? F G f FSIG I1: G f SIG Ti-r, [- S I G I'F'G 0.406 145.125 27.051 1,47.87B 0.40t~ 26.887 147.875 7~.938 1.92.250 2t.002 245.125 78.000 294.250 ~7.I. 74 )75.0r)0 60oq~9 287.500 16.285 295.'750 75.56 ~, ]28. 250 26.27:~ .]2 l. 250 95. 275 2:18.000 27.4!! ?~2.125 0 o 000 320.250 30. 465 :,25.50() O.OOn 321.50o -1000.050 lo2.125 -999.250 -999.250 -1000.050 GR T R A T SIGN GR T}~ AT GR 81GM SI, GY~ $IG~q G~ S i G TP, a 17, SIGa SIGnal G~ ~ RA1 2b.~25 140.650 415.8ql 4.079 26. ~25 1 O5. 050 447.01 .~ 4.075 25.531 I t2. 396.026 3. t 96 3a.~13 91..450 387.40~ 4.499 19.~75 70.450 406.023 2.845 27.344 94.600 420.a95 3.849 2a.422 120.650 445.828 4. 098 59.625 80.200 458.510 ~.034 59.250 -1998.500 1999.250 -999.250 -999.250 -1Q98.500 -999.250 -q99.250 ESI. G T~4r~D f's1G GRBU TF B~ FSI G GRBL) I~S1G GRBU T M {:3 D ~$1G GRBU fSIG ~iFBg fS[G TF BF. f'S1G T M 0 O fSlG G~BU IF Bi', ?SiG GRBU VALUE 23.125 148.814 200.709 1.922 23.125 102.871 208.325 1.805 22.156 133.458 238.875 1.9~6 36.9~9 90.880 276.169 1.470 1~.859 71.036 281.044 1.670 26.141 95.381 324.755 2.0'13 2~.250 121.a48 20~.044 1.850 58.656 8 ~. 396 325.000 1.713 58.406 -999.250 -999.250 -9q9.250 -999.250 -999.250 -999.250 -999.250 MNEaON lC TNG TNG SiGN TNG TNG SIGH T N G T bi G SIGa 'I'NG TNG SIGN TNG TNG S1GM T NG 'rag SIG~] TNG T N G T'NG TNG S [ GM 'l' NG TNG SiG~! T N G V A L id E 343.000 26.928 580.710 343.000 20.928 ~17.819 525.000 24.814 585.957 924.000 37.39~ 918.728 68~.000 18.755 652.424 819.000 2~.508 794.540 '700.000 2'1.528 640.180 854.000 32.312 911.294 ~54.000 -999.750 -999.250 -999.250 -999.750 -999.250 [: I L E ii: F! ~ I. L E 14. F:flF 024 TAPE 2122