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194-023
Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/29/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221129-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 11-04A 50029204800100 194023 11/4/2022 READ Mult-Array-Pprof PBU 11-24A 50029216230100 193204 11/9/2022 READ Mult-Array-Pprof Please include current contact information if different from above. By Meredith Guhl at 2:00 pm, Nov 29, 2022 T37339 T37340 PBU 11-04A 50029204800100 194023 11/4/2022 READ Mult-Array-Pprof Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 14:06:10 -09'00' STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 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 0 Other Pull Plug 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 194-023 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20480-01-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 11-04A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9355 feet Plugs measured feet OCT T 2 true vertical 9079 feet Junk measured 9101/9193 feet " ' ! 0 2017 Effective Depth: measured 9311 feet Packer measured See Attachment feet AOG CC true vertical 9036 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2684 13-3/8"72#L-80 28-2713 28-2712 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9022-9043 feet feet 9051-9064 feet 9080-9096 feet 9108-9118 feet 9128-9139 feet 9139-9148 feet 9148-9149 feet 9170-9190 feet True vertical depth: 8751-8772 feet feet 8780-8793 feet 8808-8824 feet 8836-8846 feet 8856-8867 feet 8867-8875 feet 8875-8876 feet 8897-8917 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): SCANNED NOV 0 2 2017 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 34 994 2026 1589 713 Subsequent to operation: Shut-In 1866 0 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 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Chamansingh,Ann Marie Contact Name: Chamansingh,Ann Marie Authorized Title: �Peettroleum//Enn'��gineer Contact Email: AnnMane.Chamansingh@bp.co Authorized Signature:�y� i t C.A'!q•rvtii ' Date: a$n ;1oiT Contact Phone: +1 9075644070 Form 10-404 Revised 04/2017 V r(i I G/10 // 0(//0/#1)RB®MS !%v 6t„I - 3 2i1 f 7 Submit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 OCT 0 2 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 21, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Pulling of HEX Plug for Well 11-04A, PTD # 194-023. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment PBU 11-04A SW Name Type MD TVD Depscription 11-04A PACKER 7621.25 7375.82 7" Liner Top Packer 11-04A TBG PACKER 8388.33 8127.33 4-1/2" Baker S-3 Hydro Set Packer 11-04A TBG PACKER 8540.37 8277.06 4-1/2" Baker SABL-3 Packer 11111 m Q„00000000 R N CI4 D D N N 0 CO — up N- O O IO to V y 0 0 0 0 0 0 0 0 i M M N- N- CD CD C!) M 3 UI CD 00 00 m NJ- CD CD OD 00 co CD CA ,- co 01 U1 Ul N- Ns Ns N M O N- Ns UI '— O N Cr) N r N- co O) O O 0 I III I III H CD O) M O) CO O) CO N N N N N N- M N N N- O 00 4.11 0Cr) to CO Cr) O) ) N- E O) CAtovtoOOO) C) to up N N- O O) OD op 441, Q CD N N N v- CO 0 N OD C M L W O cp O a O O O 00 00 oJO CO CO O co fU M = N N Zco � CD •� Cl) O cY -00 ;0 00 N CD U 0Lc) N - (N N O) r r V 4 s C cco COD N- OO) N OCq 00 M) Cy N to co O) 00 J W W co O — — N (~jVWW V C) LL 0 Ce Ce OC Z Z Z t W W W W m m U OD Z Z =3_:: F— F— • S § § E k E o k E E ƒk k $ : 77 � a) $- 0ƒ � 02 —O al o >- E 2 < § b w E-' g22 # Oou) a 2 20 � � / ® _ ¥ � 9w k \ / 0 / U- i= co 0 oM 0- / � 03 ƒ ƒ r 0 - _ m O = 0 0- < < \ o > L cc 2 < u- - z p Z >< O E � cn = R o O waw4El Z \ 2 � k < _ < , 2 0_ 2 : 5 u R ¥ / / c � / co TREE= 4-1/16'OW • N !Mai-HEAD= MK EVOY SAFETY NOTE: "'CHROME TBG&LNRr" ACTUATOR= BAKER C 11 -04A OKB.ELEV= 56' BF.E EV= NA KOP= 4150 1/ 11� Mtax Angie= 300 g 6099 '� '� 1762' 9-5/8'H ES CEMEf�1T�R Datum MD= 9123' 11 1'4 Datum ND= 8800 SS -1 -4 f _ 1779' j--[9-5/8 BKR ECP • 11 t 9.5/8"BOWEN CSG PATCH,47#, H 1806' .� �''I L-80 HY D 563,1D=8.681" LI2014' H4-1/2"HES X NP,D=3.813" GAS LFT M AJJJI S 13-3/8"CSG,72#,N-80,D=12.347" H 2710' HAI ST MD TVD DEV NEE VLV LATCH PORT DATE 4 3457 3457 0 NIMG DOME RK 16 10/20/11 3 5851 5741 28 MSK' SO RK 20 10/20/11 Minimum ID =3.726" @ 8687' 2 7476 7237 17 MtMG DMY RK 0 08/14111 1 8288 8029 10 KBG-2 DMY BK 0 08/14/11 4-1/2" OTIS XN NIPPLE ?? H FISH-4 GRAPPLE LEGS(09/30/11) 7614' H7" BKR TIEBACK SLV,D=5.31" l 7621' —9-5/8"X 7"BKR LTP w/BKR LHGR,D=6.19"? 9-5/8"MLLOUT WINDOW(11-04A) 7786'-7831' 9 518"CSG,47#,L-80,ID=8.681" H 7786' LW8365' —4-1/2"FES X NP,D=3.813" ` 8396' J-17"X 4-1/2"BKR S-3 FKR ID=3.875" , 7 LNR 29#,N-80 XO TO 13CR-80 NSCC — 8441' .4 PRORATION S �' �i , 8430' —j4-1/2"FES X NP,ID=3.813" REF LOG: Z-DENSI ON 03/01/94 11/4 &RST SIGMA ON 09/06/10 8517' —7"X 4-1/2"UNIQUE OVERSHOT ANGLE AT TOP FERE: 8'@ 9022' 8530' H4-1/2"TBG STUB(MLLE)05/20/09) Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I, 8540' —7"X 4-1/2"BKR SABL-3 3-3/8" 6 9022-9043 0 02/04/11 \ixPKR D=3.875" 3 318" 6 9051 -9064 O 02/04111 8670 4 1/2 OTIS X NPD 3 813-. 3-3/8" 6 9080-9096 O 07/29/09 � ��3 3/8" 6 9108-9118 O 07129/09 858T H4-1/2"OTIS XN NP,ID=3.725" 3-3/8" 6 9128-9148 O 07/29/09 3-3/8" 2 9139-9149 S 05/24/98 2-1/2" 4 9170-9190 0 03/22/94 8599' —14-1/2"WLEG,ID=3.958" 11, 8591' HELM TT LOGGED 03/13/95 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,ID=3.958" —1 8599' , 7"MARKER JOINT(19') —r 8751' Ilt III 9193' —FISH: FASORLL FLUG PUSH TO BTM 111 (TAGGED 06/03/09) FBTD —j 9312' 1 ,.444:6' 7"LNR,29#,13CR-80 NSCC,.0371 bpf,ID=6.184" --1 9353' DATE REV BY CONSENTS DATE REV BY COMMENTS PRUDHOE BAY INT 07/25/80 ORIGINAL COMPLETION 10/31/11 JMD GLV 0/0(10/20/11) WELL: 11-04A 03/05/94 RIG SIDETRACK 07/31/15 JG JMD SET HEX PLUG(07/11/15) PERMIT No: 1940230 05/30/09 D14 RWO 08/28/17 JG/J1/0 FILLED HEX RUG(08/25)17) AR No: 50-029-20480-01 08/16/11 TA/PJC GLV CIO(8/14/11) SEC 33,T11N,R15E604'FNL&8'Fa 10/10/11 RCT/PJC PLLL IBP&ASH DH(09/30/11) ' 10/10/11 PJC TREE C/O(10/08/11) BP Exploration(Alaska) iogu( • • P 1g40 z3o Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Friday, October 28, 2016 1:43 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Kj �tl -S (yam Cc: AK, OPS FF Well Ops Comp Rep;AK, OPS FS2 DS Ops Lead l Subject: FW: DS11 Deficiency Report Attachments: DS11_Deficiency_Report.pdf Attached is the deficiency report for DS11 indicating corrective actions have been completed. Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony— 7187 (Alternate: Vince Pokryfki) SCANNED 'ION 2 7 201?, State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: // - e, .�-- 0 f (/ � Date: A PTD: / -.` , Operator: ip/vii , Type Inspection: Operator Rep: r /1:411 454 _ Inspector: .An% Position: � w Op. Phone: 1 lel) €s`3.., 4•yc11 Correct by(date): Op. EmailA K OP-s FS a Q,51Q,cokA Follow Up Req'd: Detailed Description of Deficiencies Date Corrected 4/124, 4).61/.4" , .---' A Zb//—c..?7, , I 40 hot- 71;of iof 2-2 / 4. .,,,,,,,=)-,41„ , - / , „I i ,. - Attachments: ,: Operator Rep Signatures: � IIS"-' AOGCC Inspector *After signing,a copy cif this form 1st. .el-ft with i Q o.,r3 tor. Follow-up instructions !Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • State of Alaska • 1,3i-k ii-c-4-4, Oil and Gas Conservation Commission (3Tp Ici 4-0-z,30 Deficiency Report ��ti4\1'� Location: < ,74/ Date: /29/6, PTD: /I�• Operator: Rp/y/t1 Type Inspection: liw Operator Rep: 7. 4 "if _ - Inspector: E r '1 Position: 7 Op. Phone: (. 671 . ., 5tril Correct by (date): kl 16 Op. Email: Av, 3 .. Follow Up Req'd: Detailed Description of Deficiencies Date Corrected /1/ } i t ? - - Jfj -J frii _ ,,, zz=) its' - f ' . i JP, /fjf 7f ..- scow JUN TT-2017 Attachments: ;9i4„.. I / ,,,Signatures: i Operator Rep _"_ _' ,, � AOGCC Inspector *After signing, a copy of this form is t• •e I ft with .,- op--:tor. )Iiow-up Instructions turn a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the "Date Correcte Id attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was ,rformed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"dat€ ust be requested and accompanied by justification(Attention: Inspection Supervisor). Documentation of deficiences that are outside o )GCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. vised 2/2016 L. • 0 oF/7/�� THE STATE Alaska Oil and Gas g�., //yamsA N � ofALAT� Conservation Commission ftriff 333 West Seventh Avenue �' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^� Main: 907.279.1433 OA, L .‘5�� Fax: 907.276.7542 www.aogcc.alaska.gov Ralph Sinnok Production Engineer &w a `" � BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU 11-04A Permit to Drill Number: 194-023 Sundry Number: 316-197 Dear Mr. Sinnok: 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, ki Cathy P Foerster Chair DATED this /3ay of April, 2016. RBDMS 1,VAPR 1 4 2016 STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMMN APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 ,I 1. Type of Request: Abandon ❑ Plug Perforations Q - Fracture Stimulate ❑ Repair Well IZI - Operations shutdown❑ Suspend ❑ Perforate II - Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Set QCLL Scab Liner 17I 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 194-023 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development [Q- 6 • 99519-6612 Stratigraphic 1=1 Service ❑ API Number: 50-029-20480-01-00 7. If perforating: 8. Well Name and NumLOC C I t E D What Regulation or Conservation Order governs well spacing in this pool? ,fib Will planned perforations require a spacing exception? Yes 0 No RI PBU 11-04A MAR 21 2016 9. Property Designation(Lease Number): 10. Field/Pools: flT S 4 111,114 ADL 0028325 - PRUDHOE BAY,PRUDHOE OIL - OG 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9355 - 9084 - 9100 8831 9100/9075 9101/9193 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 29-109 28-108 1530 520 Surface 2684 13-3/8"72#L-80 28-2713 28-2712 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development p Service ❑ 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Il • WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG Li Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Sinnok,Ralph be deviated from without prior written approval. Email Ralph.Sinnok@bp.com Printed Name Sinnok,Ralph Title Production Engineer 1 / Signature �� Phone 19075644630 Date 0 3/'1 7/ 10 I COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes❑ No ❑ Spacing Exception Required? Yes❑ No Q' Subsequent Form Required: ,/,..67,90-?--d---- COMMISSIONER APPROVED BYTHE Approved by: COMMISSION Date: Q—/�tb�//V`7Z l2/l T ORIGINAL RBDMS LA. APR 1 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • G1 ,0 0 0 0 0 0 0 0 c N CO O N N O O 76 N U x) 00000000 i CO CO N- r CO CD CO CO 7 LO O) CO CO NY V CO Cfl CO CO 00 CO N LC) CO O N 1` CO O •- O CO 00 CO V CO f� to O N CO N N- CO CA CO CO i "Ct O) CO O) CO CO N "Cr N N N N- C7 N N r t.- CO CO G) OMCL) v- 000O) O O co Ct LO O C) 1` LC) L() N CO CA 00 co V yam Q 0 000 'cY � O N N N N- C0 N L() =r '- (` CO CO •_ _ • W O O a O O O 00 00 CO O C7 O J co COc (� •N NCY CSO CLO Cr c O 00 00 N 0) v.- U O LC I� N N(NJ CO O) �t V' L `Cr N- N N- (NJ CO CO 00 CO N- O) (NJ `— 6) J CN — LC) O O CO W W ct F- Q Q •N O� U 0 0 co U0u_ r' EtccZZ Z W W W W 00 00 ODHZ Z Z J D • • a, N N N- 00 N I[) N- CO t() CO Tr . O CO I,- N , U) O 6) 00 O O a) 1- 6) 63 V (O N- ti (N p 1� aD co co co O 6) p co co cc 00 00 co co > I- Q O L() O) V r L() N- t 00 co co . O) co M O O O N r 00 O) 00 a co co cr) co O co 00 oo OMO CO O) p co c000 °Oc00000 0 2 w a w z w W w 0 p I- < J O V1 J Y () O m O O „<, Y Y rY g _ M � O CO O) 00 O7 O J J J ¢ ¢ (n W ami O O O r CO CY O U _U U_ .w_i W W 0 - 0 0 0) O) O O O) O O 6) Z Z Z O J J J 0 J CI) 2 = 2 Z t] p O F_ a z W W w a Q ca izr Q OI 0. r O I- C L N r 0 CO CO O) CO O 0 CO O OLO CO OOONM V I- }I p O) O) O) O) O) O) a) O) L a N O Ir U_)— = O OO co J d 2 2 2 O cn co w• cn cn a) .2 a a, O U c LL. LL d (n (/) (n (/) (/) QQmmmmmm 0. O a, d a f�'0r L() L() co Ln L() r- r r r r r 0 0 O O O O O O co, co) W a Z O N N N N N N N N Z U ¢ w LO 0 0 0 0 0 W O J p w LL N N N N Z a J U W W U W 0 00 N- N- N- N- N- m Q = W J J J D ¢ ¢ a w a J-1 L¢L d o a, E 2Q Q Q Q Q Q Q Q .4- -1- 00000000 a s co O a nl tr a m a a aU J V- r r r r r r r C'1 W a ¢ ¢ m m W w u. cn cn a rr • • Packers and SSV's Attachment ADL0028325 SW Name Type MD TVD Depscription 11-04A PACKER 7621.25 7375.86 7" Liner Top Packer 11-04A TBG PACKER 8388.33 8127.71 4-1/2" Baker S-3 Hydro Set Packer 11-04A TBG PACKER 8540.37 8277.56 4-1/2" Baker SABL-3 Packer • • bp • 011 -04 WSO w/ QCLL Scab Liner Wellwork Procedure Request To: T. Norene/L.Seymour: Well Services TL Date: 3/3/2016 J. Middendorf/R. Liddelow: Wireline Team Lead AFE: From: Eric Dickerman IOR: Est. Cost: Subject: 11-04 WSO w/ QCLL scab liner Job Sequence 1. S Drift to HEX/ Pull HEX plug / Drift to TD/ DGLV/ MIT-IA/Stack QCLL liner/ Drift QCLL 2. F A/SL - Load IA/ MIT-IA 3. C Deploy QCLL/Cement QCLL/ Cleanout cement 4. F WOC 3 days / Pressure test tubing and scab liner **SL may be able to do PT** 5. S DMY Gun Drift/Set GLV 6. E Perforate Job Objective: Water shut off. Run and cement QCLL scab liner. Reperf target production zones. Background: 11-04A is a 22P, 23P, and 25P producer only with a HEX plug set at 9,100' MD to isolate all other perforations below the 22P. The HEX plug was set on 7/10/15 to shutoff-25% of the water production. The HEX plug was ineffective in benefitting the well. The water rates remained the same. The most likely cause to this well not benefitting from the HEX plug set is due to drawing down more on the upper set of perforations that made about 55% of the water production (based off 8/22/14 PPROF splits). The plan forward is to isolate all sets of perforations and to re-perforate the major oil producing set in the 22P (-90% oil from PPROF). The modeled benefit from PROSPER estimated 1,150 bopd; 4,000 bwpd; and 36 mmscfd of formation gas (31,000 GOR & 78% WC) by producing only 9,080-9,096' MD based off the PPROF from 8/22/14. The offset/analog producers in the same injection pattern are 11-18 and 11-13A. 11-13A produces 950 bopd; -4,000 bwpd; and 42 mmscfd of formation gas (45,000 GOR & 80% WC) with a . 11-18 produces 940 bopd; 5,800 bwpd; and 36 mmscfd of formation gas (38,000 GOR & 86%WC). 11-04A currently produces 540 bopd; 7,700 bwpd; 24 mmscfd of formation gas (45,000 GOR & 93% WC). The objective of this SOR is to pull the HEX plug @ 9,100' MD, set a QCLL scab liner and cement squeeze the liner/scab annuli, and re-perforate the 22P. Shutting off the water from the lower and upper set of perforations increases the drawdown on the oil bearing perforations. The 66% risked incremental IOR benefit is 105 bopd based off production data, PPROF, and PROSPER model Page I 1 of 6 11-04-WSO-12/14/15 . • Program Contacts: Work Phone Mobile Phone Eric Dickerman 564-4277 307-250-4013 Ralph Sinnok 564-4630 907-304-2523 Wellbore Volumes Top Bottom Size ID Capacity Volume MD MD TBG 0 8599 4-1/2" 12.6# 3.958" 0.0152 bbl/ft 131 bbl LNR 8599 9185 7" 29# 6.184" 0.0371 bbl/ft 22 bbl IA 0 7621 9-5/8" 47# x 4-1/2" 12.6# - 0.0535 bbl/ft 408 bbl IA 7621 8396 7" 29# x 4-1/2" 12.6# - 0.0175 bbl/ft 14 bbl Total IA Volume 422 bbl Cement Volume Volume Note 7" 29# LNR x 3-1/2" annular fill up 15bbl Volume from PBTD to TBG tail (9185' — volume 8599') Total cement to pump 23bb1 40% excess Cement Properties Ppg 15.8 ppg Unislurry Glass G. Field blend to be +/- 0.1ppg of lab blend. Slurry Temp Between 80deg F and 110 degF API Fluid loss 40-200 cc Thickening Time 6 hrs Compressive strength 2000psi at 24 hrs Batch mix Cement Thickening Time Activity Time (hrs) Shearing time, quality control, PJSM 1 Cement displacement 1 Cement contamination 3 Safety 1 Minimum required thickening time 6 Cement Ramp —NEEDS WORK Time Temp (deg F) Pressure 0:00 90 0 1:00 90 0 2:00 110 3000 2:30 150 3000 3:00 160 4000 6:00 170 3000 7:00 174 3000 8:00 174 3000 Pagel 2 of 6 11-04 WSO-12/14/15 • Planned Procedure: Slickline w/ Fullbore assist Drift/ Pull HEX plug / Drift to TD/ DGLV/ MIT-IA/ Stack QCLL liner 1. Drift to HEX plug. 2. Pull HEX plug 3. Drift and tag TD with DMY whipstock drift or equivalent, and TEL. 4. Pull GLVs from STA #3 and #4 5. Set DGLV in STA# 3 and #4 6. MIT-IA to 2500psi 7. Stack -600ft 3-1/2" 13Cr QCLL liner on X Nip at 2014' MD. a) See attached diagram of 3-1/2" QCLL Liner. 8. Drift QCLL liner Coil Deploy QCLL / Cement QCLL/ Cleanout cement Deploy QCLL LNR 9. Run QCLL LNR to bottom. Paint flag #1. a) Liner will no go out on XN Nip at 8587' MD. b) Liner will seal in the polished bore of XN Nip at 8587' MD. c) Stage collar in liner will be open. Cement LNR Tentative Pump schedule: Stage Volume Fluid (bbl) Well Kill 230 1% KCI Underbalance 125 Diesel Spacer#1 10 Freshwater Cement 40 LARC Spacer#2 15 Freshwater CT FP CT volume meth Spacer#3 10 1% KCI Contamination -50 1.25 ppb Powervis Cleanout 250 1%KCI Freeze Protect 40 Diesel Page 13 of 6 11-04 WSO-12/14/15 . S Well Kill 10.Pump -230 bbl 1% KCI for well kill while POOH after deploying liner. Underbalace 11.RBIH to flag #1 with ORC (One Run Completion) cementing valve stinger assembly while pumping -125bb1 (1.0x backside volume to top perfs) of diesel down CT backside to maintain positive baseline WHP (should give 100psi of WHP). Cement Liner 12.RIH and sting in to cementing valve, paint flag #2. 13.Batch mix cement. a) 23bb1 of 15.8ppg Unislurry Class G 14.Cement liner maintaining 1:1 returns up backside (if possible). a) Establish 1:1 returns before cement reaches ORC stinger. b) WCTOC (no cement behind 3-1/2" liner) = 7160' 15.Unsting from cementing valve with -2 bbls cement left. 16.PUH and shift stage collar closed. 17.RBIH to flag #2 and circulate/contaminate excess cement with freshwater spacer and PowerVis. 18.POOH Contaminate/Cleanout Cement 19.RIH with JSN to -7160' and make three passes (down, up, down) from 7160' to flag #2 contaminating with 1.25ppb PowerVis, taking returns up backside. 20.At flag #2, POOH at 80% to 8700' (-100' above top of liner) while still on gel. a) This will leave gel in liner. 21.Swap to 1% KCI and continue to POOH at 80% making repeat passes across jewelry and tree. 22.Freeze protect well with diesel. Fullbore WOC 3 days / Pressure test tubing and scab liner 23.After WOC for 3 days, PT TBG and scab liner to 2,000psi. Record LLR if test fails. a) *****SLICKLINE or DHD MAY BE ABLE TO PERFORM PT WITH TRIPLEX***** Page 1 4 of 6 11-04 WSO-12/14/15 • Slickline DMY Gun Drift/ Set GLV 24.Drift to corrected TD with DMY guns for 2" OD x 20' perforating guns. 25.Set new gas lift design. Eline Perforate 26.Reperf per attached Perforating Procedure. a) Perf interval 9,080' — 9,096' b) Tie in log: Baker RPM CO on 7/6/15. Page 15 of 6 11-04 WSO-12/14/15 • • 8500 Casing 853 ft •----------- 8500 - -8500 tubing 99 ft .a, 8540.31 Packer 4.29 ft 8570.34 X Nipple 1.15 ft -- - ------------------- 8580.29 Depl Sleeve w/3.79 No Go Sub w/PKG 6.8 ft --- 8594.09 Cement top 590.91 ft 8587.02 XN Nipple 1.22 ft ------- ------------------- 8594.09 Stage collar 3 ft 8598.13 W LEG 1.3 ft ---'-- -- 8607.09 QCLL 1.61 ft -_..__.._-__ 8639.7 QCLL 1.61 ft -------- 8672.31 QCLL 1.61 ft --"---"' - 8998.41 QCLL L61 ft - 9022 Perfs 21 ft - 9031.02 QCLL L61 ft 9051 Perfs 13 ft -"-' QC11 1.61 ft 9080 Perfs 16 ft - - --------- 9063.63 - 9096.24 QCLL 1.61 ft 9108 Perfs 10 ft - "' 9128 Perfs 20 ft -- "- "`------- 9128.85 QCLL 1.61 ft 9161.46 QCLL 1.61 ft -- 9168.07 ORC 0.8 ft ___________ 9173.87 4.5 X lock anchor 195 ft _ _ 9175.22 Ported tail pipe 10.12 ft ----^• 9185 Fig(RCP)168 ft 2/14/15 II = 4-1/16'aw 1AELLF-FAD= 11KEVOY • S411/Y NOTE: -"CHROME TBG&LIkIR"' ACTUATOR= BAKER C I 1 -04A GB.ELEV= 56' Br'LEV= NA i I 4 -kaii;-- - - 4150' * 4 4 li 1767 H9-5/8"I-ES ES CEMENTER x krigTe=----iii;7446-4- .6 0, • 1 Datum MD= 9123' I --' 1779' —9-5/8"BKR BOP Datum TVD= 880(755 Mr, 0 . .4. 'I- 9-5/8'BOWEN CSG PATCH,47#, H 1806' L-80 HYD 563,ID=8.681' I I 2014' —4-1/2"1-ES X M3,ID=3.813' 13-3/8'CSG,72#,N-80,ID=12.347" I— 2710' 1-41 Ili GAS LFT MAICRELS ST MD TVD DEV TYPE VLV LATCH PORT TATE 4 3457 3457 0 MMG DOPE RK 16 10/20/11 3 5851 5741 28 M1A3 SO FK 20 10/20/11 Minimum ID =3726" @ 8687' 2 7476 7237 17 FAMG DMV RK 0 08/14/11 1 8288 8029 10 KBG-2 DMV BK 0 08/14/11 4-1/2" OTIS XN NIPPLE ?? I—FISH-4 GRAFPLE LEGS(09/30/11) 7614' —r BKR TEf3ACK SLV,ID=5.31" l J P 7621' —9-5/8"X TBKR LTP w/BKR LINE HGR,E)=-6,19-7 9-5/8"CSG,47#,L-80ID=8.681" 9-5/8"PK LOUT WIsIDOW(11-04A) T786'-7831 --- ' 8365' —4-1/2'HES X MP 13=3,813' , — T/88* If 7'LINFt,29#,N-80 XO TO 13CR-80 NSCC — 8441' 11111 8396' —7"X 4-1/2"BKR 5-3 pKR,o=3,875" fik FERFORATION SUMMARY * Ili 8430' —4-1/2'FES X MP,ID=3.813" i REF LOG: Z-L1 ON 03/01/94 11/4 8 FIST SIGMA ON 09/06/10 851r —r X4-1I2'UNIQUE OVERSHOT ANGLE AT TOP FEF : 8' ,.,9022' 8530' —4-1/2'TBG STUB(MILLED 05/20/09) Note:Refer to R-oduction DB for historical pe data SIZE SFF FITERVALOpn/sn-, DATE 40 8540 —7'X 4-1/2"BKR SABL-3 12KR I)=3.875" 3-3/8' 6 9022-9043 0 02/04/11 3-3-3/8" 6 9051-9064 0 02/04/11 * \ilk 1, 8570' —4-1/2'OTIS X MP,ID=3.813" 3/8" 6 9080-9096 0 07/29/09 3-3/8' 6 9108-9118 C 07/29/09 11), - 13587' H4-1/2"OTIS XN NIP,Et=3.725" 3-3/8" 6 9128-9148 C 07/29/09 3-3/8' 2 9139-9149 S 05124/98 2-1/2' 4 9170-9190 C 03/22/94 6599' —14-1/2"WLEG,V=3.9513" 8691' —BAC Tr LOGGED 03/13/95 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,ID=3.958" H 8599' t 7"MARKER JOINT(19') 8751' -...11 9193' ]—FISH: FASCRLL PLUG 1./TERWELL 363-700 HEX FLUG,4-1/2'G FN(07/10/15) — 9100* FUSI-ED TO BTM ii (TAGGED 06/03/09) :40 PBTD 9312' Ag 4itb6 r LNR,29#,13CR-80 NSCC,.0371 bpf,ID=6.184" — 9353' LATE REV BY COMENTS - DATE REV BY CORM:NTS PRUDHOE BAY UNIT 07125/80 ORIGINAL COMPLETION 08/16/11 TA/PJC GLV C/O(8/14/11) WELL: 11-04A 03/05/94 RIG SIDETRACK 10/10/11 RCT/PJC FULL EP 8 FISH OH(09/30/11) PERMIT No: 1940230 05/30/09 014 MO 10/10/11 PJC I KEE 00(10/08/11) AR No: 50-029-20480-01 02/12/11 AMA9PJC ADPERF/SET EP(02/04-06111) 10/31/11 JM) GLV C/0(10/20/11) SEC 33,T11N,R15E604'Ftl.,&8 FEL 02/12/11 J*LJPJC FISH D/33TH CORRECTION 07/31/15 JCM/JM3 SET 1-EX PLUG(07/11/15) 04/23/11 PAW PJC DUO.FSLUGGITS(04/14/11) BP IBtploratIon(Alaska) - - STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM( N t. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program V Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:4 ' #E)C,1 vq 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 194-023 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20480-01-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 11-04A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9355 feet Plugs measured 9100 feet true vertical 9084 feet Junk measured 9193 feet AUG 1 0 2015 Effective Depth: measured 9100 feet Packer measured 8396.25,8540.31 feet true vertical 8831 feet Packer true vertical 8135.51.8277.5 feet G c C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 30-110 30-110 0 0 Surface 2684 13-3/8"72#L-80 26-2710 26-2710 4930 2670 Intermediate Production 8507 9-5/8"47#L-80 24-8531 24-8268 6870 4760 Liner 1739 7"29#13CR80 7614-9353 7369-9082 8160 7020 Perforation Depth: Measured depth: 9022-9043 feet 9051-9064 feet 9080-9096 feet 9108-9118 feet 9128-9139 feet 9139-9148 9148-9149 feet 9170-9190 feet True vertical depth: 8754-8775 feet 8783-8795 feet 8811-8827 feet 8839-8849 feet 8859-8870 feet 8870-8879 8879-8880 feet 8901-8920 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 30-8599 30-8336 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8396.25 8135.51 true vertical depth) 4-1/2"Baker SABL-3 Packer 8540.31 8277.5 12.Stimulation or cement squeeze summary: Intervals treated(measured): schtiVIECI NOV 1 22015 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 520 24506 7184 1592 831 Subsequent to operation: 478 27090 6113 2025 853 14.Attachments:(required per 20 AAC 25.070 25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp.com Printed Name ummerhays,NN/ (WIPRO Technologi Title Petrotechnical Data Manager 11P7, Sit Leger, // ..i.., , Phone +1 907 564-4035 Date 08/10/2015 Form 10-404 Revised 5/2015 it rt, q/ /!., 1 RBDMS AUG 1 4 20tubmit Original Only • • Daily Report of Well Operations PBU 11-04A ACTIVITYDATE SUMMARY ***WELL FLOWING UPON ARRIVAL***(profile-mod) TRAVEL FROM COIL SHOP, R/U PCE. 7/5/2015 ***CONT JOB ON 7/6/15 WSR*** ***CONT JOB FROM 7/5/15 WSR***(profile-mod) DRIFTED TBG w/3.70"WRP DRIFT, 4-1/2"TEL, 1-3/4" S. BAILER. LOC TT @ 8,572'SLM/8,591' ELMD (+19'CORR)TAG HARD BTM @ 9,166' SLM/9,185' ELMD (121'OF Rat Hole) RAN PDS 40 ARM CALIPER FROM TD @ 9,166'SLM TO 8,300'SLM. (good data) 7/6/2015 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/I/O=2000/1600/550 Assist E-Line(Borax Log). Pumped 3 bbls neat methanol followed by 211 7/6/2015 bbls 1% KcL down TBG to L&K well and assist with Logging. Continues on 7-7-2015. ***WELL SHUT IN ON ARRIVAL*** (E-LINE BORAX) INITIAL T/I/O=2250/ 1300/550. RU. PT. LRS RU/PT. LOAD WELL WITH 150BBL KCL. RIH WITH BAKER RPM TOOL. LOG GAS VIEW PASS AT 10FPM. 7/6/2015 ***JOB CONTINUED ON 07-JULY-2015*** ***JOB CONTINUED FROM 06-JULY-2015*** COMPLETE GAS VIEW PASS#1 AND#2 FROM 9190'-8650'. COMPLETE THREE C/O PASSES AT 2 FPM FROM 9190'-8650'. COMPLETE STOP COUNTS AT 9160'/8986'/8961'/ 8923'/8858'/8773'. COMPLETE TWO BORAX PASSES AT 20 FPM FROM 9190'-8650'. 200 BBL KCL FLUSH PUMPED. COMPLETE FLUSH PASS 20 FPM. POOH. LRS RD. SLB RDMO. WELL SI ON DEPARTURE. FINAL T/I/O = 0/ 1210/500 7/7/2015 ***JOB COMPLETED ON 07-JULY-2015*** Continues from 7-6-2015. Assist E-Line with RPM/Borax log. Pumped 607 bbl 1% Kcl while E-Line performed Logs. Then pumped 3 bbl Neat Spear, 172 bbl Borax pill followed by a 3 bbl Neat tail, Then Continued to pump 367 bbl of 1% Kcl for Logging and Flush, Followed by 40 bbl Crude for F/P TBG . **Job Complete** ..E-line still rigging down at departure, FWHP's =vac/ 1359/516 7/7/2015 SW C, WV=C, SSV= C MV= 0 IA and OA=OTG's ***WELL SHUT IN ON ARRIVAL***(SLB E-LINE SET HEX PLUG) INITIAL T/I/O = 2400/ 1200/500 RIH W/GR/CCL& LOGGED JEWELRY PASS FROM 9190'TO 8200'. RIH W/INTERWELL HEX PLUG (363-700) &SET TOP OF PLUG @ 9100' (PLUG SPECS= 9.56'OAL/3.63"O.D. /4-1/2"G Fishing neck -- PICTURE IN DIGITAL PICTURES ONLINE AND WELL FILES) FINAL T/I/O=2400/ 1200/500. 7/10/2015 ***JOB COMPLETE. WELL SHUT IN ON DEPARTURE.*** Fluids Summary BBLS Type 4 DIESEL 14 METH 1185 1% KCL 172 BORAX 40 CRUDE 1415 Total TRW= 4-1/16"CMI • ` 1AE LFEA0 MEVOY -04A NOTES: "'CHROME TBG&LHR"' ACTUATOR= BAKER C 11 • CKB.ELBA/= 56' BF.ELEV= NA KOP- 4150 �.� 1767 —I s-siaHES E5 ER8liEft MIX Angle= 30'6 6089 •'j' Ostium M)= 91_23' �� ( tum*di 8800'SS _4,--Hum —9-5/8'BKR EL,P 9-5/8'BOVVEI•I CSG PATCH,47#, H 1806' L-80 HYD 563,V=8.681' 2014' H4-1/2"FES X NP,D=3.81T GAS LFT MAICRELS 13-3/8'CSG,72#,N-80,D=12.347" — 2710' _41 ST IC ND DEV TYPE VLV LATa-I PORT DATE 4 3457 3457 0 MG DOlE RK 16 10/20111 3 5851 5741 28 MNG SO FITC 20 10120/11 Minimum ID =3.725" @ 8587' 2 7476 7237 17 MNG DRY RK 0 08/14/11 4-1/2" OTIS XN NIPPLE 1 8288 8029 10 KBG-2 DMY BK 0 08/14/11 ?? FISH-4 GRAR'LE LEGS(09130/11) 7614' Hr BKR TE BACK SIN,D=5.31' l 11 7621' —9-58'X r B BKR LTP w KR LARHGR.D=6.19'? 9-5/8"ML OUT WINDOW(11-04A) 7786'-7831' 9 5/8'CSG,47#,L-80,D=8.681' H 7786• I-- 8365' H412"IIS X MP,D=3.813' 7'LN111 8396' —IT X 41/2'BKR S-3 RO2,D=3.875' FR,29#,N-80 XO TO 13CR-80 NSCC —1 $441' 1 FEIF(XiAT10N SUMMARY 0 1 8430' —4-12'HES X NP,D=3.813" FIEF LOG: Z-DENSI ON 03/01/94 &RST SIGMA ON 09/06/10 8517' —r X 412'UNIQUE OV OVERSHOT ANGLE AT TOP FERE 8°r?9022' ‘ B530' —I412'TBG STUB(PALLED 0.5120109) Note:F lefer to Roduction DB for historical pert data 8540' 7'X4-12'BKR SABL-3 SIZE SFF INTERVAL OprJSgz DATE 40 1 3-3/8' 6 9022-9043 0 02/04/11 ` PKR D=3.875' 3-3/8" 6 9051-9064 0 02/04/11 �4 3-3/8" 6 9080-9096 0 07/29/09 8570' I—412'OT6 X NP,D=3.813' 3-3/8' 6 9108-9118 C 07/29/09 3-3/8' 6 9128-9148 C 0729/09 X13587' H4-1/2"OTIS XN NP,D=3.725' 3-38' 2 9139-9149 S 05/24/98 2-1/2" 4 9170-9190 C 03/22/94 8699' H4-12'INLEG,D=3,958' • 8681' H 6.1413 TT LOGGED 03/13/95 lk 4-1/2"TBG,12.6#,13CRI-80,.0152 bpf,0=3.958" H 8599' 7"MARKER JOM(19') 8751' I TE2V11 .L 363-7001-EX FLOG,4-1/2"G FN(07/10/15) H 9100' % M FISH: FASDRLL PLUG PUSHED TO BTM (TAGGED 06/03/09) FWD —I 931r OA'rLNF2 ,13CR-80CC,.0371 bpf,D=6.184' HIii DATE REV BY COM ENTS - DATE REV BY COMIEN S RILDHOE BAY UHT 07/25/80 ORIGINAL COMPLETION 08/16/11 TA/PJC GLV C/O(8/14/11) WE I: 11-04A 03105/94 RIG SIDETRACK 10/10/11 RCT/PJC PULL BP&RSH OH(09/30/11) PERMIT AT No: 1940230 05/30/09 D14 1611/0 10/10/11 PJC TREE CIO(10/08/11) AR No: 50-029-20480-01 02/12/11 AMAIPJC Ate/SET EAP(02104-06/11) 10/31/11 JM) GLV C/O(10120111) SED 33,111N,R15E604'R4.&8'FEL 02/12/11 JMJPJC ASH DOTH CORRECTION 07/31/15 JCMJMJ SET I-EX PLUG(07/11/15) 04/23/11466M PJC DLAPSLUGGffS(04114/11) _ BP aplora0on(Alaska) kgs-023 it BAKER PRINT DISTRIBUTION LIST HUGHES RECEIVED COMPANY BP Exploration Alaska,Inc. INTERMEDIATE FINAL Yes JUL 2 1 2 015 onandato,yi WELL NAME I1-04A RUN NUMBER I (manry) AOGCC FIELD Prudhoe Bay Unit BH SALESMAN Paul Canizares (mandatory) (mandatory) COUNTY North Slope BH DISTRICT Prudhoe Bay,AK (mandatory) (mandatory) STATE Alaska PAGE I OF I DATA LOGGED (mandatory) 7/u/201E LOG DATE: July 7,2015 TODAYS DATE: 7/18/2015 ivl.K.BENDER (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? SCANN c /n COMPANY ingt! JUL 2 2 2015 ADDRESS(FEDEXWILL NOT DELIVER TO P.O.Box) A B C D L.I.S. FILM PERSON ATTENTION #OF PRINTS#OF COPIESn #OF COPIESC #OF CCOPIES#OF COPIESn #OF COPIES nn 1 ConocoPhilllps Alaska Inc. 1 I 1 I 1 I 1 I I I Attn:Ricky Elgaricio A= 11-04A_RPM_PNC3D_RAW_07JUL2015_BHI.meta ATO 3-344 11-04A_RPM_CO_RAW_07JUL2015_BHI.meta 700 G Street Anchorage,AK 99510 B= *(Folder 1 on cd/dvd) 11-04A_RPM_PNC3D_RAW_07JUL2O15_13HI.meta ll-04A RPM CO RAW 0 7101.2 015 BHI.mets C= **(Folder 2 on cd/dvd) II-04A_RPM_PNC3D_RAW 07JUL2015 BHI.PDF 11-04A RPM CO RAW 07J111.2015 BHI.PDF D= ***(Folder 3 on cd/dvd) Il-04A_RPM_PNC3O_RAW_PASSDIUP_D7JUL2015_BHI.dlis 11-04A RPM PNC3O RAW PASS02UP 07JUL2015 BHl.dlis II-04A RPM PNC3O_BORAX RAW PASSOIOP 07)01.2015 BHI.dlis 11-04A RPM PNC30_BORAX RAW PASS02UP_075112915_BHI.duis Il-04A RPM PNC3D BORAX RAW PASSO3UP_07JU12015_881.dlis 11-04A RPM CD RAW PASSDIUP 07)01.2015 BHI.dlis 11-04A RPM CD_RAW PAS SD20P_071012015_8Hl.dlis 11-044 RPM CO RAW PASS03UP D7JUL2015 801.dlis ****(Folder 4 on cd/dvd;11-04A_RPM_PNC3D_RAW_PASSOIUP_07JU1.2DI5_BHl.1as II-04A RPM P8930 RAW PASS02UP 07JUL2015 BHLlas 11-04A RPM PNC3D_BORAX RAW PASSOIUP D7JOL2015 BHI.las II-044 RPM PNC3D BORAX RAW PASS02UP_07)912015_BHl.las II-04A RPM PNC3O BORAX RAW PASS03UP_O7JUL2015_BHl.las 11-944 RPM CO RAW PASSOIUP 07)01.2015 BHI.las Il-04A_RPM_CD_RAW PASSD2UP_07JU1.2015_1Thl.las 11-044 RPM CO RAW PASSD39P 07)01.2015 BHI.las 11-044_RPM_CO_RAW_STATIONARY_8773 07)01.2015_BHI.lax 11-044_RPM CO RAW STATIONARY_8858 07)01.2015 BHI.las 11-044 RPM CD RAW STATIONARY 8923 07)01.2015 BHl.las 11-044 RPM CO RAW STATIONARY 8991 07)912015 BHLlas 11-044 RPM CO RAW STATIONARY 8986 07)01.2015 BHLlas 11-04A RPM CO RAW STATIONARY 9160 07)1112015 BHLlas * Folder 1 on cd/dvd needs to be named"META" ** Folder 2 on cd/dvd needs to be named"PDF" **>r Folder 3 on cd/dvd needs to be named"DLIS" **7e* Folder 4 on cd/dvd needs to be named"LAS" 2 ExxonMobil,Alaska I 1 I 1 I 1 I 1 I I 'Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 ',Anchorage,AK 99503 3 State of Alaska-AOGCC I 1 I_ 1 I 1 I 1 I I I ,Attu:Makana Bender 333 W.7th Aye,Suite 100 SII Anchorage,Alaska 99501 4 DNR-Division of Oil&Gas I 0 I 0 I 1 I 1 I I Attu:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 3 3 4 4 TOTALS FOR ALL PAGES: 3 3 4 4 OPERABLE: Producer 11 -04A (PTD #194023.AxOA manageable by bleeds Page 1 o 2 Regg, James B (DOA) From: Reynolds, Charles (Alaska) [Charles.Reynolds @bp.com] ����o�►� Sent: Saturday, October 08, 2011 8:56 PM hl To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Huebel, Ross Cc: King, Whitney; Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike J (Swift) Subject: OPERABLE: Producer 11 -04A (PTD #1940230) IAxOA manageable by bleeds All, Following the servicing of the casing packoffs on Producer 11 -04A (PTD #1940230), an OA Repressurization test was conducted on 8/21/11 - 8/25/11. The OA build up rate was found to be 80 psi /day making the well manageable by bleeds. The tree has also — been changed out to assure surface integrity. The well is being reclassified as Operable and may return to production. Please notify Well Integrity if an increase in the OA build up rate is observed. Thanks, Charles Reynolds Filling in for... Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, August 02, 2011 2:52 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'S► wartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, • PS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Wel ervices Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; A , RES GPB West Wells Opt Engr; Bommarito, Olivia 0 Cc: AK, D &C Well Integrity Coordinator; King, W tney; Walker, Greg . (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike 3 (Swift Subject: UNDER EVALUATION: Producer 11 +4A (PTD #1940230) Sustained OA Pressure Over MOASP All, Producer 11 -04A (PTD #1940230) h confirmed sustained OA casing pressure above MOASP. The wellhead pressures were tubing /IA/9A equal to 460/1830/1050 on 07/31/2011. The well has been reclassified as Under Evaluation. Vie well may remain online while work is conducted to attempt to restore integrity. 10/10/2011 UNDER EVALUATION: Producer 1144A (PTD #1940230) Sustained OA Prere Over MOA... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, August 02, 2011 2:52 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bommarito, Olivia 0 Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike J (Swift) Subject: UNDER EVALUATION: Producer 11 -04A (PTD #1940230) Sustained OA Pressure Over MOASP Attachments: Producer 11 -04 (PTD #1940230) TIO Plot.doc; Producer 11 -04 (PTD #1940230) wellbore schematic.pdf All, Producer 11 -04A (PTD #1940230) has confirmed sustained OA casi essure above MOASP. The wellhead pressures were tubing /IA/OA equal to 460/183 0 on 07/31/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. OA_ SCP la.s`o MX(? Plan forward: 1. DHD: Outer Annulus Repressurization Test /Oh ce 2. Wellhead: Positive Pressure Packoff Test - Inner Casing (PPPOT -IC) A TIO plot and wellbore schematic have been included for reference. «Producer 11 -04 (PTD #1940230) TIO Plot.doc» «Producer 11 -04 (PTD #1940230) wellbore - schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) [ d r LU \ Aliffiret) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/8/2011 PBU 11-04A PTD #1940230 8/2/2011 TIO Pressures Plot Well: 11-04 4 000 3 000 111 Tbg IA 2,000 OA 00A —4— 000A On i 1,000 05/07/11 05/14/11 05/21/11 05/29/11 06/04/11 06/11/11 06/1 BM 06/25/11 07/02/11 07/09/11 07/16/11 07/23/11 07/30/11 TREE= CIW WELLHEAD = MCEVOY 411 SAFETY OS: ***CHROMETBG & LNR*** ACTUATOR = ' C 1 1 -044 KB„ELEV =, , , .. _55.0' EiF. ELEV = NA KOP = 4150' 4 Max Angle =30° @ 6099' .4 • 1762' I-19-5/8" HES ES CEMENTER .. QaTu m nii = --- 9123' . H9-5/8" BKR ECP Datum 1V D = 8800' SS 1 rl --- 1806' v 4 /4 • 9-5/8" BOWEN CSG PATCH, 47#, 1 1. L-80 HY D 563, ID = 8.681" ll 1 I 2014' H4-1/2" HES X NIP, ID = 3.813" I 13-3/8" CSG, 72#, N-80, ID = 12.347" 1-1 2710' 1 GAS LIFT MANDRELS 5. 3 o iy.) ST MD 'DID DEV TYPE VLV LATCH FORT DATE ,iiiii........iii. L 4 3457 3456 0 MMG DOME RK 16 06/02/09 3 5851 5741 28 MMG DOME RK 16 06/02/09 Minimum ID = 3.725" @ 8587' 2 7476 7236 17 MMG DOME RK 16 06/02/09 4-112" OTIS XN NIPPLE 1 8288 8029 10 KBG-2 SO BK 28 08/21/09 ......... 7614' H7" BKR TIEBACK SLV, ID = 5.31" I I .i._, 7621' 1- 9-5/8" X 7" BKR LTP w /BKR [ LNR HGR, ID = 6.19? 9-5/8" MILLOUT WINDOW (11-04A) 7786' - 7831' -- 8365' F-14-1/2" HES X NIP, ID = 3.813" I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 7786' 1 I 7" LNR, 29#, N-80 X0 TO 13CR-80 NSCC HI 8441' % 8396' H7" X 4-1/2" BKR S-3 PKR, ID = 3.875" I ik 44 11 PERFORATION SUMMARY 'fp. 8430' H4-1/2" HES X NIP, ID = 3.813" I REF LOG: Z-DENSI ON 03/01/94 & RST SIGMA ON 09/06/10 8517' H7" X 4-1/2" UNIQUE OVERSHOT I ANGLE AT TOP PERF: 8° @ 9022' 8530' 1-14-1/2" TBG STUB (MILLED 05/20/09) I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE fik 8540' 1- 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" 3-3/8" 6 9022 - 9043 0 02/04/11 3-3/8" 6 9051 - 9064 0 02/04/11 * IL I 8570' 1-14-1/2" OTIS X NIP, ID = 3.813" I 3-3/8" 6 9080 - 9096 C 07/29/09 3-3/8" 6 9108 - 9118 C 07/29/09 NI 8587' H4-1/2" OTIS XN NIP, ID = 3.725" I 3-3/8" 6 9128 - 9148 C 07/29/09 3-3/8" 2 9139 - 9149 S 05/24/98 2-1/2" 4 9170 - 9190 C 03/22/94 8599' H4-1/2" WLEG, ID = 3.958" I 1 1 I L 8591' 1-1ELMD TT LOGGED 03/13/95 I - % 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" H 8599' J % 9064' 1- 3-3/8" BKR CROSS- 17" MARKER JOINT (19') I 8751' ..._-,--=-- , FLOW IBP )02/06/11) _ I (04/14/11) H 9071' SI-M ----- 9193' 1 FISH: FASDRILL PLUG PUSHED TO BTM (TAGGED 06/03/09) I PBTD I 9312' 4 4: 1 41E44 6 6 I 7" LNR, 29#, 13CR-80 NSCC, .0371 bpf, ID = 6.184" H 9353' 416 DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT - 07/25/80 ORIGINAL COMPLETION 09/09/09 RRD/TLH ADPERF (07/30) & GLV C/O (08/21/09) WELL: 11-04A 03/05/94 RIG SIDETRACK 02/12/11 A MW/PJC A DPERF / SET IBP (02/04 - 02/06/11) PERMIT No: P 1940230 05/30/09 D14 RWO 02/12/11 JNL/PJC FISH DEPTH CORRECTION API No: 50-029-20480-01 06/12/09 DB/JMD DRLG DRAFT CORRECTIONS 04/23/11 MBM/PJC DUMP SLUGG1TS (04/14/11) SEC 33, T1 1N, R15E 604' FNL & 8' FEL 06/13/09 JMD GLV C/O (06/02/09) 06/27/09 TLH/TLH TBG STUB CORRECTIONS BP Exploration (Alaska) 02/23/11 Scierger NO. 5698 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD P2 -31A BCRD -00081 TEMP & X/Y CALIPER SURVEY aO'- .---JC //) 02/06/11 1 $/S 1 E -03A BL65 -00015 SCMT ..",.)6, f —alb- 01/27/11 X1(66 1 1 04 -21 _ BG4H -00031 PRODUCTION—PROFILE I Q... 02/02111 1 - ar r 1 1 04 -17 BG4H -00029 INJECTION PROFILE ;lIQi .01, 01/31/11 1 0 01 1 s P2 -52 BCRD -00082 PRODUCTION PROFILE — f 02/09/11 1 [� a 1 11 -04A BG4H -00032 X-FLOW CHECK IBP / " (! - h - 02/06111 1 (j�Jl 1 W -202 BMSA -00005 ISOLATION SCANNER —_f 01/30/11 �6$n/ 1 1 15 -268 13D88-00088 MCNL 6 Ca-- / �j 12/1 3/10 1 QM 15 -11C BD88 -00081 MCNL (� — /Cp. 01/06/11 1 Th` Ib 1 07.09A BD88 -00078 MCNL } — / 12/08/10 1 1 K -12B BCUE -00094 MCNL dS - /4/ 11/23/10 1 ( ' } 1 • E -35B BD88 -00077 MCNL /4„) — / (p r 12/05/10 1 1 B -04A BAUJ -00055 MCNL /() — (1) V 11/21/10 1 b � 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • kmvirriuto MA E 1 ' � I MAR 1 211 # PA S; . COM 4, , A, STATE OF ALASKA ALASKAO AND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ 5€`f ,j6P Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ig Exploratory ❑ 194 -0230 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . -50- 029 - 20480 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028325 ..• PBU 11 -04A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9355 feet Plugs (measured) 9075 feet true vertical 9084.3 feet Junk (measured) 9193 feet Effective Depth measured 9311 feet Packer (measured) 8396 8540 feet true vertical 9040.59 feet (true vertical) 8135 8277 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" SURFACE - 110 SURFACE - 110 Surface 2710' 13 -3/8" 72# N -80 SURFACE - 2710 SURFACE - 2710 5380 2670 Intermediate 7786' 9 -5/8" 47# L -80 SURFACE - 7786 SURFACE - 7535 6870 4760 Production Liner 1739' 7" 29# N- 80/13CR80 7614 - 9353 7369 - 9082 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ - _ True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 8599 SURFACE - 8335 Packers and SSSV (type, measured and true vertical depth) 7" X 4 -1/2" BKR S -3 PKR 8396 8135 7" X 4 -1/2" BKR S -3 PKR 8540 8277 9 i i G 12. Stimulation or cement squeeze summary: Intervals treated (measured): ry f1 q +� E E 0 9 */(111 Treatment descriptions including volumes used and final pressure: LU I * �'� )� 470, ��``�* $il)fl 13. Representative Daily Average Production or Injection CAMP +, n Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 833 46,370 2,676 1,088 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil v. El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam- .: Lastufka i Title Data Manager Signatur= gigi\ Phone 564 -4091 Date 2/7/2011 .FMS FEB 0 91 011 ' Y` 2-/0-# Form 10 -404 Revised 10/ Submit Original Only d am` P--710//7 11 -04A 194 -023 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11 -04A 3/22/94 PER 9,170. 9,190. 8,900.6 8,920.45 11 -04A 10/10/94 APF 9,139. 9,149. 8,869.85 8,879.76 11 -04A 4/24/95 BPS 9,160. 9,197. 8,890.68 8,927.39 11 -04A 4/25/95 SQZ 9,139. 9,149. 8,869.85 8,879.76 11 -04A 4/26/95 BPP 9,160. 9,197. 8,890.68 8,927.39 11 -04A 5/4/98 SPS 9,164. 9,197. 8,894.65 8,927.39 11 -04A 5/6/98 SPS 9,162. 9,164. 8,892.66 8,894.65 11-04A 5/15/98 SQZ 9,139. 9,149. 8,869.85 8,879.76 11 -04A 5/24/98 SQZ 9,139. 9,149. 8,869.85 8,879.76 11 -04A 5/25/98 SPR 9,139. 9,195. 8,869.85 8,925.41 11 -04A 5/14/08 BPS 8,546. 9,190. 8,283.11 8,920.45 11 -04A 3/2/09 BPP 8,546. 9,190. 8,283.11 8,920.45 . 11-04A 3/20/09 BPS 8,546. 9,190. 8,283.11 8,920.45 11 -04A 6/3/09 BPP 8,546. 9,190. 8,283.11 8,920.45 11 -04A 7/29/09 APF 9,080. 9,096. 8,811.34 8,827.2 11 -04A 7/29/09 APF 9,108. 9,118. 8,839.1 8,849.02 11 -04A 7/29/09 APF 9,128. 9,148. 8,858.94 8,878.77 11 -04A 2/4/11 APF 9,022. 9,043. 8,753.85 8,774.67 11 -04A 2/4/11 APF 9,051. 9,064. 8,782.59 8,795.48 11 -04A 2/6/11 BPS 9,075. 9,190. 8,177.64 8,920.45 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 11 -04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ^IY 2/4/2011 '`'WELL SHUT IN ON ARRIVAL""" (E -LINE: PERF) INITIAL T /I /O = 0/1500/400 PSI INITIAL VALVE POSITION = WING, SSV, SWAB = CLOSED. MASTER = OPEN FIRST PERF RUN 13' OF PJ HSD GUN PERFORATED FROM 9051'- 9064' ` CCL ! I TO TOP SHOT = 10.4', CCL STOP DEPTH = 9040.6'. SECOND PERF RUN 21' OF PJ HSD GUN PERFORATED FROM 9022' - 9043' CCL TO TOP SHOT = 8.4', CCL STOP DEPTH 9013.6'. ;API DATA. 3 3/8 POWER JET HSD GUN 6 SPF, 60 DEG PHASE, PENETRATION = 136.5 ", ENTRANCE HOLE = 0.37 ". FINAL VALVE POSITION = WING, SSV, SWAB = CLOSED. MASTER = OPEN FINAL T /I /O = 1850/1400/350 PSI 1 ***JOB TO BE CONTINUED ON 5 -FEB -2011 WELL SHUT -IN ON DEPARTURE * ** 1 � � 2/5/2011 ; ** *JOB CONTINUED FROM 4- FEB - 2011 * ** (E- LINE: CROSS FLOW) B INITIAL T /I /O = 0/1400/350 PSI INITIAL VALVE POSITION = WING, SSV, SWAB = CLOSED. MASTER = OPEN LOGGED SHUT IN UP /DOWN PASSES AT 40, 80 AND 120 FPM FROM 8900' TO 9185'. CROSSFLOW OBSERVED, BAKER NOTIFIED TO RUN CROSSFLOW IBP. FINAL VALVE POSITIONS = WING, SSV, SWAB = CLOSED. MASTER = OPEN 1 FINAL T /I /O = 1600/1400/350 PSI 1 * ** JOB TO BE CONTINUED 6 -FEB -2011 WELL SHUT IN ON DEPARTURE * ** 2/6/2011= ** *JOB CONTINUED FROM 5- FEB - 2011 * ** (E -LINE: CROSSFLOW IBP) ;INITIAL T /I /O = 0/ 1325/325 PSI ;INITIAL VALVE POSITION = WING, SSV, SWAB = CLOSED. MASTER = OPEN SET CROSSFLOW IBP 3.37 " MI! • 1 ' CCL TO MID - ELEMENT = I42.15' AND CCL STOP DEPTH = 9032.9'. IBP SET AFTER 2 HOURS BUT DID NOT !SHEAR OFF. DECISION TO PULL OFF CROSSFLOW IBP AT EMERGENCY ;RELEASE WAS MADE. A 1 3/8 FISHING NECK WAS LEFT IN THE WELL AT AN ESTIMATED DEPTH OF 9064' FINAL VALVE POSITIONS = WING, SSV, SWAB = CLOSED. MASTER = OPEN 'FINAL T /I /O = 500/1300/300 PSI C * ** JOB COMPLETED WELL SHUT IN ON DEPARTURE * ** J FLUIDS PUMPED BBLS 5 60/40 195 1% KCL 50 CRUDE 250 TOTAL TREE = CIW WELLHEAD = MCEVOY 1 SAFETY NO: ***CHROME TBG, LNR & NIPPLES*`"' ACTUATOR = BAKERC 1 1 -04A KB. ELEV = 55.0' • BF. ELEV =- NA KOP= 4150' ' ••• 0 • Max Angle = 30° 6099' � � 1 ► 1762' I-1 518" HES ES CEMENTER I @ •`0 0. - Datum MD = 9123' � • • • � Datum TV D = 8800' SS ► �� ►�1 1779' H 9 -518" BKR ECP I 9 -5/8" BOWEN CSG PATCH, 47 #, —1 1 806' V i ° 4 L -80 HYD 563, ID = 8.681" ' I 2014' ,- 14 -1/2" HES X NIP, ID = 3.813" 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2710' } GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3457 3456 0 MMG DOME RK 16 06/02/09 3 5851 5741 28 MMG DOME RK 16 06/02/09 Minimum ID = 3.725" @ 8587' 2 7476 7236 17 MMG DOME RK 16 06/02/09 4-1/2" OTIS XN NIPPLE 1 8288 8029 10 KBG -2 SO BK 28 08/21/09 7614' H 7" BKR TIEBACK SLV, ID = 5.31" I 1 1 7621' I — 9 -5/8" X 7" BKR LTPw /BKR LNR HGR, ID= 6.19 "? 9 -5/8" MILLOUT WINDOW (11 -04A) 7786' - 7831' I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 7786' 8365' H 4 -1/2" HES X NIP, ID = 3.813" • 8396' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I Ali 8430' 1 HES X NIP, ID = 3.813" I 17" LNR, 29 #, N -80 XO TO 13CR - 80 NSCC H 8441' 8517' H 7" X 4-1/2" UNIQUE OVERSHOT 1 PERFORATION SUMMARY 8530' H 4 -1/2" TBG STUB (MILLED 05/20/09) I REF LOG: Z- DENSILOG ON 03/01/94 854.0' I — 7" X 4 -1/2" BKR SABL -3 ANGLE AT TOP PERF: 8° @ 9080' �� PKR, ID = 3.875" Note: Refer to Production DB for historical perf data 44, SIZE SPF INTERVAL Opn /Sqz DATE II 1 8570' I--I -1 /2" OTIS X NIP, O = 3.813" I 3 -3/8" 6 9080 - 9096 0 07/29/09 i Q U Q Q 3 -3/8" 6 9108 - 9118 0 07/29/09 i / M 8587' I—I -1/2" OTIS XN NIP, ID = 3.725" I 3 -3/8" 6 9128 - 9148 0 07/29/09 �(� ?5 3 -3/8" 2 9139 - 9149 S 05/24/98 2-1/2" 4 9170 - 9190 C? 03/22/94 8599' H 4 -1/2" WLEG, ID = 3.958" I I 8591' H ELMD TT LOGGED 03/13/95 14 -1/2" TBG, 12.6#, 13CR - 80, .0152 bpf, ID = 3.958" I—I 8599' 1 I FISH: FASDRILL PLUG 17" MARKER JOINT (19') I-1 8751' ` G,' 13 PUSHED TO BTM % (p,3, bq (05/27/09) IPBTD 9312' 41■44414 1 7" LNR, 29 #, 13CR - 80 NSCC, .0371 bpf, ID = 6.184" H 9353' ∎ j► DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 07/25/80 ORIGINAL COMPLETION 09/09/09 RRD/TLH ADPERF (07/30) & GLV C/O (08/21/09) WELL: 11 -04A 03/05/94 RIG SIDETRACK PERMIT No: 1940230 05/30/09 D14 RWO API No: 50- 029 - 20480 -01 06/12/09 DB /JMD DRLG DRAFT CORRECTIONS SEC 33, T11 N, R15E 604' FNL & 8' FEL 06/13/09 JMD GLV C/0 (06/02/09) 06/27/09 TLH/TLH TBG STUB CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 ?A Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 1� Z" )/ —0 q/4- Mr. Tom Maunder 4 41/4 ��- -. Alaska Oil and Gas Conservation Commission 1.r. 4 ; 333 West 7 Avenue iK 0 3 20 Anchorage, Alaska 99501 4 no; COria. C.7 , ' ,,Sion Subject: Corrosion Inhibitor Treatments of GPB DS 11 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement - date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 _ NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 _ NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA _ 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 • 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA _ 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 10/26/10 Schlumberger NO. 5828 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartxer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job If Log Description Date BL Color CD 11 -04A BCZ2 -00022 RST 1 09/06110 1 1 F -47B BCUE -00038 MCNL 1 08/04110 1 1 F -048 AZ2F -00061 MCNL 08/20/10 1 1 15 -308 BAUJ -00026 MCNL 05/30/10 1 1 L1 -09 BBSK -00027 RST 08/24/10 1 1 05 -33A BCRD -00037 CH EDIT P C -GR USIT 07/27/10 1 13 -21A BD88.00038 CH EDIT PDC -GR GR -CCL _ 08131/10 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: SP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 NOV 2 20% 69` 100 STATE OF ALASKA AL OIL AND GAS CONSERVATION CO SION REP T OF SUNDRY WELL OPE~TIONS ~E~ I~ ~~~` ~ ~~~ ~ ~ 2009 1. Operations Performed: 1~~~Ska "E ~~~~ ~~;~~, ~~„~~.,;~Si~;~ ~ ~ ^ Abandon ~ Repair Well ed V~/efl Re-~~~,~ ~s,p en ^ Plug Perforations ^ Stimulate S ~ ~ ~ ~ ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 194-023 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20480-01-00 7. KB Elevation (ft): 54 26' 9• ~Nell Name and Number: . PBU 11-04A 8. Property Designation: 10. Field / Pool(s): ADL 028325 Prudhoe Bay Field 1 Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9355' feet true vertical 9084' feet Plugs (measured) None Effective depth: measured 9311' feet Junk (measured) 8620' true vertical 9041' feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2710' 13-3/8" 2710' 2710' 4930 2670 Intermediate 7786' 9-5/8" 7786' 7535' 6870 4760 Production Liner 1739' 7" 7614' - 9353' 7369' - 9082' 7240 5410 ~;~~~~ „ ~~ ~' ~~ ~~JJJ v ~J ~ b~ y. ~~~w ~ ? . ~ Perforation Depth MD (ft): 9170' - 9190' Perforation Depth TVD (ft): 8901' - 8920' 4-1/2", 12.6# 13Cr80 8517' & Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~2~ ~~~ x 4-1/2" Baker'SABL-3 packer 8396' & 8540' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut, pull and mill tubing to 8515'. Cut and pull 9-5/8" casing, mill to 1803'. Run 9-5/8" Tieback to 1806' and cement w/ 130 Bbls Class'G' ield 1.16 . Run Chrome com letion. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 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 David Bjork, 564-5683 309-035 Printed Name Terrie Hubble Title Drilling Technologist w Prepared By Name/Number: ~~ Signature Phone 564-4628 Date ~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~ Submit Original nl ~~~ ~~. ~t~~~ L ~ .~'~~~ ~~2~~g ~~I~i~A ,~i • • 11-04A, Well History (Pre Rig Workover) Date Summary 2/23/2009 T/I/O=SSV/300/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test void to check pressure (0 psi). Functioned LDS, all pins moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void to check pressure (50 psi). Bled to 0 psi. Functioned LDS, (1) pin very tight but functioned (left backed outj, the rest moved freely (1 "). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 0 psi (PASS). Bled void to 0 psi. 3/2/2009 WELL S/I ON ARRIVAL. PULLED P-PRONG C«3 8560' SLM / 8571' MD. PULLED PX PLUG BODY Q 8565' SLM / 8571' MD. RECOVERED ALL PKG, NO NEED TO DRIFT. WELL LEFT S/I, JOB COMPLETE. 3/19/2009 T/I/0=230/250/0+. Temp=Sl. Tubing & IA FL (pre E-line). AL line disconnected. Integral on IA. IA FL Q 48' (3 bbis). TBG FL C 114' (3 bbls). SV, WV=Closed. MV, SSV=Open. IA & OA=OTG. NOVP. 3/20/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 250/600/0. SET 4 1/2" HES FASDRILL BRIDGE PL Jl~ AT 8555' MID ELEMENT. SLACK OFF ON PLUG TO CONFIRM SET. CCL TO MID ELEMENT: 7.8', CCL STOP DEPTH: 8547.2'. 3/21/2009 T/I/0=160/300/0 Temp=Sl CMIT TxIA Pumped 5 bbis meth, 9 bbis crude to reach test pressure for CMIT TxIA. T/IA lost 60 psi in the 1 st 15 mins and 30 psi in the 2nd 15 mins for a total pressure loss of 90 psi in 30 mins. Bled to starting. FWHP's = 200/200/0. E-line in control of well upon departure. 3/21/2009 T/I/O = 280/170/0+. Temp=Sl. OA FL pre MITOA. AL spool dropped, ALP=600 psi. Integral on IA companion. OA FL ~ 75' ( 5 bbls). SV, W V= C. SSV, MV = O. IA, OA = OTG. NOVP. 3/21/2009 CMIT T X IA 70 3000 PSI FOR 30 MIN - PASSED. CUT TUBING AT 8510', CCL TO CUT: 11.5', CCL STOP DEPTH: 8498.5'. CORRELATED TO TUBING TALLY DATED 3/4/94. WELL SHUT IN ON DEPARTURE. FINAL T/I/0 = 300/200/0. JOB COMP~ETE. 3/22/2009 T/I/0=200/200/0+. Temp=Sl. MITOA w. triplex to 2000 psi -'~PASSED`~. A~ disconnected. Integral on IA. OA FL near surface. Bled OAP from 0+ to 0 psi in 30 seconds (gas). Increased IAP from 0 psi to 2000 psi in 40 mins using 2.4 bbls of inethanol. IAP decreased 70 psi in first 15 mins & 30 psi in 2nd 15 mins, for a total loss of 100 psi. Final WHPs 200/200/0. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 3/29/2009 T/I/0= 350/100/20 Circ-out. Pumped down Tbq takinq returns to treecap on 11-03 with ~bbl~ neet meth spear followed by 890 bbls seawater then 0.5 bbls neet meth followed by 147 bbls of 80°F diesel, then 0.5 bbls neet meth. 3/30/2009 T/I/O = 350/100/20 Circ-Out~CMIT Tx IA PASSED to 3000 psi. Finished pumping 890 bbls seawater for circ out. Pumped 0.5 bbls meth, 147 bbls diesel, & 0.5 bbls meth down Tbg. U-tubed TxIA for freeze protect. Freeze protected hardline with 3 bbls neat and 5 bbls diesel. Pressured up TxIA with 6.8 bbls of diesel. T/IA lost 40/40 psi in the 1st 15 mins and 20/20 psi in the 2nd 15 mins for total pressure loss of 60/60 psi in 30 mins. Bled WHP's to 0 psi. FWHP's=0/0/0 SV, WV = S. SSV, MV = O. IA, OA = OTG. DSO notified & tags hung upon departure. 4/1/2009 T/I/O=Vac/0/0. Set 5-1/8" Gray "K" BPV thru tree for 2ES Pre-riq. 1-2' ext. used, tagged @ 86". Complete. 5/10/2009 T/I/O=BPV/0/0 Hot DSL flush flowline. Pumped 30 bbls heated DSL down F/L to flush for the ria. Wellhead valves left in the following positions. SV, WV & SSV = S/I, MV, IA & OA left open. FWP's = BPV/0/0. Page 1 of 1 • ~ BP EXPLQRATION Page 1 of ~4 Operations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: , ~ ~ ~ ~ ~ ~ 5/16/2009 00:00 - 01:00 1.00 RIGD P PRE 01:00 - 02:00 I 1.001 RIGD I P I I PRE 02:00 - 03:30 I 1.501 RIGD I P I I PRE 03:30 - 08:00 I 4.50I RIGD I P I I PRE 08:00 - 09:00 1.00 RIGD P PRE 09:00 - 10:30 1.50 MOB P PRE 10:30 - 11:00 0.50 RIGD P PRE 11:00 - 15:00 4.00 RIGD P PRE 15:00 - 17:00 2.00 MOB P PRE 17:00 - 17:30 0.50 MOB P PRE 17:30 - 19:30 2.00 MOB P PRE 19:30 - 23:00 3.50 MOB P PRE 23:00 - 23:30 0.50 MOB P PRE 23:30 - 00:00 0.50 MOB P PRE 5/17/2009 00:00 - 01:00 1.00 MOB P PRE 01:00 - 06:00 5.00 MOB N RREP PRE 06:00 - 10:30 4.50 MOB P PRE 10:30 - 12:00 1.50 RIGU P PRE 12:00 - 14:00 2.00 RIGU P PRE 14:00 - 14:30 0.50 RIGU P PRE 14:30 - 15:30 1.00 RIGU P PRE 15:30 - 17:30 2.00 RIGU P PRE 17:30 - 18:30 1.00 RIGU P PRE 18:30 - 19:30 1.00 RIGU P PRE 19:30 - 21:30 2.00 RIGU P PRE 21:30 - 23:30 I 2.001 RIGU I P I I PRE 23:30 - 00:00 I 0.501 RIGU I P I I PRE va...zv~ ~ru .. ...pq.>• ... -Install bale lock. -Detach hydraulic rams from stand jump. -Unplug top drive and remove service loops. -Install rollers on carriage. -Remove ODS top roller to LD top drive. -Remove brace on bottom of top drive guide. -Tie back lines. -LD top drive. -Bring bridle lines down. -Install carriage on blocks. -Raise and pin up C-section -Bridle up. -Blow down rig floor. -Disconnect lines under rig floor. Skid rig floor to moving position. Move rig off well 13-13A and position on pad. Skid rig floor back to derrick down position. -LD wind walls. -LD derrick. Install rear boosters and test run new booster system. Move rig f/ back of DS 13 to pad entrance. Wait on Security. -Security escorting rig N-9ES move. Move rig f/ DS 13 to East Security shack. Wait on tool service to move sign. Move rig f/ East Security shack to West Dock Rd. Move rig down West Dock Rd to front of EAO fire station. Stopped rig move due to leak in hydraulic motor on left rear tire. Proceed to remove hydraulic motor and planetary and blank hydraulic lines. Cont. moving rig to DS 11. Position rig on pad. Raise derrick. Raise and pin wind walls. Skid rig floor from derrick down position to moving position. -Remove rear boosters. -Hang mouse hole and cellar doors. Move rig over well 11-04A. Shim rig. -Place mats for rock washer. -Spread herculite and set sills. Skid rig floor to drilling position. -Install auger in rock washer. Extend conveyor. -Spot and berm rock washer. -Hang lights on floor. -Install wind wall braces. -Bridle down. -Unpin and lower C-section. -Hang bridle lines in derrick and tie off. SIMOPS: -Load seawater in pits. -Hard line crew spot slop tank and RU hard line w/ choke manifold. -LD carriage and hook up to top drive. Printed: 6/8/2009 11:38:24 AM ~ • BP EXPLORATION ' Page 2 of 14 Operations S`ummary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Deseriptian of Operations 5/17/2009 23:30 - 00:00 0.50 RIGU P PRE -Install bale brace. 5/18/2009 00:00 - 01:00 1.00 RIGU P PRE PU top drive. 01:00 - 02:30 1.50 RIGU P PRE -RU DSM lubricator on tree. -Test lubricator to 500 psi x 5 min on chart. -Pull BPV ("K" plug). -RD lubricator. 02:30 - 04:00 1.50 RIGU P PRE -Hook up service loops. -Plug in top drive. -Clear rig floor of bridle line yoke, carriage, carriage rollers and bale lock. 04:00 - 05:30 1.50 RIGU P PRE -Install bottom brace on top drive rails. -Install roller on top drive. 05:30 - 08:30 3.00 RIGU P PRE -Hang rig tongs. -MU IBOP-saver sub assembly and torque tube assembly on top drive. 08:30 - 10:30 2.00 RIGU P PRE RU stand pipe and mud manifold. Accept riq ~ 10:00 10:30 - 11:30 1.00 RIGU P PRE Connect service lines under rig floor (hell hole). 11:30 - 13:00 1.50 WHSUR P DECOMP -Install secondary valve in IA. -Install pump in flange on wing. -RU lines to tree and hook up to hard line. -Test hard line to 3500 psi. Test good. 13:00 - 16:00 3.00 WHSUR P DECOMP Displace freeze protect w/ seawater: -Pump 90 bbls seawater down IA, taking returns out tubing to slop tank (11 bbls to obtain returns) 3 BPM C~ 390 psi -Swap lines on tree. Pump 180 bbls seawater down tubing, taking returns out IA to slop tank. 3 BPM C~ 170 psi. -Allow diesel to migrate x 30 min. Pump 30 bbls seawater down tubing, taking returns out IA to slop tank. 3 BPM C~ 270 psi. -Blow down lines and switch them to take returns back to pits. -Circulate w/ seawater until clean returns. 3 BPM @ 270 psi. -Blow down lines. 16:00 - 18:30 2.50 WHSUR P DECOMP -RU lubricator on tree. -Test lubricator to 500 psi x 5 min on ch~ -DSM install "K" plup (BPVI. -RD lubricator. -Cameron Re . dr rod in test dart. -Test test dart f/ above to 3500 si x 10 ' pluq f/ below to 1000 p~x 10 min nn chart. -Blow down and RD lines to tree. 18:30 - 21:00 2.50 WHSUR P DECOMP -Suck out tree. -ND tree and adapter flange. Remove from cellar. -Inspect threads in tubing hanger and check 4-1/2 IF x Gray ACME XO on it (17.5 turns to MU). Barriers in place: Fasdrill plug C~? 8548', BPV ("K" plug) in tubing hanger. 21:00 - 00:00 3.00 BOPSU P DECOMP -Install 3' spacer spool on tubing spool. -NU BOP choke line, riser and flow line. 5/19/2009 00:00 - 02:30 2.50 BOPSU P DECOMP -Continue to NU BOP. Install Riser and Flow line. -Cut 12" off of riser. Printed: 6/8/2009 11:38:24 AM ~ ~ BP EXPLORATfQN Operations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: ' Qate ` From - To Hours Task God~ NPT Phase Description of Ope`ratic~ns 5/19/2009 00:00 - 02:30 2.50 BOPSU P DECOMP 13-5/8" 5M BOP stack configuration: - Annular preventer. - 3-1/2" x 6" VBR (top rams). - Blind Rams. - Mud cross. - 2-7/8" x 5" VBR (bottom rams). 02:30 - 03:00 0.50 BOPSU P DECOMP RU to test BOP. 03:00 - 10:00 7.00 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test upper rams w/ 4", 4-1/2" & 5-1/2" test jts. Test lower rams w/ 4" and 4-1/2" test jts. Test witnessed by WSL and Tourpusher. Lou Grimaldi, AOGCC Rep, waived witness of test. -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained ~ 36 sec. 4. Full pressure attained @ 2 min 45 sec. 5. Nitrogen: 4 bottles x 2150 psi avg. 10:00 - 10:30 0.50 BOPSU P DECOMP RD test equipment. -Blow down Choke & Kill lines. 10:30 - 13:00 2.50 BOPSU P DECOMP Cameron Rep. "dry rod' out test dart. -RU "Dutch" system lubricator extension. -RU DSM lubricator. -Test lubricator to 500 si - OK. -Pull "K" DIUq. -RD lubricator assembly - Clear from Rig floor. 13:00 - 14:00 1.00 PULL P DECOMP Install Bales & Elevators. -Mob spear to Rig floor. 14:00 - 14:30 0.50 PULL P DECOMP PU & MU - ITCO spear dressed for 5 1/2", 17# Tbg. -PU 1 Jt of 4" DP. 14:30 - 15:30 1.00 PULL P DECOMP Enqaqe tubinq at well head. -BOLDS. -Pull hanger free w/ 225k. -Pull tubing to Rig floor w/ 160k up wt. -Release spear - LD same. 15:30 - 16:00 0.50 PULL P DECOMP Break off & LD Tbg Hanger. 16:00 - 16:30 0.50 PULL P DECOMP Change out Elevators. -RU to circulate. 16:30 - 18:00 1.50 PULL P DECOMP Establish circulation throu h"JeY' cut Tb C~ 8 510' md. -Pump 40 bbl Safe-Surf-O pill surface to surface. -360 gpm / 440 psi. 18:00 - 21:00 3.00 PULL P DECOMP PJSM on LD 5 1/2" Tbg. -RU & pufl Control line onto Control line Spooler. -Pull Control lines from 8,510' to 6,280' md. -LD 5 1/2, 17# 13 Cr-80, NSCC Tbg. -Recovered 30 Stainless Steel bands. 1 band missing. 21:00 - 21:30 0.50 PULL P DECOMP RD Control line Spooler. 21:30 - 22:00 0.50 PULL P DECOMP Continue to LD 5 1/2" Tbg from 6,280' to 5,670' md. Printed: 6/8/2009 11:3824 AM • ~ BP EXPLQRATiON Page 4 of 14: Operations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11 /1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date` From - To Haurs Task Code NPT Phase Description of Operations 5/19/2009 21:30 - 22:00 0.50 PULL P DECOMP -Total 5 1/2"Tbg pulled: (2,840') -71 Jts. 1 pup (9.97'). 1 SSSV & 30 SS Bands. 22:00 - 00:00 2.00 PULL P DECOMP Change out Elevators & XO on Safety valve. -LD 4 1/2", 12.6# 13 Cr-80, TDS/FOX Tbg from 5,670' to 4,441' md. 5/20/2009 00:00 - 00:30 0.50 PULL P DECOMP Lubricate Rig. Service & inspect Top Drive. 00:30 - 05:30 5.00 PULL P DECOMP Continue to LD 4 1/2", 12.6# 13 Cr-80, TDS/FOX Tbg. -LD Tbg from 4,441' to surface. -LD 137 Jts of 4 1/2" Cr FOX & Cut Jt of 1728'. -(7) GLM's & (1) X-nipple. 05:30 - 06:30 1.00 PULL P DECOMP Clean Rig tloor. 06:30 - 07:30 1.00 PULL P DECOMP Clear Rig floor of Tbg pulling equipment. 07:30 - 08:00 0.50 CLEAN P DECOMP MOB BHA to Rig floor. 08:00 - 08:30 0.50 CLEAN P DECOMP Install Wear ring. 08:30 - 11:00 2.50 CLEAN P DECOMP PU 4 3/4" D.C's. • Dressoff Shoe, 2-E~ensions, Inner Dress off Mill. -Washover Boot Basket, XO, 7" Csg Scraper, Bit sub, XO. -(6) 4 3/4" D.C's. to 218' md. 11:00 - 11:30 0.50 CLEAN P DECOMP Break circulation to clear scale out of D.C's. -360 gpm / 440 psi. 11:30 - 12:00 0.50 CLEAN P DECOMP PU 853' of 4" DP for 9 5/8" Scraper space out to 1,072' md. 12:00 - 12:30 0.50 CLEAN P DECOMP Lubricate Rig. Inspect & service Top Drive. 12:30 - 18:30 6.00 CLEAN P DECOMP MU 9 5/8" Cs Scra er. -Continue to PU 4" DP 1 X 1 from 1,072' to 7,535' md. 18:30 - 20:30 2.00 CLEAN P DECOMP Cut & slip 119' of 1 1/4" drlg line (double cut). -Check & adjust Brake linkage. Grease Crown. -Adjust Brakes. 20:30 - 21:30 1.00 CLEAN P DECOMP Continue to RIH w/ Dressoff Assy on 4" DP 1 X 1. -RIH from 7,535' to 8,510' md. 21:30 - 23:00 1.50 CLEAN P DECOMP Obtain parameters: PUW 190k, SOW 155k, ROT wt 170k. -212 gpm / 570 psi. RPM 60 C~ 4k Tq. - a Stub @ 8 515' md. -Wash over & Mill on Stub from 8,515' to 8,529.5' md -MiIL Shoe de th. 23:00 - 00:00 1.00 CLEAN P DECOMP Pump Hi Vis Sweep surface to surface. -386 gpm / 1810 psi. 5/21/2009 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to circulate`HV Sweep surface to surface. -386 gpm / 1810 psi. 01:00 - 02:00 1.00 CLEAN P DECOMP RU to reverse circulate w/ Overshots extensions over Tbg Stub. -Utilize Head pin & High pressure hose. -Could not get over Stub. Remove Head pin & Hose. -T~ Drive up. Rotate & pump over Tbg Stub to 8,529.5' md. -84 gpm / 140 psi.RPM 70 @ 4k Tq. -Work over Stub - Good. 02:00 - 03:00 1.00 CLEAN P DECOMP POH w/ Dressoff Assembiv on 4" DP from 8,529' to 6,700' md. 03:00 - 03:30 0.50 CLEAN P DECOMP Lubricate Rig. Inspect Top Drive. 03:30 - 05:30 2.00 CLEAN P DECOMP Continue to POH from 6,700' to the BHA @ 1,021' md. 05:30 - 07:00 1.50 CLEAN P DECOMP PJSM -LD ress ff BHA. -Internal mill showed good wear pattern. 07:00 - 08:00 1.00 CLEAN P DECOMP Clear Rig floor of Vendor Tools. Printed: 6/S/2009 11:38:24 AM • ~ BP EXPLORATION Pa~e 5 af 14 Operations Summary R~port Legal Well Name: 11-04 Common Well Name: 11-04 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 ~ ~ ~ Spud Date: 6/11/1980 Start: 5/15/2009 End: 5/30/2009 Rig Release: 5/30/2009 Rig Number: i 5/21/2009 08:00 - 09:30 1.50 CLEAN P DECOMP RU SLB E-liners for USIT log in Cement / Corrosion mode. 09:30 - 11:00 1.50 CLEAN P DECOMP RIH. Log hole up from 3,000' md to surface. 11:00 - 11:30 0.50 CLEAN P DECOMP RD SLB E-liners. 11:30 - 12:00 0.50 CLEAN P DECOMP MOB HES RBP & running Tool to Rig floor. 12:00 - 12:30 0.50 CLEAN P DECOMP Lubricate Rig. Inspect Top Drive. 12:30 - 13:00 0.50 CLEAN P DECOMP PU & MU Running Tool, RBP & D.C's. 13:00 - 14:00 1.00 CLEAN P DECOMP RIH at a controlled rate w/ RBP on 4" DP to 1,820' md. 14:00 - 14:30 0.50 CLEAN P DECOMP Obtain parameters: PUW 80k, SOW 81 k. -RIH, set RBP @ 1,900' md - COE.- FN @ 1,895' md. 14:30 - 15:00 0.50 CLEAN P DECOMP RU & test Cs to 3500 si / 10 minutes - PASS -RD test equipment. 15:00 - 16:00 1.00 CLEAN P DECOMP Suck out Pit #1. - Bring on 9.8 ppg NaCI. Displace well to 9.8 ppg NaCI. -Pump Hi Vis Sweep. Pump 9.8 ppg NaCI. 16:00 - 18:30 2.50 CLEAN P DECOMP Stand back 1 Std of 4" DP. -RU to dump 2200 Ibs of sand. Dump sand down DP -Circulate 1/2 DP volume Q 120 gpm / 30 psi. -Wait 1/2 hour for sand to settle. -RIH, tag sand @ 1,849' md. 18:30 - 19:00 0.50 CLEAN P DECOMP POH w/ running Tool on 4" DP 19:00 - 19:30 0.50 CLEAN P DECOMP Stand back D.C's, LD running Tool. 19:30 - 20:00 0.50 FISH P DECOMP MOB Csg cutter BHA to Rig fioor. 20:00 - 21:00 1.00 FISH P DECOMP PU & MU Multi-String Csg cutter, Stab, POS, XO's & D.C's. -PU BHA to 198' md. 21:00 - 21:30 0.50 FISH P DECOMP RIH w/ Csg cutter on 4" DP to 1,778' md 21:30 - 22:00 0.50 FISH P DECOMP Break circulation C~ 147 gpm / 350 psi. -Slack off and find Csg collar @ 1,822' md. -PU 20' and osition Knives on Multi-Strin cutter @ 1 8 ' -PUW 82k, SOW 82k, ROT wt 82k. 22:00 - 23:00 1.00 FISH P DECOMP Cut 9 5/8" Csg. RPM 50 C~ 1-4k Tq. -Start pumping ~ 152 gpm / 350 psi. -Slowly increase pump up to 265 gpm / 1240 psi. -Indicators of the Csg being cut: -Pressure dropped from 1240 psi to 800 psi. -Annular pressured up to 100 ~: -Torque dropped from 4k to 1 k. 23:00 - 00:00 1.00 FISH P DECOMP Drop Ball & Rod down drill pipe. -RU pump in sub and cement hose stump. -Close Rams and pressure up to 1800 psi to open P.O.S. -Establish circulation down DP u 13 3/8" X 9 5/8" annul -Take returns outside to Tiger Tank. -Pump rate: 210 gpm / 140 psi. 5/22/2009 00:00 - 01:00 1.00 FISH P DECOMP Pump 100 bbls of 180 degree diesel down drill pipe. -Take returns up 13 3/8" X 9 5/8" annulus to Tiger Tank. -Pump rate: Start C~ 63 gpm / 300 psi. FCP 84 gpm / 600 psi. -Chase diesel w/ 20 bbis of Safe-Surf-O pill C~ 168 gpm / 200 psi. 01:00 - 03:00 2.00 FISH P DECOMP Let diesel soak for 2 hours. 03:00 - 04:30 1.50 FISH P DECOMP Pump: 60 of 9.8 ppg brine. 30 bbl Hi Vis Sweep C~ 9.8 ppg. -250 bbls of 9.8 ppg brine. -Continue to take returns outside to Tiger Tank. -ICP 380 gpm / 650 psi. FCP 380 gpm / 1200 psi. -Open Rams. Circulate 35 bbls out to Rock washer. Printed: 6/8/2009 11:38:24 AM • • _ _ _ __ BP EXPLORATION Page 6 af 14.' Qperations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date; From - To Hours Task Code NPT Phase Description of Operations 5/22/2009 03:00 - 04:30 1.50 FISH P DECOMP -210 gpm / 190 psi. 04:30 - 05:00 0.50 FISH P DECOMP POH w/ Cutter assembly on 4" DP. -Stand back D.C's. 05:00 - 06:00 1.00 FISH P DECOMP LD Multi-String Cutter. -MOB 9.5/8" Spear to Rig floor. 06:00 - 07:00 1.00 FISH P DECOMP Pull Wear ring. 07:00 - 08:30 1.50 FISH P DECOMP MU Spear: -Bull Nose, Spear P.O., XO, ITCO Spear, Spear Stop sub & 1 Jt of DP. -En a e 9 5/8" Cs Han er. BOLDS. -Pull Hanger free C~ 180k. -Pull to Rig floor @ PUW 125k. 08:30 - 09:30 1.00 FISH P DECOMP Circulate hole clean. 383 gpm / 70 psi. -Mix & pump Dry job. 09:30 - 10:30 1.00 FISH P DECOMP Disengage Spear. -Break off & LD Spear, XO & DP. Break off & LD Csg Hanger. 10:30 - 11:00 0.50 FISH P DECOMP RU Csg equipment to LD 9 5/8" Csg. 11:00 - 12:00 1.00 FISH P DECOMP LD 1 JT of 9 5/8", L-80, BTC, Csg to 1,722' md. -Connection extremely tight. 12:00 - 21:30 9.50 FISH P DECOMP Continue to LD: 9 5/8", L-80, BTC, Csg from 1,722' to surface. -Connections extremely ti ht. (Beat, Steam & Mash to break). -9 5/8" csg recovered: 44 Jts & 1 cut Jt C~ 22.29'. -OD @ Flare of cut Jt = 10.75" -Bow Spring Centralizers recovered = 9. 21:30 - 22:00 0.50 FISH P DECOMP Clear Rig floor of Vendor Tools. 22:00 - 23:00 1.00 FISH P DECOMP Clean Rig floor. 23:00 - 23:30 0.50 FISH P DECOMP Inspect & service Top Drive. Grease Drawworks. 23:30 - 00:00 0.50 FISH P DECOMP Install Wear ring. 5/23/2009 00:00 - 01:00 1.00 CLEAN P DECOMP MOB 9 5/8" Dressoff BHA to Rig floor. -MU: Dressoff shoe_ Wash pipe extension, Inner Mill, Boot Basket, -Double Pin sub, 13 3/8" Csg Scraper, Bit sub, Float,Bumper sub, -Oil Jars & XO to 46' md. 01:00 - 02:00 1.00 CLEAN P DECOMP MU 4 3/4" D.C's to 231' md. -RIH w/ Dressoff assembl on 4" DP to 797' md. 02:00 - 02:30 0.50 CLEAN P DECOMP Circulate bottoms up: -ICP= 207 gpm / 90 psi & stage up to 249 gpm / 120 psi. -RPM 40 C~ 1 k Tq. PUW 70k, SOW 70k. 02:30 - 03:00 0.50 CLEAN P DECOMP Continue to RIH w/ 4" DP from 797' to 1,747' md. 03:00 - 03:30 0.50 CLEAN P DECOMP Ta ed 9 5/8" Cs stub @ 1,802' md. Obtain parameters: -PUW 85k, SOW 85k, ROT wt 85k. RPM 60 @ 1 k Tq. -126 gpm / 60 psi. -Milling Tq= 5k, W06= 10k, Milled 12" to 1,803' md. 03:30 - 05:00 1.50 CLEAN P DECOMP Pump: 30 bbls of Hi Vis Sweep, 50 bbls of 9.8 ppg NaCI brine. -Pump 30 bbls of Safe-Surf-O. -Pump Safe-Surf-O surface to surface to clean up wellbore. 05:00 - 06:30 1.50 CLEAN P DECOMP POH w/ 9 5/8" Dressoff BHA on 4" DP to BHA at 230' MD. 06:30 - 07:30 1.00 CLEAN P DECOMP Stand back D.C's. -LD dressoff assembly. -Inspect inner mill (Good wear pattern). 07:30 - 09:00 1.50 CASE P TIEB1 Clear / Clean rig floor. -Mobilize casing tools, pups to rig floor. Printed: 6/8/2009 17:38:24 AM . • BP EXPLORATIUN Page 7 of 14 Operations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date' Fr4m - To Hours Task Code NPT Phase Description of aperatians 5/23/2009 09:00 - 09:30 0.50 CASE P TIEB1 Pull Wear ring. 09:30 - 10:00 0.50 CASE P TIE61 PJSM w/ all involved. -RU Casing Tongs, Elevators and Torque Turn equipment. 10:00 - 16:00 6.00 CASE P TIE61 PU 9 5/8" Bowen casing patch, ECP, ES cementer and XO ' joint. -Bakerlock all connections below ES cementer. -Run 47 jts 9 5/8' Hyd. 563 L-80 Casin~ -Torque turn all connections to 15,800 fUlbs. -Utilize "Jet Lube Seal Guard" Thread compound. 16:00 - 17:00 1.00 CASE P TIEB1 PU 5' pup jt, BTC X Hyd 563 XO pup & XO's to Top Drive. -Screw in Top Drive. -Break circulation. Circulate air out of pipe w/ 378 gpm / 50 psi. -Slow pump to 42 gpm. -Rotate down w/ 15 rpm and enqaqe 9 5/8' stub at 1,803' md. -Stop rotatry & pump - Set down 35k. -PU to 250k. 17:00 - 18:00 1.00 CASE P TIE61 Pressure to 1000 si - Hold 10 min on chart - OK. -Pressure up to 1200 psi f/ 1 minute- 1400 psi f/ 1 minute. -Pressure up to 1750 psi to inflate ECP. -Observe pressure drop to 1550 psi. -Pressure back up to 1750 psi (took 1/4 bbl). -Pressure to 2000 psi - Hold f/ 10 minutes on chart - OK. -Pressure to 3000 psi and open ES cementer. 18:00 - 18:30 0.50 CASE P TIEB1 Break circulation w/ 383 gpm / 90 psi. -Circulate surface to surface. -Temperture in at 95 deqrees F. -Tem erture out at 88 de rees F. 18:30 - 19:00 0.50 CEMT P TIEB1 RD Top Drive & XO's. -RU Cement Head, XO's & Cement hose. 19:00 - 21:30 2.50 CEMT P TIEB1 PJSM w/ Crew & Cementers. -Pump: 5 bbls H2O. -Test lines to 4500 psi - OK. -Pump: 130 bbls of 15.8 ppg class "G" cement w/ Gas Blok• -Cmt Yd= 1.16 ft3/sx. 5.190 gal/sx. 636 sx. -Drop closing Plug. kick out w/ 2 bbis of Cmt & 5 bbls of H2O. 21:30 - 22:00 0.50 CEMT P TIEB1 Displace Cmt w/ 9.8 ppg NaCI brine w/ Rig pumps. -355 gpm / 530 psi. Bump Plug w/ 1205 stks. -Pressure up to 1600 psi to close ES Cemen er._ -Pressure up to 1700 psi to confirm shut. -CIP @ 21:50. -17 bbls of good cement back to surface. 22:00 - 23:00 1.00 CEMT P TIEB1 Bleed off pressure. Chec oats. D cementing equipment. -Suck out Landing Jt. -C/O Elevators. RU to Csq & pull 100k over strina~~ -Flush stack. 23:00 - 00:00 1.00 CEMT P TIEB1 PJSM on ND Stack. -Pull Flow line covers. ND Flow line & Riser. -ND Choke line 5/24/2009 00:00 - 02:30 2.50 BOPSU P TIEB1 ND Choke line. Split BOP Stack. 02:30 - 06:30 4.00 BOPSU P TIEB1 Set "E" Slips w/ 100k over ull. -Cut 9 5/8" Csg. Cut Jt= 25.56' / OAL 33.53' (w/2 pups). -ND Tbg Spool. Install Primary Packoff. -Change out 1 Lock down screw. Printed: 6/8/2009 11:38:24 AM . ~ BP EXPLORATC~N Page 8 c~f 14 Operations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/24/2009 06:30 - 08:30 2.00 BOPSU P TIE61 NU new Tbq Sqool w/ Secondary Packoff._ -Test Primary & Secondary Packoff seals. -Test to 3800 psi / 10 minutes - Pass. 08:30 - 11:30 3.00 BOPSU P TIE61 NU BOP Stack: Spacer Spool, Install Choke line. -Install secondary Annulus valve. -Install Turnbuckles, Riser, Bleed off line & Hole fill line. 11:30 - 12:00 0.50 BOPSU P TIEB1 RU to test Stack breaks and Choke line. -Install Test Plug. 12:00 - 13:00 1.00 BOPSU P TIEB1 Function Top Rams. -Test breaks on Stack & Choke line. -Chart & test to 250 psi low & 3500 psi high pressure. -Hold each test for 5 minutes - Pass. -RD Test equipment. Pull Test Plug. 13:00 - 13:30 0.50 BOPSU P TIEB1 Lubricate Rig. Service & inspect Top Drive. 13:30 - 14:00 0.50 BOPSU P TIE61 MOB Cleanout BHA to Rig floor. 14:00 - 14:30 0.50 BOPSU P TIEB1 Install Wear ring. 14:30 - 15:30 1.00 DRILL P TIEB1 PU & MU: -Bit, Boot Baskets, Float sub, Bumper sub, Oil Jars, XO's & D.C's. 15:30 - 16:00 0.50 DRILL P TIE61 RIH w/ Cleanout BHA on 4" DP. -Tag cement (~ 1,721' md. 16:00 - 18:30 2.50 DRILL P TIE61 Obtain parameters: PUW 80k, SOW 80k, ROT wt 30k. -308 gpm / 290 psi. RPM 70 C~3 1 k Tq. -Drill cement stringers from 1,721' to 1,762' MD. -Drill Pluq & ES cemeterfrom:1,762'to 1,765' md. -Ream down to 1,830' md. 18:30 - 19:00 0.50 DRILL P TIEB1 Circulate hole clean. 389 gpm / 520 psi. 19:00 - 20:30 1.50 DRILL P TIEB1 RU & test Csg to 3500 psi / 30 charted minutes - Pass. -RD test equipment. 20:30 - 21:00 0.50 DRILL P TIEB1 RIH. Tag Sand ~ 1,843' md. Dry drill to 1,846' md. -PUW 80k,SOW 80k ROT wt 80k. WOB 5k. 21:00 - 21:30 0.50 DRILL P TIEB1 Pump Hi Vis Sweep surface to surface. -391 gpm / 550 psi. Reciprocate & rotate. RPM = 20. 21:30 - 22:00 0.50 DRILL P TIEB1 POH w/ Cleanout BHA on 4" DP from 1,846' to the BHA ~ 220' md. 22:00 - 23:00 1.00 DRILL P TIEB1 Stand back D.C's. -LD: Bit, Boot baskets, Bit sub & Float sub. -Clean out Boot Baskets ( 1 gal of Aluminum, Brass & Rubber). 23:00 - 00:00 1.00 DRILL P TIEB1 RU & retest 9 5/8" Cs to 3500 si. Close Blind Rams.. -Test Csg to 3500 psi for 30 charted minutes - Pass. -RD test equipment. 5/25/2009 00:00 - 00:30 0.50 DRILL P TIEB1 Lubricate Rig. Inspect & service Top Drive & Blocks. 00:30 - 01:00 0.50 DRILL P TIEB1 MU BHA: -Reverse Junk Basket, 2 Boot Baskets, 9 5/8" Csg Scraper, Bit sub, -Bumper sub, Oil Jars & XO to 228' md. 01:00 - 02:00 1.00 DRILL P TIEB1 MU (6) -4 3/4" D.C's. -RIH w/ RCJB on 4" DP from 228' to 1,839' md. -W iped from 1,721' to 1,839' md several times. 02:00 - 02:30 0.50 DRILL P TIEB1 Tagged Junk / Sand C~ 1,847' md, Dry drill down to 1,850' md. -Wash down to 1,860' md. -PUW 82k, SOW 82k, ROT wt 82k. RPM 60. WOB 8k. -303 gpm / 3530 psi. Printetl: 6/8/2009 11:38:'L4 AM ~ • BP EXPLORATION' Page 9 of ~4 Operations ~ummary R~port Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ' Descrip#ion of Operations 5/25/2009 02:30 - 03:00 0.50 DRILL P TIEB1 CBU. 303 gpm / 3530 psi. -Reciprocate & rotate -RPM 20. 03:00 - 04:30 1.50 DRILL P TIEB1 POH w/ RCJB BHA from 1,860' to surface. -Rack back 4 3/4" D.C's. 04:30 - 05:30 1.00 DRILL P TIEB1 Break down & clean out RCJB. Clean out Boot Baskets. -Recovered 6 lar e ieces of ES Cementer. -(Cement & aluminum 5"-6" long, 2" diameter) -Also, recovered small pieces of aluminum, rubber & Brass. -Recovered large chunks of cement 1"-3" diameter. -Drop off 9 5/8" Csg Scraper. -MU: Junk Baskets & RCJB. 05:30 - 07:00 1.50 DRILL P TIEB1 RIH w/ RCJB BHA on 4" DP to 1,835' md. 07:00 - 08:00 1.00 DRILL P TIEB1 Obtain parameters: PUW 80k, SOW 82k. -Drydrill from 1~68'to 1,871' md. -Circu ate down to 1,880' md. -200 gpm / 3340 psi. RPM 60 ~ 1 k Tq. WOB 8k. -PU 10' to circulate. 08:00 - 09:00 1.00 DRILL P TIEB1 CBU. 307 gpm / 3600 psi. RPM 15. 09:00 - 10:30 1.50 DRILL P TIEB1 Blow down Top Drive. -POH w/ RCJB on 4" DP from 1,880' md to surface. 10:30 - 11:00 0.50 DRILL P TIE61 Break down BHA and cleanout RCJB & Junk Baskets. -(2) pieces of cement 2-3" diameter. -Some small cement, brass & aluminum. -MU same BHA to 40' for rerun. 11:00 - 12:00 1.00 DRILL P TIEB1 RIH w/ RCJB on 4" DP from 40' to 1,890' md. 12:00 - 13:00 1.00 DRILL P TIEB1 Obtain parameters: PUW 80k, SOW 80k, ROT wt 80k. -RPM 20 C~ 1 k Tq. Pump Hi Vis Sweep. -305 gpm / 3490 psi. 13:00 - 13:30 0.50 DRILL P TIEB1 POH w/ RCJB on 4" DP from 1,890' to 220' md. 13:30 - 14:30 1.00 DRILL P TIEB1 Stand back D.C's. -LD: RCJB, Boot Baskets, Bit sub, Bumper sub & Oil Jars. -Recovered small pieces of cement & aluminum. 14:30 - 15:00 0.50 DRILL P TIEB1 Clear Rig floor of Vendor Tools. -MOB RPB retrieval Tool to Rig floor. 15:00 - 15:30 0.50 DRILL P TIE61 Lubricate Rig. Inspect & service Top Drive. 15:30 - 16:00 0.50 DRILL P TIEB1 MU retrieval tool & 4 3/4" D.C's to 198' md. 16:00 - 16:30 0.50 DRILL P TIE61 RIH w/ RBP retieval tool on 4" DP from 198' to 1,890' md. 16:30 - 17:00 0.50 DRILL P TIEB1 Obtain parameters: PUW 80k, SOW 80k. -Washover & Latch onto RBP C~? 1_895' md. 17:00 - 18:00 1.00 DRILL P TIEB1 Pump 30 bbl Hi Vis Sweep. -Displace well to 8.5 ppg Seawater from 9.8 ppg NaCI brine. -400 gpm / 560 psi. 18:00 - 18:30 0.50 DRILL P TIE61 Unseat HES RBP w/ 30k overpull. 18:30 - 19:00 0.50 DRILL P TIE61 CBU - 378 gpm / 440 psi. 19:00 - 19:30 0.50 DRILL P TIEB1 POH w/ HES RBP from 1,895' to 200' md. 19:30 - 20:30 1.00 DRILL P TIEB1 POH w/ 4 3/4" D.C's. Break off & LD RBP & running tool. 20:30 - 21:30 1.00 DRILL P TIE61 RU & test 9 5/8" Cs to 3500 si for 30 charted minut -Good test. RD test equipment. 21:30 - 22:00 0.50 DRILL P TIE61 MOB: FASDRILL drillout BHA. 22:00 - 22:30 0.50 DRILL P TIEBi RU Csg equipment to run 2 7/8" PAC pipe. 22:30 - 00:00 1.50 DRILL P TIEBi PU & MU: 3 5/8" Bladed Junk Mill, Bit sub, 5 Jts of 2 7/8" PAC pipe. -MU: XO, Bumper sub & P.O.S. MU 4 3/4" D.C's. to 356' md Printed: 6/8/2009 11:38:24 AM ~ • -_ BP' EXPLORATIQN Pag~ 10 of 14' Operations Summary R~port Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date' From - To Hours Task Code NPT Phase Description of Operations 5/26/2009 00:00 - 00:30 0.50 CLEAN P CLEAN Lubricate Rig. Service & inspect Top Drive & Blocks. 00:30 - 03:00 03:00 - 04:30 2.50 1.50 CLEAN CLEAN P P CLEAN CLEAN RIH w/ Drillout BHA from 356' to 8,438' md. -Tagged sand. Obtain parameters: PUW 180k, SOW 150k, ROT wt 165k. -RPM 60 C~3 2k Tq. 170 gpm / 520 psi. -Wash down from 8,438' to 8,513' md. Circulate 124 bbls. -RU to reverse circulate. Reverse circulate. -Plugged off Mill. -Make several at{empts to unplug - no success. 04:30 - 06:00 1.50 CLEAN P CLEAN POH from 8,513' to 7,564' md. -Open P.O.S. w/ 2000 psi. -Pump dry job. -Blow down. 06:00 - 09:00 3.00 CLEAN P CLEAN POH w/ Drillout assembly on 4" DP. -Stand back 4 3/4" DC's. 09:00 - 10:00 1.00 CLEAN P CLEAN LD: Bumper sub & XO's. -LD: 5 jts 2 7/8" PAC DP, Bit sub & 3 5/8' Mill. -Clean sand from last 2 jts of 2 7/8" PAC. 10:00 - 11:00 1.00 CLEAN P CLEAN Pull wear ring. -Install test plug. -RU to test BOPE. 11:00 - 17:00 6.00 CLEAN P CLEAN Test BOP and related equipment. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Test per BP / AOGCC procedures and regulations. -Test components to 250 psi low - 3500 psi high x 5 min each on chart. -Test all components w/ 4" test jt. -Test Annular preventer to 250 psi low - 3500 psi high. -Test Annular for 5 minutes on chart w/ 4" test jt. -Test upper & lower Rams w/ 4" and 4 1/2" test jts. -All Tests witnessed by WSL and Toolpusher. -Bob Noble, AOGCC Rep, waived witness of test. -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained ~ 37 sec. 4. Full pressure attained Ca~ 2 min 37 sec. 5. Nitrogen: 4 bottles x 2150 psi avg. 17:00 - 17:30 0.50 CLEAN P CLEAN RD test equipment. Pull test plug 17:30 - 18:00 0.50 CLEAN P CLEAN Install Wear ring. 18:00 - 19:30 1.50 CLEAN P CLEAN -Mobilize 6" x 4 1/2" Dress off assembl . -PU & MU: Dressoff Shoe, Washover extensions, Dressoff Mill, -Boot Baskets, Bumper sub, Oil Jars, P.O.S. & XO. 6/8/2009 11:3824 AM ~ • -_ BP EXPLORATIQN Page 11 of 14 Ope,rations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/26/2009 18:00 - 19:30 1.50 CLEAN P CLEAN -MU 4 3/4" D.C's to 225' md 19:30 - 21:00 1.50 CLEAN P CLEAN Cut & Slip 59.5' of 1 1/4" Drilling line. -Service Top Drive & Blocks. 21:00 - 23:00 2.00 CLEAN P CLEAN RIH w/ Dressoff BHA on 4" DP from 225' to 8,382' md. 23:00 - 00:00 1.00 CLEAN P CLEAN Obtain parameters: PUW 185k, SOW 155k, ROT wt 168k. -207 gpm / 490 psi. RPM 20 C~ 2k TQ. -RIH Taq sand ~ 8,453' md. -Wash down to top of Tbg stub @ 8,515' md. -Wash & rotate over Tbg stub to 8,529' md. -PU and wash back over Tbg stub without rotation. 5/27/2009 00:00 - 02:00 2.00 CLEAN P CLEAN Displace to new 8.5 ppg Seawater C~? 8,527' md. -Pump 25 bbl Hi Vis Sweep, chase w/ new 8.5 ppg Seawater. -250 gpm / 800 psi. 02:00 - 03:00 1.00 CLEAN P CLEAN RU to reverse circulate - No circulation. -Pull 20k over. -RU to circulate the long way - No circulation. -Pull up to 8,500' md. Circulate the long way 200 gpm / 550 psi. -RU to reverse circulate - No circulation. -Wash down over stub the long way 200 gpm / 550 psi. -~ 8,527' md RU & reverse circulate 126 gpm / 430 psi. -Stage up pumps to 168 gpm psi. 03:00 - 05:00 2.00 CLEAN P CLEAN Reverse circulate 3 X bottoms up ~ 8,527' md. -168 gpm / 580 psi. Stage up to 220 gpm / 720 psi. -Lots of sand in returns. -PUW 185k, SOW 155k. 05:00 - 07:30 2.50 CLEAN P CLEAN Prepare to POH. Well U-tubing strongly. Sand falling in Annulus. -Rig back up and reverse circulate a Hi Vis Sweep surface to surface. -PU & work back over stub w/ no issues. -Pump dry job -RD circulation head and lines. -Blow down. 07:30 - 11:00 3.50 CLEAN P CLEAN POH w/ 4' DP from 8,529' md to BHA C~ 44' md. -Stand back D.Cs. 11:00 - 12:00 1.00 CLEAN P CLEAN Break down BHA: P.O.S., Oil Jars, Bumper sub, Washover Basket, -(2) E~ensions & Dressoff Shoe. -Clear floor of all equipment not needed for upcoming operation. 12:00 - 12:30 0.50 CLEAN P CLEAN Service rig. -Service & Inspect Top Drive & Blocks. 12:30 - 14:00 1.50 CLEAN P CLEAN MU: 3 5/8" Mill, Bit sub, Circulation sub, 5 Jts of 2 7/8' PAC DP and BHA. -RIH w/ D.C's & 1 stand 4" DP to 460' md -Circulate pipe volume C~ 210 gpm / 390 psi. 14:00 - 16:00 2.00 CLEAN P CLEAN RIH w/ Cleanout BHA on 4" DP from 460' to 8,500' md. 16:00 - 17:00 1.00 CLEAN P CLEAN Screw in TD- Obtain parameters: -PUW i 80K - SOW 152K - ROT wt 165K w/ 30 rpm & 2 Tq. -Wash down w/ 147 gpm / 300 psi - Tag tubing stub at 8,517' md. -PU & rotate to enter Stub. -Wash down and tag sand at 8,539' md. -Wash sand w/ 210 gpm / 650 psi - with no rotary. Printed: 6/8/2009 11:38:24 AM ~ ~ BP EXPLQRATION Page 12 of 1~' Operations Sumrnary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date Fram - To Hours Task Code NPT Phase Description caf Operations 5/27/2009 16:00 - 17:00 1.00 CLEAN P CLEAN -Wash and taq FasDrill pluq at 8,560md w/ 5k down weight. -PU 2-3' to 8,557' md. 17:00 - 18:30 1.50 CLEAN P CLEAN Pump 100 bbls Hi Vis Sweep around Mill C~ 210 gpm / 720 psi. -Pump out to 8,519' md. -Increase pump rate to 378 gpm / 1750-2000 psi. -Pump sweep to surface - No noticable sand in returns. 18:30 - 19:30 1.00 CLEAN P CLEAN PUW 180k, SOW 155k, ROT wt 165k. WOB 5-10k. RPM 40 @ 2k Tq. Wash and rotate down to FasDrill w/ 182 gpm / 440 psi -Drill FasDrill pluq & push to 8 620' m~ -Well went on vacuum (~ 240 bph -Stand back 1 stand to 8,530' md. 19:30 - 00:00 4.50 CLEAN P CLEAN LD 4" DP from 8,530' to 2,261' md. -Fill hole 20 bbls every 15 minutes. Seawater losses to well= 514 bbls. 5/28/2009 00:00 - 02:30 2.50 CLEAN P CLEAN Continue to LD 4" Dp & 4 3/4" D.C's to 220' md. -Fill hole w/ 15 bbls of Seawater every 15 minutes. 02:30 - 03:30 1.00 CLEAN P CLEAN Break down Baker Cleanout BHA. -LD 2 7/8" PAC pipe, P.O.S. & Mill. -Fill hole w/ 15 bbls of Seawater every 15 minutes. 03:30 - 04:30 1.00 RUNCO RUNCMP Clear Rig floor of all Tools not needed for upcoming operation. -Fill hole w/ 15 bbls of Seawater every 15 minutes. 04:30 - 05:00 0.50 RUNCO P RUNCMP Pull Wear ring. -Fill hole w/ 15 bbls of Seawater every 15 minutes. 05:00 - 08:00 3.00 RUNCO P RUNCMP PJSM on RU to run 4 1/2" completion. -RU Tbg running equipmenY' -RU: single Jt compensator & Torque Turn Equipment. -Fill hole w/ 15 bbis of Seawater every 15 minutes. 08:00 - 12:00 4.00 RUNCO P RUNCMP Run 4 1/2", 12.6#, 13Cr-80, Vam Top Tbg. -Optimum torque 4440 t s. -Baker Lok all connections below Baker S-3 Packer. -Utilize "Jet Lube Seal Guard" thread compound. -Run Tbg to 2,600' md. -Fill hole w/ 15 bbis of Seawater every 15 minutes. Seawater losses for Tour = 850 bbls. 12:00 - 12:30 0.50 RUNCO RUNCMP Lubricate Rig. Inspect & service Top drive & Blocks. 12:30 - 20:00 7.50 RUNCO RUNCMP Continue to run 4 1/2" Vam Top Tbg. -Run Tbg from 2,600' to 8,482' md. -Fill hole w/ 15 bbls of Seawater every 15 minutes. 20:00 - 20:30 0.50 RUNCO P RUNCMP RU to pump down over Tbg Stub. -Fill hoie w/ 15 bbls of Seawater every 15 minutes. 20:30 - 22:30 2.00 RUNCO P RUNCMP Obtain parameters: PUW 152k, SOW 130k. 135 gpm / 40 psi. -Wash down over stub. Tag C~ 8,514' md. -Slack off to 8,520' md w/ 25k down wt. -No Shear indicated. No pressure increase indicated. -PU to 8,515' md. RU to reverse circulate. -Reverse circulate 135 gpm / 20 psi. -Slowly slack off. Apears to be washincidown. -Stack out C~ 8,520' md w/ 15k down wt -P ~ es. No success. -PU to 8,466' md. ~ Printed: 6/S/2009 17:3824 AM . ~ -- BP EXPLORATION Page ~3 af 14 Operations Sumrnary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task G~de NPT Phase ~escription of Operations 5/28/2009 22:30 - 00:00 1.50 RUNCO DPRB RUNCMP Wait on Slick line to drift Tbp to insure Tbq is open. 5/29/2009 00:00 - 02:00 2.00 02:00 - 03:00 1.00 03:00 - 05:30 I 2.501 RUNCO 05:30 - 11:30 I 6.001 RUNCO 11:30 - 12:00 I 0.501 RUN -Move pipe every 15 minutes to insure the pipe is free. -Fill hole w/ 15 bbls of Seawater every 15 minutes. Seawater losss for Tour = 850 bbis. Total losses or ay = s. ~ Total losses to well 2214 bbls. DPRB RUNCMP Wait on Slick line. -Move pipe to insure free movement. DPRB RUNCMP RD circulating equipment. -LD 1 Jt (#202) of 4 1/2" Tbg. -RU XO's (4) to 7" OTIS connection. -Clear Rig floor of all Tools & equipment not needed for Slick line operations. DPRB RUNCMP PJSM for Slick line PU & MU. MOB: Extension, Lubricator, Pump-in sub, BOP's & Packoff. -PU & MU same. DPRB RUNCMP PJSM w/ new Slickline crew (Changed out 06:00). -RIH w/ Slickline. -Ta RHC-M at 439' md WLM. -Pull RHC-M & POH. -LD RHGM. RUNCMP RD retieval Tools & C/O XO's. PU 3.625" drift. MU lubricator. Seawater losses for Tour = 750 bbls 12:00 - 18:00 6.00 RUNCO RUNCMP RIH w/ 3.625" drift to 8,700' md w/ no issues. -POH. LD drift. -RIH w/ RHC-M and re-set at 3 '~~~'1 -POH - LD running tooi -PJSM - RD slickline sheaves, pressure control 18:00 - 19:00 1.00 RUNCO RUNCMP PJSM on Space out. -LD Jts # 201 & 200. Replace Jt# 200 with Jt # 220. -Land Tbg. RILDS. 19:00 - 22:00 3.00 RUNCO RUNCMP U& reverse 236 bbls of 120 degree Seawater w/ Corrosion Inhibitor. -Chase w/ 185 bbls of Seawater. 126 gpm / 160 psi. 22:00 - 22:30 0.50 RUNCO P RUNCMP Drop Ball & Rod. Fill Tbg void (12 bbls). -Set Packer. 22:30 - 23:00 0.50 RUNCO P RUNCMP Chart & Test Tb to 3500 psi / 30 minutes - Pass. Install pump-in flange on IA & Tie into cement line. 23:00 - 00:00 1.00 RUNCO P RUNCMP -Fill IA void in Annulus (38 bbis~, -Pressure up Tbg to 1500 psi. -Chart & test IA to 3500 psi / 30 minutes - Pass. Seawater losss for Tour = 870 bbls. Total losses for day = 1620 bbls. Total losses to well 3835 bbl ~ 5/30/2009 00:00 - 01:00 1.00 RUNCO P RUNCMP Continue to hold pressure (1500 psi) on Tbg and Annulus (3500 psi). -Bleed pressure from Tbg. -Shear DCR-1 valve (sheared C~ 2500 psi differential). Printetl: 6/8/2009 11:38:24 AM ~ ~ BP' EXPLQRATION' Pag~ 14 of 14 Qperations Summary Report Legal Well Name: 11-04 Common Well Name: 11-04 Spud Date: 6/11/1980 Event Name: WORKOVER Start: 5/15/2009 End: 5/30/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/30/2009 Rig Name: DOYON 14 Rig Number: Date' From - To Hours Task Code NPT Phase Description of Op~rations 5/30/2009 00:00 - 01:00 1.00 RUNCO P RUNCMP -Confirm circulation: -The long way 126 gpm / 220 psi. -Reverse circulate 126 gpm / 240 psi. 01:00 - 02:00 1.00 RUNCO P RUNCMP RD circulating equipment. LD landing Jt. Install TWC. -Test TWC from below to 1000 psi / 10 minutes - Pass. -Test TWC from above to 3500 psi / 10 minutes - Pass. -Chart TWC test. 02:00 - 02:30 0.50 RUNCO P RUNCMP RD test equipment. -Blow down Kill line & Choke line. 02:30 - 05:00 2.50 RUNCO P RUNCMP PJSM on ND BOP Stack. -LD Mouse hole. Remove Flow line, Riser & Long Bales. -Remove Compensator sub. Clear Rig floor of unneeded items. -Remove Turnbuckles. Bleed off Hole fill & Choke line. -ND BOP Stack. Rack back Stack & secure. 05:00 - 07:30 2.50 RUNCO P RUNCMP Install Adaptor flange & 4 1/8" 5M Tree. Torque to Specs. -Test Flange & Tree to 5000 psi / 5 minutes - Pass. 07:30 - 08:30 1.00 RUNCO P RUNCMP PJSM w/ DSM. -RU Lubricator & test to 500 psi - Pass. -Pull TWC. RD Lubricator. 08:30 - 09:30 1.00 RUNCO P RUNCMP PJSM w/ Hot Oil. Spot truck & tanker. -RU to pump Diesel freeze protection (140 bbls). 09:30 - 12:00 2.50 RUNCO P RUNCMP HOT Oil pump Diesel -140 bbls / 84 gpm / 400 psi. -SIM-Ops - Slip on extra Drlg line to lower Derrick. RD Top Drive. 12:00 - 13:00 1.00 RUNCO RUNCMP U-Tube Diesel. -SIM- ps - Remove IBOP, Saver sub & Link Tilt. 13:00 - 13:30 0.50 RUNCO P RUNCMP Vacuum out lines w/ LRS. -Install BPV. 13:30 - 14:00 0.50 RUNCO P RUNCMP Chart & Test BPV from below to 1000 psi / 10 minutes - Pass. -RD - ube ines. 14:00 - 18:00 4.00 RUNCO P RUNCMP RD Pump-in flanges, Install Blank flanges. -Clear Cellar. Secure Cellar. T/I/O = 0/0/0 Release Rig C~ 18:00 Hrs. 5/30/09 Printetl: 6/8f2009 11:38:24 AM WELLHEAD = MCEVOY ACTUATOR= BAKERC KBE EL~/ _ - 55.0' BF. ELEV - NA KOP = 4150' Max Angle = 30° @ 6099' Datum MD = 9123' Datum ND = 8800' SS 9-5/8" BOWEN CSG PATCH, 47#, L-80 HYD 563, ID = 8.681" 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ I SAF~ NOTES: ""xCHROMETBG, LNRB~ NIPPLES""` 11-0 4A I 1806' I I 2710' I Minimum 1D = 3.725" @ 8587' 4-1/2" OTIS XN NIPPLE 9-5/8" CSG, 47#, L-80, ID = 8.681" I-I 7786' 7" LNR, 29#, N-80 XO TO 13CR-8Q NSCC ~-~ $441' PERFORATION SUMMARY REF LOG: Z-DENSILOG ON 03/01/94 ANGLEAT TOP PERF: 7° @ 9170' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 2 9139 - 9149 S 05/24/98 2-1/2" 4 9170 - 9190 O 03/22/94 1762~ -19-5/8" HES ES CEMEMER 1779~ 9-5/8" BKR ECP GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3457 3456 0 MMG DOME RK 16 06/02/0~ 3 5851 5741 28 MMG DOME RK 16 06/02/0£ 2 7476 7236 17 MMG DOME RK 16 06/02/Of 1 8288 8029 10 KBG-2 SO BK 24 06/02/0~ 7614~ 7" BKR TIEBACK SLV, ID = 5.31" 7621' 9-5/8" X 7" BKR LTPw/BKR LNR HGR, ID = 6.19"? 9-5/8" MILLOUT WINDOW (11-04A) 7786' - 7831' 8365~ 4-1/2" HES X NIP, ID = 3.813" 8396' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8430' 4-1/2" HES X NIP, ID = 3.813" 8517~ 7"X4-1/2"UNIQUEOVERSHOT ~ $540~ 7" X 4-1/2" BKR SABL-3 8570' 8587' 4-1/2" TBG STUB (05/20/09) -~~Sc.~~ ~ 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 8599~ ~° MARKERJOINT (19') 8751' Pero s312' 7" LNR, 29#, 13CR-80 NSCC, .0371 bpf, ID = 6.184" 9353~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/25/80 ORIGINAL COM PLETION 03/OS/94 RIG SIDETRACK 05/30/09 D14 RWO 06/12/09 DB/JMD DRLG DRAFT' CORRECTIONS 06/13/09 JMD GLV GO (06/02/09) 2014' ~~ 4-1/2" HES X NIP, ID = 3.813" PKR, ID = 3.875" ~ 4-1/2" OTIS X NIP, ID = 3.813" 4-1/2" OTIS XN NIP, ID = 3.725" 8599' I--~4-1/2" WLEG, ID = 3.958" ~ 8591 ~ ELMD TT LOGGED 03/13/95 H620' FISH: FASDRILL PLUG PUSHED TO BTM ~ (05/27/09) PRUDHOE BAY UNIT WELL: 11-04A PERMff No: ~1940230 API No: 50-029-20480-01 SEC 33, T11 N, R15E 604' FNL & 8' FEL 00 ~....~..~..a:..., iwi....~...~ ~1 ~J .~ S~hberg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~-! ~ ~~. t~rnisss~r~ ~r~lt~e~ Log Description NO.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Oate BL Color CD os/os/os H-35 AYTO-00018 CROSS FLOW CHECK j 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE ~ 05/15/09 1 1 06-OSA AViH-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYOQ-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - ~ , 05/06/09 1 1 15-458 ANHY-00010 PRODUCTION PROFILE '~-- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ 05/08/09 1 1 M-196 AY3J-00024 PRODUCTION PROFILE 05!14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A B1JJ-00018 MEM CNUSTP p a. ~ 05/18/09 1 1 X-30A 62WY-00005 MEM PROD PROFILE C 05/10/09 1 1 i2-23 AYKP-00021 USIT G - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG • (®- 05/20/09 1 1 Lt-21 62ND-00006 PRODUCTION PROFILE _ 05/24/09 1 1 A-31A AZCM-00023 USIT ~ - Q fp <. 05/22/09 1 1 H-19B' 62WY-00004 MEM PROD PROFILE L 05/07/09 1 1 G-16 AYKP-00022 SCMT f J 05/09/09 1 1 M-19B AY3J-00024 SCMT - 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ [/!~ / 04/21/09 1 1 11-04A AYOO-00028 USIT f e/ - 05/21/09 1 1 18-30 61JJ-00015 MEM PROD PROFILE JG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE 5-~ i 05/11/09 1 1 3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL ~ / ~jJ 04/26/09 1 1 PLtASt A(:KNUWLtUI.it Fit(:tIY I I3T ~1(iNINCi ANU lit I UFININCi UNt l;Vl'Y tA(:t1 I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • 0 ~ ~ O SARAH PAL1N, GOVERNOR ~5$A OITj A1~TD GAS 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'TIOI~T COMbII551O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. ~1 PO Box 196612 ~ Q Anchorage AK 99519-6612 ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-04A Sundry Number: 309-035 . i*~ X16'8 fr _ q" jN t`~E C ~~. ~ p~ fy -' - ~'~r. a~rxv. _ ti. .. ~ L Dear Mr. Hobbs: Enclosed is the approved Application far Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless : ehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair r DATED this ~ day of February, 2009 Encl. v` ~ > v_~ • ';1,j , ~1~~,,"1~,~ r~G~ STATE OF ALASKA ~ /a9-09 j,.., !~ ,~;~ALA~ OIL AND GAS CONSERVATION COMII~ION ~CCE~VEL1 ~~ ~ APPLICATION FOR SUNDRY APPROVA 20AAC25.280 ~~ Innl 2 Q Anna e Extension 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Tim p e ®Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate L9'ft9=~n~ ~~~~+ Commiss ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other Anchorage 2. Operator Name: 4. Current Weil Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 194-023- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20480-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 11-04A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): C3'~~ ADL 028325 54.26' Prudhoe Bay Field / Prudhoe Bay Pool '12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9355' - 9084' - 9311' 9041' 8571' None sin L n h iz M TVD B r t olla r rl n 1 1 1 rt 271 1 /" 7 0' 7 4 3 2670 In is a 77 / " 77 7 7 4760 Pr finer 17 7" 7 14' - 7 724 1 Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 9170' - 9190' 8901' - 8920' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 8599' Packers and SSSV Type: T' x 4-1/2" Baker'SABL-3' packer Packers and SSSV MD (ft): 8540' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well atus fter proposed work: , `' Commencin O erations: April 1, 2009 ~ Abandoned Oil ^ Gas ^ Plugged 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that t e f ~fegoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-59x1 Printed Name Gr s Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-4191 Date ~2 ~ Terrie Hubble, 56a-x628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness S ~ ~ Ct5 ~ ~ ' ^ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance ~-5C7~PS v,-~iic~~ ~v r~C;~~~J ~~ ~~~ Other: ~~ ~a S c ~~~~~~ ; Subsequent Form R uired: ' ~d L- APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006/ Submit In Duplicate m ~~~.r~~~ t~~~~~~RI~INAL • . by c~~ 11-O4A Rig Workover Well Type: Producer Scope of Work: Pull 4-1/2" x 5-1/2" 13CR-80 tubing. Cut and pull 9-5/8" casing, run and cement to 9-5/8" surface casing, test 9-5/8" casing. Run 4-1/2" 13CR-80 tubing. Current Status: This well is completed with 5-1/2' x 4-1/2" 13CR tubing and is currently shut-in. Request : Pull Tubing, alter casing. Other Requests: ~~~~~~~~ Given rig floor height limitations, a MASP < 3000 psi,, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: • Cut and pull the existing 5-1/2" x 4-1/2" tubing above the production packer at 8,450'. • Run USIT log on the 9-5/8" casing. • Cut and pull 9-5/8" casing. Run new 9-5/8" casing patch and cement to surface. • Replace 9-5/8" packoff. • Run 4-1/2" 12-CR80 tubing with stacker packer completion. • There is a contingency to run 7"from 7614' to surface and fully cement it, if unable to cut and pull the 9-5/8" casing. MASP: 2,470 psi Estimated Start Date: April 1, 2009 Pre-rig prep work: S 1 Pull PX lu ~ 8,571'. Drift for Fasdrill lu to 8587' E 2 Set Fasdrill plug in the 4-1/2' tubing C~3 8,555' MD below the production packer and above the X Ni le at 8,571'. CMIT T x IA to 3,000 si to verif lu inte rit /barrier. E 3 Jet cut the tubing at 8,510' MD (reference tubing tally of 3/4/94) in the middle of the first full 'oint above the roduction acker. F 4 Circulate well with seawater. FP with diesel throu h the cut. Bleed Wellhead ressure to 0 si. W 5 Check the tubing hanger lockdown screws for movement. Completely back out and check each lock down screws for breaka a check one at the time .Well should be secured with a Fasdrill • • lu at this time. V 6 Set a BPV in the tubin han er 7 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . D 8 .Line the cellar around the wellhead with s ra -sealed Herculite. Proposed Procedure: 1. MIRU Nabors 2ES. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine. 2. Pull and LD 5-1/2" x 4-1/2" tubing string. Test the lower set of pipe rams. 3. RU E-line. Run USIT/GR/CCL from cut stub to surface to confirm the TOC on the back-side of the casing. 4. Run 9-5/8" RBP and set 100' below TOC behind 9-5/8" casing. Pressure test RBP to 3500 psi to prove barrier. Place 50' of sand on RBP. 5. Cut and pull the existing 9-5/8" casing in the middle of the second full joint above the TOC based on USIT results. Displace with diesel and heated seawater to remove Arctic Pack. 6. Run 9-5/8" 47# L-80 HYD 563 casing with ECP, ES Cementer and casi g p~ atch. ~~~~~~ ~~\`~ ~S~ 7. Run new 4-1/2" Chrome tubing completion with packer at --8440'. '9-- 8. Displace the IA to packer fluid and set the packer. -~5~. "~"~' ~•"~r~ 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. c-recpu~C-- Q~Q 10. Set BPV. ND BOPE. NU and test tree. RDMO. ~~ ~~... Drilling Engineer: Name Mehrdad Nadem 907-564-5941 Production Engineer: Name Trina Cooper 907-564-5254 Geologist: Name Daniel Schafer 907-564-5098 ATTACH: Current Schematic Proposed Schematic TREE = 5-1 /8" FMC WELLHE>4D = GRAY ACTUATOR = AXELSON KB. ELEV = .._..~ 55.0' BF. ELEV = NA KOP = 4150' Max Angle = 30 @ 6099' Datum MD = 9124' Datum TVD = 8800' SS SAFETY NOTES: ***CHROM E TBG 8 LNR""' ~ 11-0 4A I 13-3/8" CSG, 72#, N-80, ID = 12.347" ~~ 2710• Minimum ID = 3.725" @ 8587' 4-1 /2" OTIS XN NIPPLE 5-1/2" TBG, 17#, 13-CR-80, .0232 bpf, ID = 4.892" 2836' TOP OF BKR TIEBACK SLV, ID = 7.50" 7614' 9-5/8" X 7" BKR LT PKR, ID = 6.184" 7621' 9-5/8" X 7" BKR HMC HGR, ID = 6.184" 7627' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 7786' PERFORATION SUMMARY REF LOG: Z-DENSILOG ON 03/01/94 ANGLE AT TOP PERF: 7 @ 9170' Note: Refer to Production ~ for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 2 9139 - 9149 S 05/24/98 2-1 /2" 4 9170 - 9190 C 03/22/94 ~ 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~ 7" MARKERJOINT(19') H 8751' PBTD -i 9311' F 7" LNR, 29#, 13CR-80, .0371 bpf, ID = 6.184" 9353' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/25!80 ORIGINAL COMPLETION 03/05194 RIG SIDETRACK 10/14!05 TWS/PJC GLV GO 02/28/06 TEL/PJC GLV GO 09/12/06 CJNITLH PX TTP PLUG SET ~~5-1/2" OTIS HRO SSSVN, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3011 3011 0 MMGM DOME RK 16 02/28/06 2 5058 5017 18 MMGM DOME RK 16 02/28/06 3 6272 6110 27 MMGM DOME RK 16 02/28/06 4 6857 6655 20 MMGM DMY RK 0 03/05/94 5 7126 6907 23 MMGM DMY RK 0 03/05/94 6 7394 7159 16 MMGM DMY RK 0 03/05/94 7 7505 7264 17 MMGM SO RK 20 02/28/06 2838' 5-1/2" X 4-1/2" TBG XO, ID = 3.958" 9-518" CSG MILLOUT WINDOW 7786' - 7831' (SECTION MILL) $4$2' 4-1/2" OTIS X NIP, ID = 3.813" $540' 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" 8571' 4-1/2" OTIS X NIP, ID = 3.813" 8571' 4-1 /2" PX TTP PLUG (09/12/06) $587' 4-1/2" OTIS XN NIP, ID = 3.725" $599' 4-1/2" TBG TAIL WLEG 8591' ELMD TT LOGGED 03/13/95 PRUDHOE BAY UNIT WELL: 11-04A PERMlT No: 1940230 API No: 50-029-20480-01 SEC 34, T11 N, R15E 604' SNL & 8' EWL BP Exploration (Alaska) TREE = 5-1 /8" FMC WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 55.0' BF. ELEV = NA KOP = 4150' Max Angle = 30 @ 6099' Datum MD = 9124' Datum TV D = 8800' SS ~ 11-04A 2009 RV1~ 113-3/8" CSG, 72#, N-80, ID = 12.347" I I 2710' I Minimum ID = 3.725" @ 8587' 4-1 /2" OTIS XN NIPPLE 7' BKR TIEBACK SLV, ID = 7.50" 7614' 9-5/8" X 7" BKR LT PKR, ID = 6.184" 7621' 9-5/8" X 7" BKR HMC HGR, ID = 6.184" 7627' 9-5/8" MILLOUT WINDOW (11-04A) 7786' - 7831' 9-5/8" CSG, 47#, L-80, ID = 8.681" 7786' 7" LNR, 29#, N-80 XO TO 13CR-80 NSCC I~ 8441' PERFORATION SUMMARY REF LOG: Z-DENSILOG ON 03/01/94 ANGLE AT TOP PERF: 7 @ 9170' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 2 9139 - 9149 S 05/24/98 2-1/2" 4 9170 - 9190 C 03/22/94 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 8598' I7" MARKERJOINT(19') ~ 8751' PBTD 9312' 7" LNR, 29#, 13CR-80 NSCC, .0371 bpf, ID = 6.184" -~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/25/80 ORIGINAL COMPLETION 03/16/08 GJFlTLH GLV GO & PLUG PULLED (319/08) 03/05/94 RIG SIDETRACK 05/24/08 BSE/SV SET PX PLUG (05/14/08) 10/14/05 TWS/PJC GLV GO 02/28/06 TEUPJC GLV GO 09!12/06 CJN/TLH PX TTP PLUG SET 11/05/07 JLJ/PJC GLV C/O SAFETYN~ °'q-~T1~S~LN~""` 1950` 9-5/8" HES ES Cementer 1950` 9-5/8" BKR ECP 1980` 9-518" Bowen Casing Patch 2 000` -5/8" 47#, L-80, Hydrill 563, ID=8.835' 2 200` 4-1/2" HES X NIP, ID = 3.813" Gas Lift Mandrels ST MD TVD DEV TYPE 4 - x 3 - x 2 - x 1 - x 8400` 4-1/2" HES X NIP, ID = 3.813" 8440` 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 8480` 4-1/2" HES X NIP, ID = 3.813" 8510` 4-1/2" 13CR 12.6#, ID=3.958" 8510` 7" x 4-1/2" 13CR Unique Overshot 8~540~ 7" X 4-1/2" BKR SABL-3 PKR ID = 3.875" 8571' I~ 4-1 /2" OTIS X NIP, ID = 3.813" 14-1/2" OTIS XN NIP. ID = 3.725" 14-1/2" WLEG, ID = 3.953" I 8591' ELMD TT LOGGED 03/13/95 PRUDHOE BAY UNfT WELL: 11-04A PERMIT No: 1940230 API No: 50-029-20480-01 SEC 34, T11N, R15E604' SNL i£ 8' EWL BP Exploration (Alaska) C ,. ProActive Diagnostic Services, Inc. • :~ ~~ ~ ~ _ ~ .-~ 3~~~?'~ ~ ~ ~ ~ . .., - -- To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Bhrd. Anchorage, Alaska 99508 and ~~ )~i~~ ~ ~ ~~~ 1;ctlve:,Qiagnostic_Seruices, Inc. Af~ - Oo~rt A.-Richey _. 130 West International Airport Road Suite C Anchorage, AK 99518 . Fax: (907) 245-8952 /~~/-~3 '~/(~DU~ 1) Leak Detection -WLD 24-Fetr08 D6 16-04A 1 EDE Leak Detection -WLD 28-Feb-08 DS 11-04A EDE Signed : ~ Date Print Name: (~ ~; ~ r Q ~~~,r,rUi.G4 50-029-20561-01 5029-2480-01 ~' _ __ :.. , PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (90245-88952 E-MAIL: ~~san~~s®rage(a?merra~r*!lo~9.c~rr~ WEBSITE: ~nnn~;~.a'rger5a©rv9tat~ ~:~rra C:\Documen6 and Settingsl0wne~Desktop\Tnmsmit_BP.doc 11-04A (PTD #1940230) Internal Waiver Cancellation - Normal Well Subject: 11-04A (PTD #194!0) Internal Waiver Cancellation - NO!I Well 1<"t'l ?/z'1I~ From: "NSLJ, ADW Well rntcgrity Engineer" <NSUADWWcllIntcgrityEngincer@BP.com> Date: Tue, 21 Feh 2006 15:27:15 -0900 To: "AOGCC - Winton Aubert (E-mail)..<winton__auhcrt@admin.state.ak.us>. jim_regg@admin.statc.ak.us, "!\SU, ADW Well Operations Supervisor" <I\SUAD\VWeIlOperationsSupervisor@BP.com>, "R.ossberg, R Steven" <Steven.Rossberg@BP.com>, "GPB, FS2/COTU Area Mgr" <GPBFS2TL@BP.com>, "Kurz, John" <john.kurz(@BP.com>, "GPB,FS2 DS Ops Lcad" <GPBFS2DSOpsLead@BP.com> cc: "NSLJ, ADW \-Vell rntcgrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "NSU, ADW WI Tcch" <NSUADWWITech@BP.com>, "Cooper, Katrina N" <Katrina.Cooper@BP.com>, "Winslow, Jack L." <Lyonsw@ßP.com> All, An internal waiver was issued for IAxOA communication on well 11-04A (PTD #1940230) on 10/19/05. An OA repressure test was conducted on 02/11/06 with a pressure differential of 2000 psi between the IA and OA. Over the next four days, the OA repressured a total of 30 psi showing there is no IAxOA communication. Daily pressure readings will help identify if the communication returns in the future. The well is reclassified as a Normal well with normal operating pressure limits of 2000 psi on the lA, 1 000 psi on the OA. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Please let me know if you have any questions. Thank you, }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 c:·,t·... A "- ,~, ~;~-. \¡:t;Ø,~" \;~.,:!e;.;J'~~1 .'ìç '"I r¡ Íì h ,. l ';~'; ,to. f ~I f,;' ~J 1 of I 2/27/200612:13 PM MEMORAND 3NI State of' ias ka Alaska Oil and Gas ConserVation CommiSsion TO: Mike Bill Commissioner THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL DATE: December 8, 2002 SUBJECT: Mechanical Integrity Tests ,\t __~'-g~ BPX PBU · DS ~1:~4A P rod ucer Class 137 Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 11-04A IType,nj.I N/A I ~.V.D. I~.~ I Tubingl 1500 I 1500 I 1500 11500 Ilntervall O P.T.D.I 1940230 ITypetestl P ITestpsil 3000 I Casingl 550 I 3000 I 2940 I 2920I P/F IP Notes: OA Pressure increased F/0 test. WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type I NJ. 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 travelled to BP's PBU DS 11 to witness the MIT on WAr Producer 11-04A. No problems witnessed. M.I.T.'s performed: Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. CC.' MIT report form 5/12/00 L.G. MIT BPX PBU 11-04A 12-08-02 JC.xls 12/11/2002 ON OR BEFORE W .DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: Operation Shutdown_ Stimulate__ Plugging_ Perforate _ Pull tubing _ Alter casing_ Repair well _ Other_X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _X 54' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchora~le, AK 99510-0360 Service _ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 604' SNL, 8' EWL, Sec 34, T11N, R15E, UM. 11-04A At top of productive interval: 9. Permit number/approval number: 1517' SNL, 987' WEL, Sec 33, T11N, R15E, UM. 94-023 At effective depth: 10. APl number: 50-029-20480-01 At total depth: 11. Field/Pool: 1592' SNL, 962' WEL, Sec 33, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary , . Total Depth: measured 9355 feet Plugs (measured) true vertical 9084 feet Effective Depth: measured 9311 feet Junk (measured) true vertical 9040 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 343 Sx PF 110' 110' Surface 2656' 13-3/8" 2500 Sx Fondu & 2710' 2710' 400 Sx PF Production 7732' 9-5/8" 500 Sx Class G & 7786' 7535' 300 Sx PFC Liner 1739' 7" 339 Sx Class G 9353' 9082' Perforation Depth measured 9170 - 9190' true vertical 8846 - 8865' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 2836' MD; 4-1/2", 12.6#, L-80, Tbg @ 859~3LI~D Packers and SSSV (type and measured depth)Baker SABL-3 Packer @ 8540' MD; 13. Stimulation or cement squeeze summary d t,,, L.- Intervals treated (measured) see attached Alaska 0il & Gas Cons. Commission Intervals treated (measured) Anchorage 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 864 19226 1464 1702 Subsequent to operation 532 1073 566 207 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"~~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 11-04A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 4/1/98: RIH & tagged PBTD at 9197' MD. 5/4/98: MIRU CTU & PT equipment. RIH w/CT & loaded wellbore w/Crude. Tagged bottom, then PU & pumped Gelled Sand Slurry containing a total of 1750 lbs of sand, to place an isolation sand plug across the lower open perforation interval located at: 9170 - 9190' MD (Z1) Ref. Log: Z-Densilog 3/1/94. Made a final TOS tag at 9164' MD. POOH w/CT. RD. 516198: RIH w/dump bailer & dumped 11 gallons of liquid sand cap on top of the sand plug, to raise plug to 9162' MD. 5115198: An Acid Wash & Maraseal Gel/Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment. RIH w/CT & loaded the wellbore w/1% KCI Water & Crude. Reciprocated an acid wash across the leaking perforation interval (interval was previously Maraseal Gel squeezed 4/25/95) at: 9139- 9149' MD (Z1) Ref. Log: Z-Densilog 3/1/94. Pumped 20 bbls of 2% NH4CI Water w/Citric Acid, followed by 10 bbls of 70/20/10% Diesel/Xylene/Musol, followed by 15 bbls 12% HCI w/10% Xylene @ 1.8 bpm, followed by 10 bbls 6% HCL - 0.75% HF, followed by 15 bbls 12% HCI w/10% Xylene, followed by 20 bbls of 2% NH4CI Water, followed by 40 bbls of 1% KCI Water. Swapped to pumping Gel / Cement Squeeze to resqueeze the leaking perforation interval (listed above). Pumped 130 bbls of 1% KCI Water, followed by 100 bbls of Crosslinked Maraseal Gel @ 1.1 - 1.3 bpm, followed by I bbl of Seawater spacer, followed by 30 bbls of Latex Acid Resistive Cement. Placed all the Gel & LARC behind pipe without reaching squeeze pressure. Attained 560 psi max final squeeze pressure. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 9162' MD. RD. 5124198: A Cement Resqueeze for Gas Shutoff was performed as follows: MIRU CTU & PT equipment. RIH w/CT & loaded the wellbore w/1% KCI Water & Crude, then resqueezed the leaking perforation interval (listed above). Pumped 6 bbls of Neat Latex Acid Resistive Cement, followed by 10 bbis of Latex Acid Resistive Cement w/20# bbl aggregate, followed by 23 bbls of Neat Latex Acid Resistive Cement. Placed 16 bbls of cement behind pipe and attained 3500 psi max final squeeze pressure. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 9160' MD. RD. Produced the well through the isolation sand plug. 7/12/98: RIH & tagged bottom fill below the open perforation interval (listed above) at 9195' MD. Returned the well to production w/gas lift & obtained a valid welltest. P E Ri'41 T DATA AOGCC individual Well ....~,~eoiogical Materials Inven'~i~y T DATA_PLUS Page: i Date: 10/13/95 RUN DATE_RECVD 94-023 94-023 ~L/GR 94-023 ~L/GR/SP 94-023 T 8410-9341, OH-DLL/ZDL L 8475-9341 L 8475-9303 L 8475-9341 '~UAL BURST TDT-P L 8800-9184 94-023 z~4~RF L 8450-9170 94 023 - PL/FBS-LFS L 9000-9190 94-023 ~S/STVD L 8475-9341 94-023 ~SiT (C&C) L 8400-9300 94-023 '~zDL/cNL/GR/CAL I, 8~75~9324 05~27/94 o t2719 02/26/95 10/19/94 03/0S/95 04/2!/94 04/27/94 04/27/9{ Are dry ditch samples required? yes~ A_~nd receive'~cL?~ Was the well cored? yes ~p. alysis & description receivedl. .~-s o Are well test{ required?~s Received? Well is in compliance Initiaz STATE OF ALASKA ALASKA"'-'"'_ AND GAS CONSERVATION C(, 'MISSION REPORT' ,F 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 604' SNL, 8' EWL, Sec. 34, T11N, R15E, UM At top of productive interval 1517' SNL, 987' WEL, Sec. 33, T11N, R15E, UM At effective depth At total depth 1592' SNL, 962' WEL, Sec. 33, T11N, R15E, UM 12. Present well condition summary Total depth' measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service 9355 feet Plugs(measured) 9084 feet 6. Datum of elevation(DF or KB) 56' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-4A 9. Permit number/approval number 94-023 10. APl number 50 - 029-20480-01 11. Field/Pool Prudhoe Bay Oil Pool Effective depth' measured 9311 feet true vertical 9040 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 343 sx PF 110' 110' Sudace 2654' 13-3/8" 2500 sx Fondu & 400 sx PF 2710' 2710' Production 7775' 9-5/8" 500 sx G & 300 sx PFC 7831' 7579' Liner 1739' 7" 339 sx CIG 9353' 9083' Perforation depth: measured 9139-9149'; 9170-9190' true vertical 8869-8879'; 8900-8920' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 2836' MD; 4-1/2", 12.6#, L-80, Tbg @ 8599' MD Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker SABL-3 Packer @ 8540' MD; 5-1/2", Otis HRQ SSSV @ 2231' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. OiI-Bbl Gas-Md Water-Bbl Prior to well operation 2021 25,322 691 Subsequent to operation 1129 3830 75 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Representative Daily Average Production or Injection Data Casing Pressure Oil X___ Gas __ Suspended __ Service Tubing Pressure 1125 772 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~,.....~.~..~2., ~ ~ Title Engineering Supervisor Form 10-404Rev 06/15/88 GSS cc: KZ, JWP. Date "~//Z__..~/¢~'""'"'~ SUBMIT IN DUPLICATE ,'-,.~. 11-04A DESCRIPTION OF WORK COMPLETED MARASEAL GEl_ SQUEEZE FOR GAS SHUTOFF 4/1 8/95: RIH & tagged PBTD at 9194' MD. 4/25/95: A Maraseal Gel Squeeze using an Inflatable Packer was performed for Gas Shutoff as follows: MIRU CTU & PT equipment. Loaded the wellbore w/Dead Crude & RIH w/CT mounted inflatable packer. Inflated & set packer at 9160' MD, to isolate the lower open perforation interval located at: 9170 - 9190' MD (Z1) Ref. Log: Z-Densilog 3/1/94. Pumped Maraseal Gel to squeeze the perforation interval located above the packer at: 9139 - 9149' MD (Zl) Ref. Log: Z-Densilog 3/1/94. Pumped: a) 125 bbls Seawater @ 1.8 bpm to establish injection, followed by b) 47 bbls Maraseal Gel w/delayed crosslinker @ 1.0 bpm, followed by c) 10 bbls Maraseal Gel w/crosslinker @ 1.0 bpm, followed by d) 3 bbls Maraseal Gel w/delayed crosslinker @ 1.0 bpm, followed by e) 1 bbl Seawater, followed by f) Dead Crude Flush. Displaced 57 bbls of Gel behind pipe at 375 psi max squeeze pressure. Hesitated squeeze, but could not establish squeeze pressure. Released & POOH w/packer leaving 320 psi on well. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. Note: Oil rate decreased by 892 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1803 BOPD, resulting in a net oil benefit of 911 BOPD. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.9296 Company: 3/2/95 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 Mylar Disk .. D.S. 1-.2~'.~ LEAK DETECTION 021 995 I 1 D.S. 4-1-"2~) TUBG PUNCHER RECORD 021895 I 1 D.S. ~?~_~ RESERVOIR SATURATION 0 2 21 9 5 ,, I 1 D.S.4~~ CNT-G 0221 95 I 1 D.S. 4-~ P~F "E~RD 0 21 9 9 5 I 1 D.S. 4-48~ P~F .E~RD 0 21 3 9 5 I 1 D.S. 6-3~ PRODUCTION LOG 022195 1 1 D.S. 7-4A~ PERFRECORD 021595 1 1 D.S. 9-2~ ~ INF~TABLE BRIDGE PLUG 021795 I 1 D.S. 9-11~ P~F RE'RD 021895 I 1 D.S. 9'45 ~ P~F RE'RD 022095 I 1 D.S. 13-2~ INF~TABLE BRIDGE PLUG 021795 1 1 D.S. 11-4~ PROD PRORLE 022095 I 1 D.S. 15-11~ PROD PRORLE 022095 I 1 D.S. 18-1~ ~ DUAL BURST TDT-P 021895 1 1 D.S. 11-~ 95058 DUAL BURST TDT-P 021195 1 D.S.~~- ~ ~ 95057 DUAL BURST TDT-P 020595 I Please sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED !~E: ~ !995 Alaska 011 & Gas Cons. Commission Thank you. Anch0mge GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.9296 Company: 3/2/95 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 Mylar Disk D.S. 4-1~ TUBG PUNCHER RECORD 021 895 I 1 D.S.-.~'~ ~ RESERVOIR,~ SATURATION 022195 I 1 D.S. 4"--2~6~"~ CNT-G 022195 I 1 D.S. 4-.,19"°, PERF RECORD 021 795 1 1 D.S. 4-3,~ PERFRECORD 021 995 I 1 D.S. 4-48``````) PERF RECORD 021395 I 1 D.S. 6-3~,"-u~ PRODUCTION LOG 0221 95 I 1 D,S. 7-4A'"~ PERF RECORD 021 595 I 1 D.S. 9-2.~"'-~, ~ INFLATABLE BRIDGE PLUG 021 795 1 1 D,S. 9-11~-.~ PERF RECORD 021895 I 1 D.S. 9-45 '"'-.)' PERF RECORD 022095 I 1 D.S. 13-20~'--* INFLATABLE BRIDGE PLUG 021795 I 1 D.S. 11-4A'~..~ PROD PROFILE 022095 I 1 D.S. 15-11-.~ 5 PROD PROFILE 022095 I 1 D.S. 18-1,~.,, ¥ DUAL BURST TDT-P 021895 I 1 D.S. 11-0~ 95 05 S DUAL BURST TDT-P 0211 95 1 D.S. -1--t-g~- q5 95057 DUAL BURST TDT-P 020595 I ~-q SIGNED: R E CEI V ED ~Aa~'E: 5 !995 Alaska 011 & 6as Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Anchorage STATE OF ALASKA ALASK/ 'IL AND GAS CONSERVATION C MISSION REPORT dF SUNDRY WELL OP,--RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 604' SNL, 8' EWL, Sec 34, T11N, R15E, UM At top of productive interval 1517' SNL, 987' WEL, Sec 33, T11N, R15E, UM At effective depth At total depth 1592' SNL, 962' WEL, Sec 33, T11N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 56 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-04A 9. Permit number/approval number 94-023 10. APl number 50 - 029-20480-01 '11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9355 feet 9084 feet Plugs(measured) PBTD Tagged @ 9188' MD (10/7/94) Effective depth: measured 9188 feet true vertical 8918 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110 20" 343 Sx PF 11 O' 11 O' Surface 2654' 13-3/8" 2500 Sx Fondu & 400 Sx PF 2710' 2710' Production 7775' 9-5/8" 500 Sx Cl G & 300 Sx PFC 7831' 7579' Liner 1739' 7" 339 Sx CIG 9353' 9083' RECEIVED Perforation depth: measured 9139- 9149'; 9170- 9190' NOV - 7 1994 Aircska 0il & Gas Cons. Commission true vertical 8870 - 8880'; 8900 - 8920' Anchora¢o Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR-80, Tbg @ 2836' MD; 4-1/2", 12.6#, 13CR-80, Tbg @ 8599' MD. Packers and SSSV (type and measured depth) 7 x 4-1/2" Baker SABL-3 Packer @ 8540' MD; 5-1/2", Otis HRQ SSSV @ 2231' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production orlniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2278 12911 73 -- / 2295-// 14008 0 -- Tubing Pressure 269 272 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'.~ /~. Form 10-404 Rev 06/15/88 cc: KZ. JWP. Title Engineering Supervisor SUBMIT IN DUPLICATE 11-04A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I 0/7/94: RIH & tagged PBTD at 9188' MD. I 0/1 0/94: MIRU & PT equipment. Added perforations: 9139 - 9149' MD (Z1B) Ref. Log: Z-Densilog 3/1/94. Used a 3-3/8" carrier & shot 2 spf at 180 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. RIH w/perforating gun & shot 10' of add perforations as follows: Returned the well to production & obtained a valid welltest. RECEIVED NOV - 7 1994 AJ~ska 0il & 6as Cons. Commission Anchora,j,, GeoQuest 60(] W. International Aiq3ort Road Anchorage, AK 99618-1199 ATrN: Sherrie NO. 9010 Company: Alaska Oil & Gas Cons Oomm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 10/18~94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar '~ 0 "' ~(~ J~.S. 1-05 ST1 PROD PROFILE (10-8-94) ., 1 1 ,,, ~..S.. 4-16 PERF REOORD (1.,0-11-94) 1 1 J:).S. 4-16 JEWELRy LOG (10-11-94) 1 1 '" J).S. 4-48 ROPE PERF RECORD (10-,9-94) 1 " 1 D.S. 6-10 LEAK DETECTION (10-11-94) 1 1 D.S. 9-26 ,,, LEAK DETECTION (10-10-94) 1 '" 1 D.S. 11-4A PERF RECORD (10-10-94) 1 1 D.S. 14-19 ST DUAL BURST TDT-P (10-7-,94) 1 "1 J).S. 17-13 STAtiC BHP SURVEY (10-10-94) '1 ' " 1 ,, SIGNE .~ _.., Plea~'~ign and return one copy of this transmittal to She the above addreg9. Thank you.' DATE: Alaska 0i~ & Bas Cons. c0mmissi0~ ---. STATE OF ALASKA -- ALASKA .LAND GAS CONSERVATION CC, ,vllSSlON REPORT OF SUNDRY WELL OPERATIONS ,Jperations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 604' SNL, 8' EWL, Sec. 34, T11N, R15E, UM At top of productive interval 1517' SNL, 987' WEL, Sec. 33, T11N, R15E, UM At effective depth At total depth 1592' SNL, 962' WEL, Sec. 33, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service ORI8IIxlAL 6. Datum of elevation(DF or KB) 56' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-4A 9. Permit number/approval number 94-023 10. APl number 50 - 029-20480-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9355 feet 9084 feet Plugs(measured) PBTD Tagged @ 9284' M D (3/27/94) Effective depth: measured 9284 feet true vertical 9014 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 343 sx PF 110' 110' Surface 2654' 13-3/8" 2500 sx Fondu & 400 sx PF 2710' 2710' Production 7775' 9-5/8" 500 sx G & 300 sx PFC 7831' 7579' Liner 1739' 7" 339 sx CIG 9353' 9083' Perforation depth: measured 9170-9190' true vertical 8900-8920' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 2836' MD; 4-1/2", 12.64¢, L-80, Tbg @ 8599' MD Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker SABL-3 Packer @ 8540' MD; 5-1/2", Otis HRQ SSSV @ 2231' MD 13. Stimulation or cement squeeze summary r~ L ~,, L. I v L ~,' 14. Intervals treated(measured) See Attached Treatment description including volumes used and final pressure JUL 1 8 1994 ~,taska 0il & Gas Cons. Commission Prior to well operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure .- Subsequent to operation 2697-- 9210 64 257 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 2~'" ~ Title Engineering Supervisor Form 10-404"Rev 06/15/88 1140/10 MJBKRF cc: JED. JWP Date 7////'~z~ SUBMIT IN DUPLICATE 11-04A DESCRIPTION OF WORK COMPLETED ROPE PERFORATIONS & FRACTURE TREATMENT OF ZONE I 3/12/94: RIH & tagged PBTD at 9325' MD. 3/22/94: MIRU & PT equipment. RIH w/perforating gun & logged into position. Pumped 39 bbls of Meth Water down the tubing & pressured up to 6600 psi, to perform a ROPE (Really Overpressured Perforation Extension) Treatment, then shot the initial perforations at: 9170 - 9190' MD (Z1) POOH w/perforating gun. Rigged down. 3/25/94: MIRU & PT equipment to 10000 psi. mesh proppant, through the open perforations (listed above). Pumped: a) b) Resumed c) d) Ref. Log: AWS Z-Densilog 3/1/94. Pumped a Hydraulic Fracture Treatment, using 20/40 250 bbls Pre Pad Gel @ 20 - 30 bpm, followed by Shutdown. ISIP @ 1920. pumping Data Frac: 110 bbls 30# Crosslinked Gel @ 30 bpm, followed by 32 bbls 30# Crosslinked Gel @ 5 bpm, followed by e) 135 bbls 20# Flush @ 30 bpm, followed by f) Shutdown. ISIP @ 1940. Resumed pumping Fracture Treatment: g) 72 bbls Crosslinked Pad @ 30 bpm, followed by h) 293 bbls Crosslinked Slurry wi/proppant stages @ 1 - 8 ppg, followed by i) 132 bbls Flush, followed by j) Shutdown. Placed a total of 44,000 lbs of proppant into the formation. Rigged down. 3/26/94: RIH w/CT & jetted Crude to perform a proppant fill cleanout to 9320' MD. 3/27/94: RIH & tagged bottom fill at 9284' MD. RECEIVED JUL 1 8 1994 Alaska Oil & Gas Cons. Commission Anchorage Placed the well on initial production w/gaslift & obtained a valid production test. ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location' P.O. Box 100360, ~orage, AK May 24, 1994 Transmittal #: ARCO open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 94041 Distribution 99510,~ ~b' Well Number Log Date i Tape Type (M-D-Y) i Run, Footage 01-09A 03-17-94 iDLL/CN/GR/AC/ [ 11786- J'/. "- GR ! 12637 5~ 03-32A 05-01-94 i AC/GR& DEL/ON/~ !v/' GR i9200'9654 4-5A ' 05-03-94 i AC/GR & DLL/CN/ Iv'. 4CAL/GR 9- 03-06-94 D~L/AC/CN/G R 2,01 34APH 03-01-94 ¢DLL/ZDL/CN/GR 1-04A 11-35 5-34 18-23A i8250- 10292 i 9120- Contractor Atlas Atlas Atlas Atlas 11658 8410-9341 Atlas 5-19-94 ¢' ZDL/CN 8670-9471 Atlas 1-36 05-08-94 /DIFL/ZDL/CN/GR !9300-9969 Atlas · 12-13A 03-31-94 .D..LL/AC/CN/GR i 8607- Atlas 10380 5-09A 03-30-93 v" MWD/GR i 1, 9971- Sch i 8767 05-16-94 ,/DEIJZDL/ON/GR i 10560-11282 Sch 03-06-93 Sch .1, 9635- 7999 ',~, MWD/GR Number of Records: 11 John E. DeGrey Distribution: Bob Ocanas Phillips BPX Exxon ~ sta'te :of'Al'a~'~'k~.' Please acknow~dge receipt by signing and returning a copy of transmittal. By: ..--~ ,~,~ ,~ Date: D ~"*' ~ ~ ~i? ~ P~ Alaska Oil & Gas Cons. Commission Anchorage ARCO AlaaKa, Inc. Is a Subsidiary of Atten~]cRIcl'ffleldCompany ARCO Alaska, Inc. P.O. Box 100360, Date: Subject: From/Location: Telephone: To/Location: Mar 18, 1994 Transmittal #: 94033 Distribution orage, AK j Well ILog Datei Tool Type iRun, Scale Contractor . Number (M-D-Y) ; ~/~ 9-i 03-06-941 ~ CNL/GR i 1,2"&5" Atlas 34APH ~ /* I 9- I 03-06-94!j SSTVD ! 1, Atlas 34APH . 1 "&2"&5" '~,,~* ] 9-34APH I03'06'94 '/' BHCA/GR l 1' 2"&5"i Atlas 9- 03-06-94 ./ DLL/GR/SP 1, 2"&5" Atlas 34APH /~ 11-04AI 03-01-941¢BoreholeProf i 1,5" Atlas _,~'-' ! 11-04A 03-01-94 v- SSTVD 1, 2"&5" Atlas t,,. I 11-04A I 03-01-94 1,," CNL/GR ! 1, 2"&5" Atlas 'x,, I 11-04AI 03-01-94 iv' DLL/GR/SP I 1, 2."&5" Atlas Densiio?/CNL/G R i ~ * Well 9-34APH is the correct well name. Number of Records: 9 /'John E. DeGrey ~"-- Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State 'of AlaSka... Mobil. D & M PB Well Files P1 Files Please acknowled/ge r.ecei~pt by signing and returning a copy of transmittal. By:.~ ~_~ _ _ Date: ARCO Ala~k~ Inc, Is a Sub~Bary of At~anl~cRlchfleJdCompany ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location: P.O. Box 100360, A jorage, AK Mar 18, 1994 Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 94032 Distribution 99510,~ ~, q~-do Number of Records: 7 Well Number 4-43 4-44 11-4A 11-24A 13-20 14-20 17-16 (M-D-Y) , 03-10-94 ~ . USIT- ~ment/Oorrosio i Cement/Corrosio i03-10-94i F USiT- Cement/Corrosio Cement/Corrosio I 03'12'94 i 'Inflatable Bddge 03-11-94 1¢,' TDTP 03-10-94 I/ Perf record Run, Scale I 5" Contractor Sch Sch 1 5" Sch I 5" Sch 1 5" 1 5" Sch Sch Sch Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ~_~[a:t e:d.~_A I~-~/~s k_~? Mobil Please acknowledge receipt by signing and retuming a copy of transmittal. By: ~,~ t~~/% Date: ARCO Alasi(l, Inc.. I$ a Subsidiary of AUantlcR~chfleldComl:amy STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~MMISSION Wl=l ! COMP! r=TION OR RI=COMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SLISPEI~E)ED [] ,ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 0 ~'~ l i'~ i it"~'---I '~ L 94-023 3. Address 1 \ i ~,~ ~ 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 s0- 029-20480-01 4. Location of well at sur/ace ?.~.~..._~.. ...... 9. Unil or Lease Name ..... · .... .~ .... ~- !'i,._~;~ 3' Prudhoe Bay Unit 604'SNL, 8'EWL, SEC. 34, T11N, R15Ei! !~.j,~ ~ . - .... ;~ . lO. Well Number At Top Producing Interval E ~~..~i ~ J~- - 11-4A 11. Field and Pool At Total Depth i_~,,~..,. , ! ' Prudhoe Bay Field/Prudhoe Bay Pool 1592' SNL, 962' WEL, SEC. 33, T11N, R15E" ' ........ -;-~ 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 54.26' ! ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Suep. or Aband. 115. Water Depth, if offshore 116. No. of Completions 2/25/94 3/1/94 3/22/94J N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set ~21. Thickness of Permafrost 9355'MD/9084' TVD 9311 'MD/9040' TVD YES [] NO []! 2231' feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run DLL/CNL/ZDL/GR/SP/Cal/MWD 23. CASING, LINER AND CEMENTING RECORD SE'FrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING I=IECOFID AMOUNT PULLED 20" 94~ H-40 Surface 110' 32" 343 sx PF 13-3/8" 72# N-80 Surface 2710' 17-1/2" 2500 sx Fondu/400 sx PF 9-5/8" 47# L-aO/SOO-gS Surface 7786' 12-1/4" 500 sx "G"/300 sx PF "C" 7" 29# N-8o/13CR80 7614' 9353' 8-1/2" 339 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 (MDI Gun Diameter 2-172" 4 spf 5-1/2" x 4-1/2" 8599' 8540' MD TVD (Subsea) 9170'-9190' 8846'-8865' 13CR80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production JMethed of Operation (Flowing, gas lift, etc.) 4/4/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OlL-BBL GAS-MCF WATER-BBL CHOKE,SIZE. IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED DIL-BBL GASWICF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED APR 1 ,~ 1994 i~..i~$~,a, Oil & Gas C;ons. OornmJssJor~ Anchorage Form 10-407 Submit in duplicale Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS ~ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GeR, and time of each phase. Subsea Shublik 8677' 8359' Top Sadlerochit 8720' 8400' Zone 3 8874' 8552' Base Sadlerochit 9195' 8871' RECEIVED 1 1994 ~.lask~ ell & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -~ Title Drill[ncl Encfineer Suoervisor Dale ,, / 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 BP/AAI SHARED SERVICE DAILY OPERATIONL PAGE: 1 WELL: DSll-04A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/21/94 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 02/22/94 ( 1) TD: 9275 PB: 9068 02/23/94 (2) TD: 9275 PB: 9068 02/24/94 ( 3) TD: 9275 PB: 9068 TESTING BOPE MW: 8.5 Seawater MOVE RIG F/DSll-24A T/DSll-04A. DO MISC. WELDING IN TRIP TANK AND ON STEERING SYSTEM WHILE RIG IS AWAY FROM WELLS. SPOT RIG OVER WELL. LEVEL AND SHIM. SPOT SEAWATER TANKS AND TAKE ON SEAWATER. CIRC OUT DIESEL AND CIRC WELL. SPLIT TREE DUE TO ACTUATOR VALVE STUCK PARTIALLLY CLOSED. INSTALL BPV. REMOVE ADAPTOR FLANGE AND MASTER VALVE. NU BOPE. MU LANDING JT. INTO HNGR. TO TEST AGAINST. TEST BOPE. TEST BOPE MW: 8.5 Seawater RU TO TEST BOPE LEAK IN BPV. CHANGE RAM CONFIGURATION TO INSURE BOP TEST. RU LUBRICATOR AND PULL TEST DART AND BPV W/DIFFICULTY. PU SPEAR, RELEASE LOCK DOWN SCREWS, DISCONNECT CONTROL LINES TO HANGER. SPEAR TBG HANGER AND PULL TO FLOOR. LAY DOWN SPEAR AND HANGER. LD 7" AND 5.5" TBG. REPAIR 8-5/8" TBG TONGS. RD TBG EQUIPMENT AND TEST BOPE. POOH W/ SECTION MILL MW: 9.9 KC1 TEST BOP'S. PU SECTION MILL MASTER. RIH PU 100 JTS DP. TAG TOP OF STUB AT 8094 DPM. DISPLACE SEAWATER WITH MILL MUD. SPOTTED 10 PPG PILL ON BTTM. POOH TO 7776 AND PU KELLY. STARTED CUT AT 7786 DPM. LOST RIG POWER TWICE. FLUSH FLOWLINE RESTART MILLING. LITTLE PROGRESS BECAUSE SHALE SHAKER MOTOR WENT OUT. REPLACED MOTOR AND RECIPROCATED PIPE WHILE WAITING. MILLED TO 7831. CBU POOH W/SECTION MILL. RECEIVED /~PR '1 3 1994 A~.aska Oil & Gas Cons. Commissio~ Anchorage WELL · DSll-04A OPERATION: RIG : DOYON 16 PAGE: 2 02/25/94 (4) TD: 7786 PB: 7786 02/26/94 (5) TD: 8015' ( 0) 02/27/94 ( 6) TD: 8445' ( 430) 02/28/94 ( 7) TD: 8891' ( 446) 03/01/94 (8) TD: 9205' ( 314) WASHING DN TO TOC MW: 9.9 KC1 POOH LD 6.5" DP AND SECTION MILL. WINDOW IS F/7786 TO 7831. PU 3.94' LONG SLOTTED CMT STINGER AND RIH. PU 9 JTS DP WHILE RIH. HOLE OK. RIH TO 7931 BREAK CIRC. MIX CLASS G AND TESTED LINES. DISPLACED CMT AT 78 SPM AT 600PSI. POOH 12 STNDS. PERFORMED SQUEEZE. FINAL PRESSURE WAS 2000PSI W/5.6 BBLS PUMPED. NEW EST TOC = 7574'. WAITED ON CMT WHILE SLOWLY BLEEDING OFF PRESSURE. CBU. POOH LD 36 JTS DP. LD STINGER AND PULL WEAR BUSHING. SET TEST PLUG, OPEN BOP DOORS AND CLEAN OUT METAL CUTTINGS. SET WEAR BUSHING. PU DIRECTIONAL BHA RIH TO 7349. PU KELLY. BREAK CIRCULATION AND WASH DOWN TO TOC. DRILLING MW: 9.8 VIS: 40 TAGGED TOC AT 7567, DRILLED CMT TO 7705 W/15K WOB & 90 SPM AT 2100 PSI AND 40 RPM. ROP VARIED 150 TO 200 FPH. CBU. WOC. DRILLED TO 7767. ROP DROPPED TO 100 TO 150 FPH. CBU. DRILL CMT TO 7782. TOP OF WINDOW AT 7786, K/O POINT AT 7791. DRILLLED TO 7841. CBU. DUMP MILLING MUD FROM PITS AND CLEAN UP. TAKE ON KCL AND DISPLACE WELL. DRILL AND SURVEY TO 8015. POOH MW:10.0 VIS: 40 DRILLING TO 8046 - DRILLED 5' SLID 25'. DRILLED TO 8140. TORQUE BECAME ERATIC. CBU. ST 5 STNDS. MAKE CONNECTION AND SURVEY. DRILL TO 8445. LOST 500 PSI IN BTTM PRESSURE. CIRC AND MIX SLUG. POOH. DRILLING MW: 9.7 VIS: 40 POOH CHANGE BHA AND LD MOTOR AND MWD. RIH TO JARS TO CIRC AND CHECK FOR LEAKS. BIT PLUGGED. POOH. CLEAN BIT. SLIP AND CUT LINE. RIH, FILL DP AT 4100 AND 7780. OPEN HOLE IS SMOOTH. DRILLING F/8445 T/8891. HOLE IS ACTING GOOD ON CONNECTIONS. DRILLING MW: 9.8 VIS: 40 DRILLED TO 9075. BIT SLOWED TO 6 FPH. ART=9.6HRS. CBU. POOH OK. CHANGED BIT. HELD SAFETY MTGL RIH. DRILLING TO 9205. RECEIVED AI: f '1 3 1994 Gas Cons, Commission Anchorage WELL : DSll-04A OPERATION: RIG : DOYON 16 PAGE: 3 03/02/94 (9) TD: 9355' ( 150) 03/03/94 (10) TD: 9355 PB: 9312 03/04/94 (11) TD: 9355 PB: 9311 03/05/94 (12) TD: 9355 PB: 9311 PREPARE TO RUN 7" LINER MW: 9.8 VIS: 43 DRILLING TO 9355 TD. CBU. SHORT TRIP 17 STNDS, HOLE OK. CIRC HOLE CLEAN. DROP MULTI-SHOTS AND RABBIT WITH 100' OF .092 WIRE. POOH TAKING SURVEYS TO SHOE. POOH SLM. RETRIEVE MS. LD BTTM STABS AND PDC. HELD SAFETY MTG. RU ATLAS WL. RAN DLL/CN/ZDL/GR/SP/CAL F/9354 TD. TO 8444. HOLE GOOD. POOH RD ATLAS/ RU WEATHERFORD AND PU 7" LINER. PU 4.75" DC'S MW: 9.8 KC1 RAN 7" LINER/HANGER/PACKER/TIEBACK SLEEVE ASSY. TOTAL LINER LENGTH WAS 1739.16'. CIRC. AND RD WEATHERFORD. RIH W/LINER ON DP TO SHOE. CBU. RUN TO TD 9355. HOLE GOOD. CBU. ADDED DEFOAMER AND CIRC. DISPLACED RIG PUMP WITH 1622 STKS. BUMP PLUG W/2500 PSI. PRESSURE UP TO 3300PSI TO SET HANGER. TOL AT 7614. PRESSURE UP TO 4500 TO SET LINER TOP PACKER. CIP AT 19:40 HRS. ON 3/2/94.REV. OUT RECOVER SPACER, KCL WATER AND 6 BBLS OF CMT. STOP TWICE TO TRANSFER FLUIDS TO SLOP TANK. POOH LD DP AND HANGER. LD 6-1/2" DC'S AND HWDP. RU AND PU 4.75" DC'S. AOGCC REP BOBBY FOSTER WAIVED BOP TEST THAT WAS DUE BECAUSE OF RUNNING LINER. RUNNING PROD. TBG. MW: 8.4 Seawater PU BHA AND 42 JTS. 3.5" DP. TAGGED CMT AT 9237. C/O CMT TO LC AT 9311' (PBTD). CLEAN PITS AND DISPLACE W/WATER. TEST CSG AT 3500PSI FOR 30 MIN. POOH. LD DP. PULL WEAR BUSHING. RU WEATHERFORD AND HOLD SAFETY MTG. PU AND RUN 4.5 12.6#, 13CR80 FOX TBG. 80 JOINTS RUN BY 6:00 HRS. RELEASED RIG. MW: 8.4 Seawater RUN TBG TO SSSV LN. RU OTIS AND CONTROL LINE SPOOLS. MU LINES TO SSSV LN AND TEST T/5000PSI FOR 15 MIN. MU TBG HANGER. RILDS. ND BOP'S NU 5-1/8" X 7-1/16" 5M TREE. TEST TO 5000PSI. TEST UPPER AND LOWER PACKOFF TO 5000PSI, BLED TO 4850 IN 10 MIN. OK'D W/SHOEMAKE. TEST CONTROL LINE STINGERS TO 5000PSI. RU BPV LUB. AND PULL BPV. RESSURE UP TO 4000PSI AND SET BAKER SABL 3 PACKER. HELD TEST FOR 30 MIN. BLED OFF 150 PSI IN 30 MIN. SLIGHT LEAK F/TBG TO BACKSIDE. RETESTED AT 4000, HELD FOR 15 MIN. STILL LEAKING. RE-TEST W/ 3500 BACKSIDE AND 1500 ON TBG. BLED OFF 100PSI IN 30 MIN. RE-TESTED. SAME RESULTS. DISPLACE W/142 BBLS OF DIESEL. U-TBED.SET BPV. PUMP OUT CELLAR AND PITS. SECURE WELL. RELEASE RIG AT 06:00 HRS. 3/5/94 SIGNATURE: (drilling superintendent) DATE: RECEIVED API 1 1994 Aiaska OJi & Gas Corls. Commission Ancl]orage OR GINAL NO, ***..'.~**~**** SURVEY PRO(RAM *********** DO~P~ PRUDHOE BAY I)RLG ~LL NA~ DS l l-04A LOCATION I DRILLSI1'E i1 IJ~_CATION 2 I~-iOE [~Yt Al< MAGNETIC DECLINATION 30°05 DATE: ~-PEB-94 6~LL NUMBER 0 WELL HEAD LOCATION: LAT(N/-S) 0,00 AZII'tLrlI-i FR~)M ROTARY ?~LE TO TARGET IS TIE IN POINT(TIP) : MEASURED DEPTH TRUE VF~ DEF%H INCLINATION AZI~I.rI'H LATIllJI)E(N/-S) DD,'~I'UR~(E/-W) 7535,00 13,34 2~,43 -1018,00 DEF'(E1-W) 0,00 157.98 RECEIVED APt-"( '1 5 199~- Gas Cons. Commission Anchorage ME.A~ INTEIUJAL Ui~-TICAL I)P.F~H ft ft ft 7786.00 0.0 753~,00 7925o6~ 13~,7 7671.82 79~7,09 31,4 7702.69 79~.~,~ 3I, 5 7733.67 ~20.45 31,9 7765,00 ************* ANADRILL *****ww**ww*** ~JRVET C~TIONS ****** MIHIMU~ CURVA~E ~?HOD TAR(;E? STATIDN AZIMUTH S~CTIDN IHCU~, ft deg deg 332.15; 13.34 235.43 345,76 10.74 197,15 350,51 10,28 185,65 35~.83 10,47 165.72 361.71 10,86 I55,77 I.~TITU~E D~F'ARTU~E DISPLACL~qENI at N/-S EY-W ft ft ft -770,(X> -lO1B,O0 1276.41 -791,61 -1035,14 1303.13 -797,2~ -1036,28 1307,44 -802,76 -1035,85 1310,~ -~8o31 -1033.90 1312,37 AZIMLr~H deg 232,90 232 232,43 232,22 231,98 DLS d~/ lOOft 0,00 5,88 6,82 11,37 5,89 8051.29 30.8 77f5.32 6077,73 26,4 7821,3! 8112,9 34,8 7855,56 8205,81 93,3 7947,:35 8235,93 30,1 7977,02 8266.45 30,5: 8007.09 8297.8? 31.4 8038.06 8386.3~ 88,5; 8125.22 367,39 10.3~ 153,~ -813,46 -1031,48 1313,65 372,20 10,60 lb'5,96 -817.62 -1029,44 1314.75 378,50 10o28 154.71 -823.56 -1026.81 1316,27 3?4,90 10.00 154.94 -838,42 -1019,82 1320,22 400,10 9.93 156.06 -843,16 -1017,66 1321,b-7 405,34 9,86 155,05 410,76 9.99 156,09 -852,87 426,0? 9.98 1~,73 -8/6,93 231,74 231,54 231,27 230.58 230.3S 1,8~ 1.66 1,13 0,30 0,69 -1015,49 1322,~ 230,14 0,60 -1013.2~ 1324,41 229,91 0,70 -1007,11 1326.84 229,28 0,12 P~£ ~, COP~At,IY PR~HOE BAY DRLG W~LL NAKE DS lI-04A LOCATION I I)RILI, SITE 11 LOCATi~~ ~ ~HO~ D.~Y~ A~ ~O~?IC DECLINATION 30,05 ~TE: 27-1:I~-94 ~ NU~ER W~LL READ LOCATIOn: LAT(N/-9) 0.00 AZIMUTH FRO~ RO?ARY TABLE l'O TAR6ET IS TIE IN POINT{TIP) ~ DEPTH ~,~UE VERT DEPTH IHCLINATION AZIffJTH LATITUD£(N/-$) DEPAR~E(£/-W) ZZ86.00 7535.00 13.34 235,43 -ZZO,00 DEP(~/-W) O,(X) MF. Ao~ INTES~L VL~'ICAL D~TH D~TH fl: ft: ft 7786.00 0,0 7535,00 7925°6? 139,7 7671,82 8020,45 94,8 7765+04 8205,81 ?3°3 7947,37 TARGET ~ATION AZI~dTH SEC?I~ INCLN, dq 345,76 30,74 t97,15 to, ~8,42 10,28 154.71 ANADRIL~ ****~*~*~ SUE~Y CALCULATIONS MINIML~ CUE~ATL~ M~ll~OD ****** LATITUDE ])EPt~;TUr~ DISPLACEI~T aT AZIMUII-! ~-S £/-W f: ft ft d~ -770,00 -1018,00 1276,41 232,90 -7B1,61 -1035,14 1303.13 23~.57 -808,21 -1034,08 1312,45 231,99 -823,5'5 -1027.01 1316.42 231,27 -838.41 -1020,02 1320,37 230,58 dec/ 0,00 8,01 0.30 8~7,89 8038.06 8i25.~ 410,78 9,~ 15~,0~ -852,96 -1013,37 426,12 9,78 1~,73 -~7,.01 -1007,26 1324,58 22%91 0,21 1329.01 227,28 0.12 PRUDHOE BAY DRILLING PBU/ll-4A 500292048001 NORTH SLOPE COMPUTATION DATE: 3/ 8/94 SPeRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-40022 KELLY BUSHING ELEV. = 53.60 OPERATOR: ARCO ALASKA INC PAGE FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7800 7549.00 7495.40 13 21 S 55.43 W .00 771.67S 1019.63W 7883 7630.16 7576.56 10 46 S 55.21 W 3.12 781.54S 1033.90W 7975 7720.82 7667.22 10 21 S .52 E 10.69 794.74S 1040.90W 8068 7812.29 7758.69 10 51 S 26.08 E 5.05 810.97S 1036.97W 8160 7902.74 7849.14 10 8 S 27.27 E .82 825.96S 1029.45W 333.09 336.89 346.50 363.03 379.74 8252 7993.34 7939.74 9 54 S 24.24 E .63 840.37S 1022.48W 8345 8084.96 8031.36 9 52 S 23.62 E .12 854.97S 1016.01W 8438 8176.59 8122.99 9 49 S 21.31 E .43 869.66S 1009.93W 8530 8267.27 8213.67 9 34 S 19.92 E .36 884.17S 1004.47W 8621 8357.07 8303.47 9 1 S 18.13 E .69 898.08S 999.67W 395.71 411.67 427.57 443.07 457.76 8715 8449.94 8396.34 8 44 S 18.36 E .30 911.87S 995.12W 8809 8542.89 8489.29 8 23 S 18.91 E .38 925.14S 990.65W 8900 8632.95 8579.35 8 5 S 18.78 E .33 937.49S 986.43W 8993 8725.06 8671.46 7 47 S 17.69 E .36 949.70S 982.41W 9086 8817.23 8763.63 7 33 S 17.13 E .27 961.55S 978.69W 472.25 486.23 499.26 512.09 524.46 9179 8909.46 8855.87 7 7 S' 17.59 E .47 972.89S 975.15W 9272 9001.78 8948.18 6 46 S 17.77 E .38 983.60S 971.73W 9315 9044.49 8990.89 6 30 S 16.94 E .65 988.35S 970.25W 536.30 547.52 552.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1385.00 FEET AT SOUTH 44 DEG. 28 MIN. WEST AT MD = 9315 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 157.98 DEG. i,...~.;s~,,~ Oil & Gas Cons. 6ommission Anchorage SPeRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PSU/ll-4a 500292048001 NORTH SLOPE COMPUTATION DATE: 3/ 8/94 DATE OF SURVEY: 030194 JOB NUMBER: AK-Ei-40022 KELLY BUSHING ELEV. = 53.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7800 7549.00 7495.40 8800 8533.99 8480.39 9315 9044.49 8990.89 771.67 S 1019.63 W 251.00 923.90 S 991.07 W 266.01 15.01 988.35 S 970.25 W 270.51 4.50 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/ll-4A 500292048001 NORTH SLOPE COMPUTATION DATE: 3/ 8/94 INTERPOLATED VALUES FOR EVEN 100 DATE OF SURVEY: 030194 JOB NUMBER: AK-Ei-40022 KELLY BUSHING ELEV. = 53.60 FT. OPERATOR: ARCO ALASKA INC FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7800 7549.00 7495.40 771.67 S 1019.63 W 251.00 7804 7553.60 7500.00 772.37 S 1020.65 W 251.16 .16 7906 7653.60 7600.00 784.34 S 1037.00 W 253.21 2.05 8008 7753.60 7700.00 800.66 S 1040.31 W 254.71 1.50 8110 7853.60 7800.00 818.05 S 1033.49 W 256.46 1.75 8211 7953.60 7900.00 834.05 S 1025.36 W 258.06 1.60 8313 8053.60 8000.00 849.97 S 1018.19 W 259.57 1.51 8414 8153.60 8100.00 865.95 S 1011.38 W 261.07 1.50 8516 8253.60 8200.00 882.00 S 1005.26 W 262.54 1.47 8617 8353.60 8300.00 897.55 S 999.84 W 263.88 1.35 8718 8453.60 8400.00 912.40 S 994.95 W 265.10 1.21 8819 8553.60 8500.00 926.63 S 990.14 W 266.22 1.12 8920 8653.60 8600.00 940.27 S 985.49 W 267.25 1.03 9021 8753.60 8700.00 953.42 S 981.22 W 268.21 .95 9122 8853.60 8800.00 966.15 S 977.27 W 269.09 .88 9223 8953.60 8900.00 978.13 S 973.49 W 269.88 .79 9315 9044.49 8990.89 988.35 S 970.25 W 270.51 .63 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ~ u LF~] U ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 17, 1994 Russell B. Strickland Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit ll-04A ARCO Alaska, Inc. Permit No. 94-23 Sur. Loc. 604'SNL, 8'EWL, Sec. 34, TllN, R15E, UM Btmnhole Loc. 3680'NSL, 969'WEL, Sec. 33, TllN, R15E, UM Dear Mr. Strickland: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~ In Chairman BY O~ER OF TM COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll;'l.lb. Type of w~'l.'~'x'l::;Iorat~3~';I-I Stratigraphic Testl-I Development oilr~l Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 54' fe et Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28325 4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 20 ^AC 25.025) 604' SNL, 8' EWL, SEC. 34, T11N, R15E Prudhoe Ba~, Unit At top of productive interval 8. Well number Number 3708' NSL, 980' WEL, SEC. 33, T11N, R15E 11-04A U-630610 At total depth 9. Approximate spud date Amount 3680' NSL, 969' WEL, SEC. 33, T11N, R15E 2/17/94 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dTVD) property line ADL 28328-3680' feet No close approach feet 2560 9343' MD/9072' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~ 20 AAC 25.035 (e)(2)) Kickoff depth 7800 feet Maximum hole angle ~3.4 0 Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29~ 13CR8O NSCC 1275' 7650' 7403' 9343' 9072' 231 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9275 feet Plugs (measured) true vertical 9012 feet Effective depth' measured 9226 feet Junk (measured) true vertical 8963 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 82' 20" 343 sx'PF 110' 110' Surface 2689' 13-3/8" 2500 sx Fondu & 2710' 2710' Intermediate 400 sx PF Production 8510' 9-5/8" 5oosx'G"/3OOsxPF"C' 8531' 8270' Liner 1065' 7" 306 sx "G" 9270' 9006' Perforation depth: measured 8940'-8966', 9006'-9024' true vertical 8678'-8704', 8744'-8762' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program I T] Drilling fluid program [] Time vs depth pict [] Refraction analysis• Seabed report• 20 AAC 25.050 requirements[] 21.' herebyDe~i:y.. ~t tjX, ,o~ correct to the best of my knowledge Date,~, Signed ~'"" , Title Drillin~tEn~lineerSupervisor ~ ~L Commission Use Only Permit Number IAPI number IApp~v_a~ date ISee cover letter ~'d- O:z% 150- 02fi- 2. r.)"/,~O-OI, ,,.-~ __"?---.F"~/ Ifor other requirements Conditions of approval Samples required [] Yes [~'NO Mud log required []Yes [211'4o Hydrogen sulfide measures [] Yes ~ No Directional survey required ¢~ Yes [] No Required working pressure for DOPE []2M; D3M; J~5M; I'-11 OM; D15M' Other: Original Signed By by order of Approved by David W, Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate [Well Name: [DS ll-04A Redrill Plan Summary [ Type of Redrili (producer or injector): [ Producer ISurface Location: Target Location: Bottom Hole Location: 604 FNL 8 FEL S34 T11N R15E UM 3708 FSL 980 FEL S33 T11N R15E UM 3680 FSL 969 FEL S33 T11N R15E UM I AFENumber: I 4J8019 I I Estimated Start Date: 102/17/94 [MD: 19343' I I Rig: ! Doyon #16 I I Operating days to complete: I 13 ITVD: 19°72 I IKBE: Well Design (conventional, slimhole, etc.): 154' I conventional Objective: Sidetrack well. Several unsuccesful squeeze attempts to shut off gas has made this an attractive candidate for a sidetrack. Sidetrack well will provide wellbore to recover reserves targeted to the original DS 11-04 well. Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. I Special design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 l0 0 5 tO tO tO tO tO tO tO tO tO TD' 10.0 18 30 15 30 5 0 8 Directional: I KOP: 17800 MD IMaximum Hole Angle: Close Approach Well: 13.4 degrees NONE The above listed wells will be secured during the close approach. RECEIVED F~3 -9 1994 Abuka oill& Gas Cons. Commission Anchorage Redrill Plan Summary Page 1 Casing/Tubin{ Pro~ ram: Wt/Ft Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb§ O.D. MD/TVD MD/TVD 8.5" 7" 29# 13CR80 NSCC 1275 7650/7403 9343/9072 Cement Calculations: l Liner Size: I Basis:1 20qo open hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above linei' with DP. Total Cement Volume: 231 sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equiPment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVED FEe9 -9 1994 Alaska Oil & (]as Cons. Commission AnChorage Redrill Plan Summary Page 2 DS 11-04A SIDETRACK INFORMATION Objective: The primary objective of this sidetrack is to return the Lower Romeo to Iow GOR production. Open hole logs will allow for selective perforating in the Victor, Tango, Upper Romeo, and lower Romeo. Three squeezes since 1989 have been unsuccessful at maintaining sustained gas shut off results. The proposed target will place the bottom hole location approximately 250' south of the present wellbore. The expected initial post sidetrack production from the Lower Romeo is approximately 1300 BOPD with 50% WC and 1500 GOR. Scope: 1) P & A existing well per state regulations. 2) Pull existing 7"x 5-1/2" tubing. 3) Mill window in 9 5/8" casing. 4) Set kickoff plug and drill 8 1/2" hole to TD. 5) Run OH logs, GR/DLL/BHCS/CNL. 6) Cement 7" chrome liner in place. 7) Run 5-1/2" x 4-1/2" chrome tubing. Timing' Doyon #16 will be making a well to well move from well DS 11-24A to DS 11-04A on or about February 17 1994. RECEIVED FEB - 9 1994 Aiaska 0il & Gas Cons. Commission Anchorage Redrill Plan Summary Page 3 ! PRdO'HO¢ f AY OR'I_LING ( ROUP ~arker Ident~f~ca[]or, ~,0 BKB SCCTN~NCL~. (p ) ,~ ~,o o~ ~/,oo cu,v~ ~o;9,~s,~, ~.o~ VERTICAL SECTZON VIEW O) 7~ LINE~ SHOE ~B4B ~072 ~ g.02 .... E) T~ ~4~ 907~ 5~5 9.0~ Section ~l ~58,~ TVO Scale.' ~ inch = BO0 feet .... Oep Scale.' ] ~nc~ = ~00 teet ~ " i ' , ..... . ,,: ....... ' )0 .... , ~ , ! ' ' ~ : - ~ ~ - I/-- ' .-- ~ I ' , : ,' -~ ~ -¢~ .......... , ..... 4 .... ~_~ ......... L ..... ' ....... 2. ' I -~4~ - ~ ~,- - _ -~ ...... ~ ........~ .... ~ .... ~ _ _ _ ~:,~ 7 ~- -~ ...... T - - -, ........~ - ;- .......... "r ~ I r ~ ' ' ~="?'~'~'-~ ...... ~ - ' ....... * - ~ .... ~ Alaska 0il & 6a~ Cons, 6~missig- -300 -150 O~ 150 300 450 600 750 ~00 t050 ~200 1350 ~500 ~650 1800 : , Sect ion Oeoerturo . .. !.. ~ : - . . . PRUDHOF--'BAY DRi Marker IOent~ficotion A) TIE-IN B) END OF 6/i00 CURVE C) TA;~GET D) 7" LINER SHOE E) TD MD N/$ 7800 77~ 10~9 8039 805 9154 987 9343 934 959 --LING GROUP ...... · .... imm ,, ___ os -04A PLAN VZEN -- CLOSURE ' 1381 feet at AZimuth 223,96 DECLINATION.' 30.000 E SCALE ' 1 inch : 200 feet DRAWN · 0!/27/94 Anaffr] 11 5cflJumberger i ,,i fill BO0 -900 IOOC 100 1300 .~3~0 200 i i00 ! f000 900 80O 700 600 500 400 300 200 ]00 0 O0 ' <- WEST' EAST-> -- mi -- - . imm I mi il . i (A~Or~i]'-~c)g~ ~.~O~APl B'.,52 ~OiO~ FW ~) ......... J ' ~ 'TOTAL P. 05 _~, rATE OF ALASKA ALASKA ( ,ND GAS CONSERVATION COMMISSION APPLICATIO FOR SUNDRY APPROV 'Ls 1. Type of Request: Abandon x Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing.__ Repair well__ Plugging x Time extension__ Stimulate__ Change approved program __ Pull tubing __ Variance__ Perforate__ Other x __ Plugback for redrlll 2. Name of Operator ARCO Alaska, inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at sudace 604'$NL, 8' EWL, SEC. 34, T11N, R15E At top of productive interval 1410' SNL, 1135' WEL, SEC. 33, T11N, R15E At effective depth At total depth 1403' SNL, 1177' WEL, SEC. 33, T11N, R15E 12. Present well condition summary Total depth: measured true vertical measured true vertical Effective depth: Casing Length Size Structural Conductor 82' 20" Surface 2689' 13-3/8" Intermediate 8510' 9-5/8" 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED FEB - 4 1994 Alaska 0il & 8as Cons, Commission ch0rage 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 11-4 9. Permit number 80-60 10. APl number 50- 029-20480 11. Field/Pool . Prudhoe Bay Field/O# Pool 9275 feet Plugs (measured) 9012 feet 9226 feet Junk (measured) 8963 feet Cemented Jeasured depth 343 s~F 110' 2500 sx FondLV400 sx PF 2710' 500 sx 'G'/300 sx PF "C" 8531' True vertical depth 110' 2710' 8270' Production Liner 1065' 7" 306 sx Class "G" 9270' 9006' Perforation depth: measured 8940'-8966', 9006'-9024' true vertical 8678'-8704', 8744'-8762' Tubing (size, grade, and measured depth) 7", 26#, PCT@ 2985'MD;5-1/2", 17#, L-80, PCT@ 8173'MD; 4-1/2", 12.6#, L-80, PCT tail @ 8882'MD Packers and SSSV (type and measured depth) Baker FAB- 1 packer @ 8828' MD;7" Otis RPB SSS V @ 2241' MD; Baker SAB pkr @8162'MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 2/1 O/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~/'(Z,,~ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~'~ BOPTest Location clearance~ Mechanical Integrity Test~ Subsequent form required 10- -~',';'/~ (Jr ginal Signed By Approved by order of the Commission ~avid W. Johnstrm Form 10-403 Rev 06/15/88 J Approva, Apptuved Copy' Returned -- Commissioner Date SUBMIT IN TRIPLICATE WELL pERMIT CHECKLIST PROGRAM: exp [] dev~ redrll [] serv [] FIELD & POOL ~ ~ ...... ' ADMINISTRATION DATE 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ ENGINEERING APPR "'GEOL'OGY 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in surf csg to next string .... Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed ......... ~----L N 23. If diverter required, is it adequate .......... .Y~N 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~6~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y N 28. 29. 17. /~ Fe;~q Work will occur without operation shutdown. Is presence of H2S gas probable ............. APPR 30.~Permit can be issued w/o hydrogen sulfide measures .... Y N ~3 I~ ~_._~.._Da~entedon potential overpressure--zo~''~' ''~'-.. Y N 32~~h~'--;ones~-- .......... y N 33. Seabed con~dl%eon~survey (i~~e) ......... Y N DATE 34.~ame/phone for weekly progress reports ........ ~ . . . Y N ~ [exploratory only] ...... ~ GEOLOGY: ' 'ENGINEERING: COMMISSION: Tm~ ~ , , Co~ments/Instructions: z HOW/jo - A:\FORMS~cheklist rev 01/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * ....... SCHLU~i~ERGER ....... * . ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. ll-04A FIELD NAM~ : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NU~IB~ : 500292048001 REFERENCE NO : 98028 * ALASKA COMPUTING CENTER * ....... SCHLUFIBERGER ....... COMPANY NAI~E : ARCO ALASKA INC. WELL NAPIE : D.S. ll-04A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUFIBER : 500292048001 REFERENCE NO : 98028 LfS Tape Verification Listing Schlumberger Alaska Computing center 21-JAN-1998 14:27 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/21 ORIGIN : FLIC REEL NAME : 98028 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. ll-04A, API# 50-029-20480-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/21 ORIGIN : FLIC TAPE NAME : 98028 CONTINUATION # : 1 PREVIOUS TAPE : COF~VlENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. ll-04A, API# 50-029-20480-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. ll-04A API NUFIBER: 500292048001 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUFIBERGER WELL SERVICES TAPE CREATION DATE: 21-JAN-98 JOB NUFiBER: 98028 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: J. JULIAN SURFACE LOCATION SECTION: 33 TOWNSHIP: 1 iN RANGE: 15E FNL: FSL: FEL : FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 54.52 DERRICK FLOOR: 54.52 GROUND LEVEL: 28. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9. 675 7831.0 47. O0 7. 000 9353.0 29. O0 5.500 2836.0 17.00 4. 500 8599.0 12.60 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) L~S Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS ~ER: DATE LOGGED: O1-MAR- 94 LOGGING COMPANY: ATLAS BASELINE DEPTH .............. 88888 0 9179 5 9174 5 9169 0 9166 0 9164 5 9164 0 9160 0 9159 5 9156.5 9152.0 9147.5 9139.0 9138.5 9135.0 9130.0 9129.5 9128.5 9124.0 9123.5 9122.0 9121.5 9112.5 9103.5 9101.0 9094.5 9091.0 9090.5 9089.0 9085.5 9085.0 9080.5 9080.0 9070.0 9069.5 9063.5 9056.5 9050.5 9047.0 9046.5 9038.0 9037.5 9028.5 9026.5 9015.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.5 88887.5 9168.5 9167.0 9164.0 9159.5 9156.0 9152.0 9147.5 9139.5 9134.0 9129.5 9127.0 9124.0 9121.5 9112.5 9103.5 9101.0 9093.5 9090.0 9088.5 9085.0 9080.5 9069.5 9063.0 9056.5 9049.5 9046.0 9036.0 9028.0 9026.5 9179.0 9174.5 9168.5 9167.0 9164.0 9159.5 9156.0 9152.0 9147.5 9139.5 9134.0 9129.5 9127.0 9124.0 9121.0 9112.0 9104.0 9101.0 9093.5 9090.5 9088.5 9085.0 9080.5 9069.5 9063.0 9056.5 9049.5 9046.0 9036.0 9028.0 9026.5 9014.5 PAGE: Lrs Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 9014 5 9012 0 9008 5 9005 5 9003 0 9000 0 8997 5 8992 0 8991 5 8984 5 8982 5 8979.0 8974.0 8962.5 8962.0 8957.0 8952.0 8947.0 8946.5 8941.5 8935.0 8928.5 8924.0 8923.5 8919.5 8909.5 8907.0 8897.5 8895.5 8895.0 8882.5 8871.5 8869.0 8865.5 8849.5 8846.5 8843.O 8837.0 8831.0 8826.5 8825.5 8825.0 8821.5 8816.0 8815.5 8812.5 8807.5 8806.5 8800.5 8796.5 8794.0 8793.5 100.0 $ 9014.5 9011.5 9011.5 9008.0 9008.0 9005.0 9005.0 9002.5 9002.5 8999.5 8999.5 8997.0 8997.0 8994.0 8994.0 8986.5 8986.5 8983.0 8983.0 8979.0 8979.0 8974.0 8974.0 8961.5 8961.5 8957.0 8957.0 8953.0 8953.0 8946.5 8946.5 8940.0 8940.0 8934.0 8934.0 8928.5 8928.5 8924.5 8924.0 8918.0 8918.0 8908.5 8908.5 8906.5 8906.5 8898.0 8898.0 8895.0 8895 0 8882 5 8882.5 8871 5 8871.5 8869 5 8869.5 8865 5 8865.5 8849 0 8849.0 8846.5 8846.5 8843.5 8843.5 8837.5 8837.5 8831.0 8831.0 8826.0 8826.0 8824.0 8824.0 8821.0 8821.0 8816.0 8816.0 8812.5 8812.5 8806.5 8806.5 8800.5 8800.5 8796.5 8796.5 8794.0 8794.0 100.5 100.0 PAGE: REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG L~S Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 DATA AQUIRED ON ARCO ALASKA'S DS ll-04A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAMMA RAY, ALSO PASS #1 NPHI AND THE BCS GAlV~A RAY, CARRYING ALL CNTG CURVES WITH THE AUPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUAIBER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~La~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9172.5 8790.5 CNTG 9183 . 5 8790.0 $ CURVE SHIFT DATA - PASS TO PASS (F1EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. · $ LIS FORMAT DATA L~S Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP EL~ CODE (HEX) DEPT FT 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNTG 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1065827 O0 000 O0 0 1 i 1 4 68 0000000000 ENRA ClTTG 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTClTTG CPS 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTClVTG CPS 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1065827 00 000 O0 0 1 1 1 4 68 0000000000 ClFEC CNTG CPS 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 CFECCl~fG CPS 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 ~R BCS GAPI 1065827 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9288.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG -999.250 LI'S Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: GR.BCS 134.982 DEPT. 8760. 000 NPHI. CNTG -999. 250 ENPH. CNTG NRAT. CNTG -999. 250 CRAT. CNTG -999. 250 ENRA. CNTG FCNT. CNTG -999 . 250 CNTC. CNTG -999. 250 CFTC. CNTG CFEC. CNTG -999. 250 GRCH. CNTG -999. 250 TENS. CNTG GR. BCS 56. 828 -999.250 CPHI. CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL. CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAlVlE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAI~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER : 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFi~ER : 2 DEPTH INC~: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9172.5 8790.0 CNTG 9182.5 8789.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: BASELINE DEPTH GRCH CNTG 88888.0 88887.5 88886.5 9180.5 9179.0 9175.0 9174.5 9173.5 9173.0 9171.5 9171.0 9168.0 9167.0 9162.5 9162.0 9161.0 9159.5 9158.0 9157.0 9157.0 9156.5 9149.5 9149.0 9148.0 9147.5 9145.5 9144.0 9142.5 9141.5 9141.5 9140.0 9138.0 9138.0 9135.5 9134.0 9130.0 9129.5 9124.5 9124.0 9122.0 9121.0 9121.0 9120.5 9119.0 9113.0 9112.0 9112.5 9112.5 9104.0 9103.5 9104.0 9102.0 9101.5 9097.5 9097.5 9092.5 9093.5 9091.0 9090.5 9090.5 9090.5 9087.0 9088.5 9087.0 9083.5 9082.0 9081.0 9080.5 9080.0 9079.5 9076.0 9075.5 9070.5 9069.5 9070.0 9069.0 9068.5 9068.0 9067.5 9067.5 9066.5 9065.0 9065.5 9064.5 9063.5 9063.0 9061.5 9061.0 9058.5 9057.5 905~.5 9057.0 9056.0 9056.5 9051 . 0 9049 . 5 9047.0 9046.0 9046.0 9044.5 9040.5 9038.0 9040.0 9039.0 9037.0 9037.5 9034.5 9032.5 9032.5 9030.5 9029.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 9027.0 9023.0 9020.0 9019.0 9015.5 9009.5 9004.5 9001.5 8999.0 8998.0 8993.5 8987.5 8984.5 8982.5 8979.0 8974.0 8973.5 8967.0 8962.0 8961.0 8957.5 8957.0 8953.0 8952.5 8949.0 8946.5 8944.0 8943.5 8939.0 8935.0 8932.5 8929.0 8927.0 8923.5 8921.5 8920.5 8918.0 8917.5 8915.0 8913.0 8911.5 8909.0 8908.5 8906.0 8901.0 8898.0 8895.5 8895.0 8885.5 8884.5 8882.5 8875.5 8874.0 8873.5 8871.5 9026.5 9019.5 9017.5 9014.5 9003.5 8999.5 8996.0 8986.5 8984.0 8979.0 8974.0 8966.5 8961.5 8957.0 8953.0 8948.5 8947.0 8943.5 8938.0 8934.0 8931.0 8926.0 8922.5 8918.0 8912.0 8908.5 8906.5 8898.0 8895.0 8884.5 8882.5 8875.5 8873.0 8871.5 9023.0 9019.0 9009.0 8998.0 8991.0 8981.0 8973.0 8961.5 8958.0 8953.0 8946.5 8942.5 8935.0 8928.5 8924.5 8920.5 8916.0 8914.0 8911.0 8909.0 8901.0 8895.0 8885.0 8874.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAIV-1998 14:27 PAGE: 8870.5 8870.0 8870.0 8870.0 8866.5 8865.5 8865.0 8865.5 8863.0 8863.5 8860.0 8859.5 8857.5 8856.0 8857.5 8852.0 8851.5 8851.5 8849.5 8849.0 8848.0 8847.5 8846.5 8846.5 8843.5 8843.5 8844.5 8842.5 8842.5 8841.0 8841.5 8839.5 8839.5 8837.0 8838.0 8836.5 8837.0 8834.5 8834.5 8834.0 8833.5 8826.0 8826.0 8825.0 8824.0 8823.5 8824.0 8822.0 8821.5 8821.5 8821.0 8816.5 8816.0 8816.0 8816.0 8812.5 8812.5 8812.0 8812.5 8810.0 8809.0 8809.5 8809.5 8799.0 8799.0 8798.0 8799.0 8797.5 8797.0 8796.5 8796.5 8792.0 8791.5 100.0 100.0 99.5 REMARJfS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIs Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUF~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~IB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CNECCNTG CPS 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CFECCNTG CPS 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1065827 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9182.500 NPHI. CNTG 25.260 ENPH. CNTG 25.950 CPHI. CNTG NRAT. CNTG 3.105 CRAT. CNTG 2.788 ENRA.CNTG 4.231 NCNT. CNTG FCNT. CNTG 816.444 CNTC. CNTG 2451.294 CFTC. CNTG 896.958 CNEC. CNTG CFEC. CNTG 754.186 GRCH. ClTTG -999.250 TENS. CNTG 3630.000 CCL. CNTG 26.624 2367.126 3190.672 0.012 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 11 DEPT. 8789.500 NPHI.CNTG 10.643 ENPH. CNTG NRAT. CNTG 1.894 CRAT. CNTG 1.806 ENRA. CNTG FCNT. CNTG 1656.720 CNTC. CNTG 3221.484 CFTC. CNTG CFEC. CNTG 1180.341 GRCH. CNTG -999.250 TENS. CNTG 15.889 CPHI.CNTG 3.040 NCNT. CNTG 1839.891 CNEC. CNTG 3510.000 CCL. CNTG 12. 716 3118. 696 3588. 714 O. 034 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFiBER: 3 DEPTH INCREFIENT: 0.5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9173.0 8791.5 CNTG 9183.5 8790.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER: 1 BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 12 88888.0 88888.0 88887.5 9179.5 9179.0 9176.5 9175 . 5 9172.5 9173.0 9170.5 9170.5 9168.5 9168.5 9165.5 9167.0 9164.0 9164.0 9163 . 5 9164.0 9160.0 9159.5 9159.5 9160.0 9153.0 9153.5 9151.5 9152.0 9148.0 9149.0 9147.5 9147.5 9145.0 9144.0 9142.0 9141.5 9137.0 9138.0 9135.0 9134.0 9131.0 9131.0 9128.0 9127.0 9123.5 9124.0 9120.5 9121.0 9119.5 9119.0 9118.5 9118.5 9111.0 9111.0 9108.0 9108.5 9103.5 9103.5 9104.0 9100.5 9101.0 9097.5 9097.0 9097.5 9093.0 9093.5 9090.0 9090.5 9087.0 9088.5 9086.0 9087.0 9081.5 9081.0 9080.5 9080.5 9079.5 9080.0 9076.5 9077.5 9073.5 9074.0 9072.5 9073.0 9069.5 9069.5 9067.5 9068.5 9065.0 9065.0 9064.0 9064.5 9060.5 9060.5 9060.0 9061.0 9056.5 9057.5 9055.5 9056.5 9047.0 9046.0 9046.0 9046.0 9045.0 9044.5 9044.0 9044.0 9043.5 9042.5 9039.5 9037.5 9039.0 9038.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 13 9037.0 9035.0 9029.5 9029.5 9029.0 9026.5 9027.0 9026.0 9026.5 9018.5 9020.5 9019.5 9014.5 9014.5 9014.0 9014.5 9002.5 9002.5 9000.5 9000.0 8996.0 8994.0 8993.0 8995.0 8990.5 8991.0 8984.5 8983.5 8984.0 8984.0 8981.0 8981.0 8978.0 8979.0 8974.5 8976.0 8973.0 8974.0 8973.0 8970.5 8970.0 8970.0 8971.5 8966.5 8966.0 8964.5 8962.5 8961.5 8961 . 5 8961.0 8960.5 8959.5 8958.0 8956.0 8957.0 8952.5 8952.5 8950.0 8948.5 8946.5 8947.0 8940.0 8942.5 8938.5 8940.5 8937.5 8937.5 8933.5 8935.0 8929.5 8928.5 8927.0 8928.5 8923.5 8924.5 8917.5 8916.0 8917.0 8917.5 8914.5 8912.0 8912.0 8911.0 8908.5 8908.5 8905.0 8905.5 8900.5 8901.0 8899.5 8900.0 8897.0 8898.0 8895.0 8895.0 8894.5 8895.0 8883.5 8884.5 8882.0 8882.0 8873.5 8874.0 8873.0 8873.5 8871.5 8871.5 8869.5 8870.0 8869.0 8870.0 8865.5 8865.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 14 8865.0 8865.5 8863.0 8863.5 8860.5 8859.5 8855.5 8855.0 8855.0 8855.0 8851.5 8851.5 8851.0 8851.0 8849.0 8849.0 8846.5 8847.0 8846.0 8846.5 8841.5 8842.5 8839.0 8840.0 8836.0 8837.5 8833.5 8834.0 8826.0 8826.0 8822.5 8824.0 8822.0 8821.5 8821.0 8821.0 8815.5 8816.0 8815.0 8816.0 8810.0 8811.0 8809.0 8809.0 8807.0 8807.0 8806.5 8807.0 8799.0 8800.5 8798.0 8798.5 8796.5 8797.0 8796.0 8796.5 8792.5 8794.0 8792.0 8792.0 100.0 101.5 100.0 REM3LRKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 Lis Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 15 TYPE REPR CODE VALUE .............................. 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAlViE SERV UNIT SERVICE API API API API FILE NUMB ND?4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CRATCNTG 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1065827 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9183.500 NPHI. CNTG 25.988 ENPH. CNTG 29.653 CPHI. CNTG NRAT. CNTG 3.097 CRAT. CNTG 2.828 ENRA.CNTG 4.625 NCNT. CNTG FCNT. CNTG 824.613 CNTC. CNTG 2370.958 CFTC. CNTG 866.685 CNEC. CNTG CFEC. CNTG 711.147 GRCH. CNTG . -999.250 TENS.CNTG 3680.000 CCL. CNTG DEPT. 8790.000 NPHI.CNTG 10.381 ENPH. CNTG 15.937 CPHI. CNTG NRAT. CNTG 1.861 CRAT. CNTG 1.785 ENRA.CNTG 3.047 NCNT. CNTG FCNT. CNTG 1670.231 ClTTC. CNTG 3192.661 CFTC. CNTG 1823.438 CNEC. CNTG CFEC. CNTG 1165.889 GRCH. CNTG -999.250 TENS. CNTG 3410.000 CCL. CNTG 26.666 2334.589 3289.139 -0.016 12.716 3271.930 3551.917 -0.044 ** END OF DATA ** LfS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFIBERS 1, 2, 3, CNTG THIS FILE CONTAINS THE ARITHmeTIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 17 TYPE REPR CODE VALUE 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP EL~4 CODE (HEX) DEPT FT 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1065827 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9182.500 NPHI. CNAV 24.279 NRAT. CNAV 3.011 CPHI.CNAV CRAT. CNAV 2.734 ENPH. CNAV 26.074 ENRA. CNAV 4.244 NCNT. CNAV FCNT. CNAV 832.150 CNTC. ClVAV 2429.104 CFTC. CNAV 894.075 CNEC. CNAV CFEC. CNAV 749. 498 GRCH. CNTG -999. 250 26.385 2406.227 3181.183 ** END OF DATA ** - L'IS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : OOiCO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER : 1 DEPTH INCREM~2~f: 0.5000 FILE SUBtLetY VF2VDOR TOOL CODE START DEPTH ........................... CNTG 9204.5 $ LOG HEADER DATA STOP DEPTH .......... 8785.0 DATE LOGGED: SOFTWARE VERSION: TIFiE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 05-0CT-97 CP 42.2 1336 05-0CT-97 9200.0 9192.0 8800.0 9184.0 1800.0 TOOL NUMBER ........... SGC-SA-27 CNC-GA-12 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 19 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 9353.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMP IN DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPI THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 10000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO Z-DENSILOG/COMPNEUTRON DATED 3/1/94 PUMPED 260 BBLS CRUDE PRIOR TO LOGGING PUMED AT 1 BPM WHILE LOGGING MADE 3 PASSES SPIKING ON EPITHERMAL FAR DETECTOR (GAS BUBBLES) FIERGED 2 FILES TO GET ONE CLEAN EPITHERMAL PASS FIELD PICK GOC AT 8926' THIS FILE CONTAINS RAW PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14 ..27 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 i 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 RCENPSi CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 RCFTPS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1065827 O0 000 O0 0 5 1 · 1 4 68 0000000000 TENS PS1 LB 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1065827 O0 000 O0 0 5 1 1 4 68 0000000000 ....................................................................................... ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 21 DEPT. 9204.500 NPHI.PS1 TNRA.PS1 2.660 RTNR.PS1 C1VEC. PS1 3005.607 RCEF. PS1 RCFT. PS1 777.665 CNTC. PS1 GR.PS1 33.906 TENS.PSI DEPT. 8785.000 NPHI.PS1 TNRA.PS1 1.906 RTNR.PS1 CNEC. PS1 3548.800 RCEF. PS1 RCFT. PS1 1541.840 CNTC. PS1 GR.PS1 28.594 TENS.PSi 22.925 ENPH. PS1 2.818 ENRA.PS1 645.286 RCEN. PS1 2246.018 CFTC.PSi 2865.000 CCL.PS1 11.888 ENPH. PS1 2.040 ENRA.PS1 1095.139 RCEN. PS1 3157.342 CFTC. PSi 3460.000 CCL.PS1 28.058 TNPH. PS1 4.458 CFEC. PS1 2778.185 RCNT.PS1 861.570 NPOR.PS1 -0.016 16.257 TNPH.PS1 3.087 CFEC. PS1 3299.661 RCNT. PS1 1706.074 NPOR.PS1 0.081 24.753 674.220 2227.025 24.753 14.058 1149.515 3163.760 13.800 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 2 DEPTH INCREMF2~f: 0.5000 FILE SUF~L~RY VENDOR TOOL CODE START DEPTH ........................... CNTG 9204.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH .......... 8784.5 05-0CT-97 CP 42.2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 22 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1336 05-0CT-97 9200.0 9192.0 8800.0 9184.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG COMPENSATED NUETRON $ TOOL NUM~ER ........... SGC-SA-27 CNC-GA-125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9353.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMP IN DEAD CRUDE 20.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPI THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELIArE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 10000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO Z-DENSILOG/COMPNEUTRON DATED 3/1/94 PUMPED 260 BBLS CRUDE PRIOR TO LOGGING PUMED AT 1 BPM WHILE LOGGING MADE 3 PASSES SPIKING ON EPITHERMAL FAR DETECTOR (GAS BUBBLES) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 23 MERGED 2 FILES TO GET ONE CLEAN EPITHERMAL PASS FIELD PICK GOC AT 8926' THIS FILE CONTAINS RAW PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 RCFTPS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 24 NAI~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) ....................................................................................... GR PS2 GAPI 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1065827 O0 000 O0 0 6 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 9204.500 NPHI.PS2 23.566 ENPH.PS2 24.952 TNPH. PS2 TNRA.PS2 2.695 RTNR.PS2 2.855 ENRA.PS2 4.120 CFEC. PS2 CNEC. PS2 3260.160 RCEF. PS2 757.270 RCEN. PS2 3013.477 RCNT. PS2 RCFT. PS2 838.913 CNTC. PS2 2458.980 CFTC. PS2 929.426 NPOR.PS2 GR.PS2 50.625 TENS.PS2 2910.000 CCL.PS2 0.012 DEPT. 8784.500 NPHI.PS2 11.310 ENPH.PS2 9.391 TNPH. PS2 TNRA.PS2 1.860 RTNR.PS2 1.923 ENRA.PS2 2.175 CFEC. PS2 CNEC. PS2 3555.333 RCEF. PS2 1076.508 RCEN. PS2 3165.247 RCNT. PS2 RCFT. PS2 1516.891 CNTC. PS2 3082.312 CFTC. PS2 1684.258 NPOR.PS2 GR.PS2 22.609 TENS.PS2 3550.000 CCL.PS2 0.073 25.327 791.225 2438.186 25.327 13.780 1634.909 3253.322 12.291 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 25 PASS NUMBER: 3 DEPTH INCREFiENT: 0.5000 FILE SUF~V~RY VENDOR TOOL CODE START DEPTH ........................... CNTG 9204.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 8782.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~A RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL ,TYPE (EPITHERMAL OR THERMAL): MATRIX: 05-0CT-97 CP 42.2 1336 05-0CT-97 9200.0 9192.0 8800.0 9184.0 1800.0 TOOL NUM~ER ........... SGC-SA-27 CNC-GA-125 9353.0 PUMP IN DEAD CRUDE 20.0 MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 26 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 10000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: TIED INTO Z-DENSILOG/COMP NEUTRON DATED 3/1/94 PUMPED 260 BBLS CRUDE PRIOR TO LOGGING PUFIF2~ AT 1 BPM WHILE LOGGING MADE 3 PASSES SPIKING ON EPITHERMAL FAR DETECTOR (GAS BUBBLES) IVlERGED 2 FILES TO GET ONE CLEAN EPITHERMAL PASS FIELD PICK GOC AT 8926' THIS FILE CONTAINS RAW PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFi~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1065827 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1065827 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1065827 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1065827 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Veri£ication Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 27 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) TNRA PS3 1065827 O0 000 O0 0 7 1 1 4 RTNRPS3 1065827 O0 000 O0 0 7 1 1 4 ENRAPS3 1065827 O0 000 O0 0 7 1 1 4 CFEC PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 CNEC PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 RCEF PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 RCENPS3 CPS 1065827 O0 000 O0 0 7 1 1 4 RCNT PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 RCFT PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 CNTC PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 CFTC PS3 CPS 1065827 O0 000 O0 0 7 1 1 4 NPOR PS3 PU 1065827 O0 000 O0 0 7 1 1 4 GR PS3 GAPI 1065827 O0 000 O0 0 7 1 1 4 TENS PS3 LB 1065827 O0 000 O0 0 7 1 1 4 CCL PS3 V 1065827 O0 000 O0 0 7 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9203.000 NPHI.PS3 21.475 ENPH. PS3 TNRA.PS3 2.578 RTNR.PS3 2.731 ENRA.PS3 CNEC. PS3 3099.589 RCEF. PS3 699.040 RCEN. PS3 RCFT. PS3 868.675 CNTC. PS3 2433.819 CFTC. PS3 GR.PS3 45.031 TENS.PS3 2745.000 CCL.PS3 DEPT. 8781.500 NPHI.PS3 10.570 ENPH. PS3 TNRA.PS3 1.800 RTNR.PS3 1.955 ENRA.PS3 CNEC. PS3 3544.852 RCEF. PS3 1175.098 RCEN. PS3 RCFT. PS3 1613.487 CNTC.PS3 3253.386 CFTC. PS3 GR.PS3 34.594 TENS.PS3 3465.000 CCL.PS3 26. 070 TNPH. PS3 4. 244 CFEC. PS3 2865. 056 RCNT. PS3 962. 400 NPOR. PS3 -0. 016 15.588 TNPH. PS3 3.002 CFEC. PS3 3310.775 RCNT. PS3 1807.446 NPOR.PS3 0.021 23.608 730.384 2413.237 23.608 13.375 1180.829 3327.298 12.637 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LI~ Tape Verification Listing Schlumberger Alaska Computing Center 21-JAN-1998 14:27 PAGE: 28 **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 98/01/21 ORIGIN : FLIC TAPE NAFiE : 98028 CONTINUATION # : 1 PREVIOUS TAPE : COF~4F2Fr : ARCO ALASKA INC., PRUDHOE BAY, D.S. ll-04A, API# 50-029-20480-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/21 ORIGIN : FLIC REEL NAI~E : 98028 CONTINUATION # : PREVIOUS REEL : COMFIENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. ll-04A, API# 50-029-20480-01 * AhaSKA CONOUTING CENTE~ * , , ****************************** CO~P,aNY NAtdE ,*, ARCO ALASKa,~ INC, WELL NA~E : DS 11 ' 04a !PI NLIabER : 50-0~9-20480-01 REFERENCE NO : 95058 RECEIVED Adaska Oit a Gas ~' ' .... ' ~ A~ohora.~ Verification L,L st. lnc~ Chlumberger Alaska Computinm Center 1,-MAR-~,995 16:18 **** REEL HEADER SERVICE NAME : EDIt D~T~ .' 9510~/ OPIGIN : FDIC REEL NA~E : 9505~ CONT.!NUATION ~ : CO~ENT : ARCO ALASKA I~",~C., DS 11,-04A., PRL!DHOE BAY, APl 50-029'20480'01 **** TAPE HEADER **** SERVICE; NAME : EDIT DATE : 95/03/ 1, OPIC, IN ~' FLIC T.~.PF NA~E : 05058 CONTINUATIOM ~ ~ i. PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., DS I'l-04A, PRt!D}.iOE .~AY, ~PI 50-0~9-20480-0f TAPE ~EADER P~UDHOE C.ISFD HOLE WIPELI'.NE I,.,OGS WEI,.,L NA~E: APl NUaBE~: OPERATOR: LOGGI MG COMPANY: TaPE CREATION DATE: jOB NIINBER: LOGGING ENGINEEr: OPERATOR WITNESS: SURFACE bOCATION SECTION: TOWNSHIP: RANGE: W H [,,: FSL: FWL: E~.,5~VATI[~N(FT FROM ~qSL ()) KELLY ~USHING: GROUNO LEV~L: W~bI., CASING RECORD DS t 1 - 04A 50029204E001 Al!CO ALASKA, 1 -M ,~ R- 95 jACK RATHERT ~IKE REY~OLD 33 15E 54,50 54 bO 28~00 1ST STRING ~ND STmIWG 3RD ,~TR I ~!G PRODt!CTInN 5TRT t.tG 4,50o CURVE SHIFT DATA '", ALI, PAS,qK5 TO STANDARb(~'it~.;ASURF;D DEPTH) FDPEN HObg CASIP~G ORII, LER$ CASING ~TT ~!ZE (I~) SIZE (ID:) DEPTIt (FT) WEIGHT (LB/FT) 00 q,A25 7831,0 47.00 O0 7.000 9353,0 29.00 g5~9,0 12.60 PAGE: IS Tane Verlflcation List~r.,q cblumberger AlasKa Computing Center ~ASE[,INE CURVE FOR SHIF',~S LDWG TOOL CODE: DLL LDWG CUPVE COOE: GR DATE LOGGED: LOGGING CO~ANY: BASELINE DEPTH ~888~ n 906] 5 9045 0 8979 0 8821 5 ~00.0 .......... E(Jl.,;:IVA, LENT UNGHIFTED DEPTH---------- TDTP 9~24,0 9063,5 9044°5 8979°O 882~.5 ' t~ ...... TP ........ TNE BA~ P,AS~ 1 GRCH WAS SHIFTED TO THE [:)PEN HOI, E: GR A~'~[) gLlj .BASF PASS I TDTP CURVES WERE SHIFTED ~:I'!?l~ THE ASE PASS 1 ~RCH, **** FI[,,E HEADER FILE NA~E : EDIT .001 SERVICE : ~b!C VFR$ION : O0tCO1 DATE : ~5t03/ ~AX REC SIZE : 1024 FILE TYPE : bAST FILE : FILF NEADER FILE NUMBER: 1 EDITED CURVES DePth shifted and Cl~.pPed curves ~or each pass i. separate tiles. 0.5O00 P~S$ DFPTH INCPEHENT: FILE LUNG TOOL CODE CURVE SUIFT D~,I.',,",, - PASS '.I'0 PAS,5(~.%F.,ASURED DEPTH) BASEI, INE CURVE FOR SHIFTS LONG CURVF CUr)E: PASS NUU[~,F:R: C)OOUO00000 89 0000000000 89 0000000000 89 0000000000 89 0000000000 0000000000 89 0000000000 0000000000 89 0000000000 89 ~ t [ t 0 00 000 O0 ~8600~ fid 0000000000 89 0000000000 Nm~mmmmmmmmmmmmmmmmmmmmm#m#mmm 0 q 9 0 '[ 99 9I 89 99 0 99 KI 99 '~t ~'0 89 8 99 [ 99 ~8 EL 0 99 0 99 # $ H ,i; d iii Cl :] ,a I q 7I ~ ¥~ 8'[:9t IS Tape Verification [ist.ino chlumberger AlasKa Computi, nd Cent. er I-~v~AR-1995 PAGE: TCFD TDTP CPS 500984 TSC~ TDTP CPS $00984 TSCF TDTP CPS 500984 INND TDTP CPS 5009~4 INFD TDTP CPS ~00984 BAC~ TDTP CPS 5009~4 TBAC TDTP CPS 500984 T~NS TDTP LB 500984 G~C~ TDTP GAPI 5009~4 CE API ~P API AP. N[~i~ .UMB SIZE R ~ t, OG TYPE C[,~SS ~Or) NUmB Simp EbE,~ CODE (~EX) 84 O0 0 00 () 1 1, 1 ,4 68 0000000000 0 1 1 !. 4 68 0000000000 00 000 00 O0 000 O0 0 I 1 ~, 4 68 0000000000 O0 000 O0 0 1 ! !. 4 6~ 0000000000 00 000 00 0 ! !. 1 4 68 0000000000 00 000 O0 0 1 1 1 4 6~ 0000000000 O0 000 O0 0 1 1 1 4 6~ 0000000000 O0 000 O0 0 1 I 1 ~ 68 0000000000 O0 000 O0 0 1. I. I 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 ** DaTA ** DFPT. 9183.000 SDSI.TDTP 0.513 TRAT,TDTP 2.353 TCFD.TDTP 11280,063 INFD,TDTP 616,21.2 (;~CH,TDTP -999.250 D~PT. 9000.000 SDSI,TDTP 0.395 T~A?.TDTP 2.440 TCFD,TDTP 9163.000 INFD.TDTP 373.438 G~CH.TDTP 29.255 D~PT. 8796.000 $U8I,TDTP 0.454 TPAT.TDTP 2.131 TCFD.TDTP 9643.717 INFD.TDTP 409.411 GRCH.TDTP 35.250 ** END OW DATA ** SI(;M'TDTP 19.053 8IGC,TDTP 1,824 $iBH.TDTP SBNN, IL.!.P 36 534 SBHF.TDTP 29.916 TPHI., TDTP TCAN.T[)TP 4456.3:63~ TCAF.TDTP 18939. 102 TCND.TDTP TSC~.""D' ... ' p . . I rp 8885 299 TSCF,%DT 3776 164 INND TDTP P.ACK,,['~P ].4~ 783 TBAC lDO.. 53:758 IENS TDTP S IG'N , :fDTP 13.036 S!GC.TDTP 2 076 ~5'I' BH. TDTP St3FinJ. TDTD 3~.000 SBHF,TDTp 29:050 TPH!,TDTP TCAN,TDTP 45255.000 TCAF,TDTP 18550 000 TCND.TDTP TSC.N.TDTP 9057.5()0 TSCF.TDTP 3712:625 INND.TDTP BACK..TDTP 125.628 TI:AC TgYP 23~985 TENS TDTP SIG'~.TDTP 16.375 SIGC.TDTP 2.910 $IBH.TDTP SBF~N . TDTP 41.645 SBHF'. TDTP 31..o59 TPHI.TDTP TCAN.TDTP 36579.250 TCAF.TDTP 1.7163.258 TCND.TDTP TSCN.TDTP 7371.438 TSCF.TDTP 3458.734 INND,TDTP BACK.TDTP !49.590 T~AC.TDTP 29. 173 TENS.TDTP 36.534 25,129 30714.531 21,60,321 980.000 38.000 25,909 27517,250 1778,188 940,000 41.645 1,9.162 26232,113 20t. 9,407 925.000 **** FILM FTLF MA~E : EDIT .OOl SERVICE : ~LIC VERSION : O01CO1 DATF MAX REC SIZE : ]024 FTLF TYPE : LO IS Tape Veriilcation Listina chlumberger A].aska Computina Center ]-MAR-tg95 16:18 PAGE: FILE NAME : EDIT .002 SFRVICE : FLIC VERSION ~ O0~CO1 D~TE : 95/03/ MAX REC SIZE FILE TYPE LnST FILE FIL~ NUMBER: 2 EDITED CURVES DePth shifted add clipped curves for each pass in separate fi, les. PASS NU~iBER: DEPTH IgCRE~ENT: 0.5000 FILE SUMMARY T,DWG ToO~, CODE START DEPT~ STOP DEPTH ..... ......... TDTP 9~8 '03 8795.0 CURVE SHIFT DATA - PASS TO PASS(MEASUR~]D ?)EPTH) BASELINE CURVE FOR SHIFTS [.,D~G CUPVE CODE: PASS NUMBER: PASELINE DEPTH GRCH SIG~ 9171,0 9173.5 9~53.0 9~52.0 9~.2a,5 906],5 9060.5 9045.5 9044.5 9009.0 900~.0 9004.5 89~1.5 8g~O.n 8972.5 8972.5 8959.5 8957.0 ~96,0 8R95.0 8949,5 8948,5 8811.0 ~10.0 100,0 99,0 99.0 --- ....... Ei~IJIVALE:NT UNSHIFTED DEPTH--- .... ---, PE~APKS: 'I.'DTP BASE P~SS 2 GDCH, AN[; TH~ BASE PASS 2 SIG? WAS SHIFTED t£.) THE BAS~ PsSS ] SI{;~. Al,],, TDTD CUDVFS ~ERE SHIFTED WITH THE 0000000000 ~q ~ I [ a 0 O0 000 O0 ~600§ ~dD 0000000000 09 P t t ~ 0 O0 000 OO ~86u0~ 9dD d~ ~AmI 0000000000 89 ~ I t ~ 0 O0 000 OU ~8600~ 9dD difli QNNI 0000000000 89 9 ~ I g 0 O0 000 O0 v860©~ ~dD d£Oi 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~8600~ 9dD 0000000000 89 ~ I I ~ 0 O0 000 O0 58600~ SdD 0000000000 ~9 ~ ~ t d O O0 000 O0 ~600B 9dD 0000000000 89 ~ I I ~ 0 O0 000 O0 ~8600~ ~dD diQi 0000000000 89 ~ I ~ ~ 0 O0 000 O0 ~8600~ ~dD di~,L 0000000000 89 ~ I I ~ 0 o0 000 O0 ~8600~ 0000000000 89 9 t '[ g 0 o0 000 O0 ~8600~ $-~d 0000000000 89 ~ I '[ ~ 0 O0 000 O0 ~8600fi fid diOi ~H~ 0000000000 B9 ~ I I ~ 0 O0 000 O0 ~8600~ fid oooooooooo 89 ~ t ~ g o oo ooo oo ~86oo~ nD 0000000000 89 9 I I ~ 0 O0 000 O0 ~8600§ fid 0000000000 89 ~ I ~ g 0 O0 000 O0 ~8600h /ID dg£11 09I~ 0000000000 89 ~ t I g 0 OO 000 O0 ~8600~ i15 0000000000 89 ~ I t ~ 0 O0 000 O0 ~8600~ iA mmmmmmmmmmmmmm~#mmmmmmmmmmmmmm t 99 0 :3DVd 8'i,:91 ,q66[-dVt4-I ViV(1 £VNHO~4 9,[;1 iS Tape Yerificatlon bistlna chlumberger AlasKa Computing Center 1-MAR-!995 PAGE~ ~... $ , %iCE AP! P FILE NU~ U~!]B SIZE REPR PRO ~ ID ORDER ~ bOG TYPE ChASS MOD NUMB SAND EbEM CODE (HEX) F'BAC TDTP CPS 5009fl4 O0 OOO O0 0 2 1 1 4 68 0000000o00 TENS TDTP bB 500984 O0 000 00 0 2 1 1 4 68 0000000000 G~CH TDTP GAPi 5009~4 00 000 O0 0 2 I ! 4 68 0000000000 * * O ~ T A , * DEPT 91~3.000 SIGi~4.TDI.'P 1~.343 SI(;C.: ...... I ,2... 38.1 SIBH.TDTP SDSI;TDTP 0,537 SBHN.TDIP~' 37.609 SBHF:,TD~P' ' 29~B40 TP~tI,TDTP T~AT.TDTP 2 223 "~ ........ ., . . TC .N TDTP 43064 000 TCAF.TDTP 19373 000 TC,ND TDTP TCFD, TDTP 11489. 500 TSCN . TDTP 8623 ,.750 · c(-~..... ...... ~., i ~. ~I'P'~'D ". 387q.. '150 iNND ' TDTP INFD,TDTP 620.469 BACK,TDTP 172,906 FBgC,TDTP 6]..090 TENS,TDTP GgC~i, TDTP -999,250 D E. P T , 9000 , 000 S I G iq . T D T P 13 . 484 S I G C., T E)'I" ? 2 . 278 S I B H . T D '.t P SDST.TDTP 0.375 SBHN.TI)TV 39.~38 SBHF.,~.,,TP" D 35.023 TPHI.TDTP TRAT,TDTP 2. 434 TCA?~.TDTP 44340.000 TCAF.TDTP 1,8218.000 "ICbD.TDTP') TCFD..TDTP 0~,66.000 ~SCN.TDTP ~{087 000 TSCF.TDTP 3692.375 INND TDTP INFn., . TDTP 370.613, BACk. TDS?D i 7 J.: 223 FBAC .. 'EDT P 36.924 'fEN,,,~'S ~TDTP GRC~i, TDTP 35.719 D~PT. 8705,000 SIGM,TDTP 16.37~ SIGC,TDTP 2 432 $IBH,TDTP SDSI,TDTP 0,449 SBHH,TDTP 41,633 S[~HF,TDTP 33~658 TPHI,TDTP RAT,TDTP 2,139 TCA.!~d,TDTP 38150.086 TCAF.TDTP 17831~ 414 TCND ~DTP ~CFD,TDTP 9922.254 TSCt~,TDTD 7791.395 TSCF,TDTP 3641'711 I'NND:TDTP I MFD . .~.9TP' ~ 3Q3 . 577 B.~CK , TDTP 167 . 824 FBAC. TDTP. 35,536 TENS, TDTP G~CW, TI)TP 34,281 ** END OF DATA ** 37,609 21.349 29708,125 2208,5(:)0 977,094 ,938 ,893 27478,750 ~.870,438 930,000 4,1 633 26857,637 1869,2.41 915,000 **** FILE TRAIL, ER **** FTLF NAHE : EDIT ,002 SFRVICE : FLTC VERSION : 0 0 :J, CO 1, DATF : 95/03/ ~aX REC SIZE : 1024 FTLF TYPE : LU LAST FI[,E ~'66 §'~6 0'~688 ~'6L6~ 0'~006 0'8006 0'E806 0'~'806 ~'~0t6 O'Yg~6 0'g£I5 0'L£~6 0"00'[ O'OLS8 0"~006 S'9L06 0'[806 ~806 0 9806 O'§OI~ 0"~6 0"8E¥6 ~'g~6 O°~L[6 0'~8888 $ §' S6/8 O' [B'[6 aaO~aH ~qlA 8'1::91 ,,q661:-ava-[ Tape Verification Listinq· ,chlt]mberoer AlasKa Compt]tlr.~q Center !-~AR-1995 16:1@ GRCM, Ak~D THE BASE PASS 3 6IGM WAS SHIFTED TO THE BASE PASS J SI.G~, ALL TDTP CURVES WERE SH]'FTED WITH THE f)ASE PASS 3 SI. GM CURVE7, LIS FOR. MAT DATA ** DATA F~]RMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** T'YP REP? C E V~l':, 1 66 0 ** SET TYPE - CHAM g S RV UNiT SE C ? AP~ APl: .~PI' F E NUMB B SiZE REPR PROCES ID 0ROER # LOG TYPE CLASS ~OD NUMB SA~P ELEM CODE (HEX) D~PT FT 500984 00 000 0O 0 3 1 1 4 68 STG~' TDTP CU 5009~4 00 000 00 0 3 I 1, 4 08 $IGC TDTP C~t 5009~4 00 000 O0 0 3 1 1 4 6~ $!B~ TDTP CU 5009~4 00 0O0 00 O 3 1 1 4 68 SDS! TDTP C~! 50098A 00 00O O0 0 3 1 1 4 68 SRHN TI)TP C~I 500984 O0 000 00 0 3 1 1 4 68 S~NF TDTP CU 5oog~4 00 O00 00 O 3 J. 1 4 68 TDHI TDTP PU-$ 500994 0O 000 0O 0 3 I 1 4 68 T~Aw TDTP 500984 00 000 O0 0 3 1 1 4 6~ TCA~ TDTP CPS 5009~4 00 000 00 0 3 1 1 4 69 TCAw ~DTP CPS q009~4 O0 OO0 00 O 3 1 1 4 68 TCND TDTP CPS 5009~4 00 0o0 00 0 ~ ! 1 4 68 TCFD TDTP CPS 500984 OO 000 00 0 3 1 1 4 68 'FSCw TDTP CPS 500984 00 0O0 00 0 3 ! 1 4 68 TSC~ TDTP CPS 500984 00 000 00 0 3 1 1 4 68 INND Wl')'~p CPS 500984 00 000 00 0 3 1 I 4 66 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000000 0000000000 0000000000 0000000000 0000000000 O000000O00 0000000000 0000000000 ~ODtO0 : ~"II,H **** ~6§'896 09L'669[ O00'LEOLE 6~q'6[ O00'OL6 O[P'~SI6E 8EO'L[ '''~';'''''''''';'''''''0 0 00000 8 P .... ;'''''I E"'''''''''''~;;''''''';~''''''''''''''~'~';;'O O0 O0 600~ idYD dA oooooooooo ~9 ~ ~ ~ ~ o oo ooo oo ~6oo~ ~ ~ oooooooooo ~9 ~ ~ ~ ~ ,, oo ooo oo ~oos sd~ a~ 01[ 'SgVd 7~V~J 3H$ 0"L§68 ~'EL'g6 0°8888~ O"JO~ 0°9968 0°00o6 0'~0t6 0'~£t6 O'6BB8 0'~/688 d ~ LI :L 0 0 0 0 0 mmimmmmm $ 0"00[ 0'v688 S"9~68 0'0006 ~°~006 ~'E906 ~"g806 '00~6 'ot~6 'ELi6 $ 000§"0 :~N~DNI H&d~O :83~F1N soA~no paOdtIO pue pO~'IqS :8~NN ~qiA 't t 8'[:9t §66'l;-aV~-'i: b u t 7 s !"1 u o l; ,o, e o l; ~ t .z o A o o e i S I IS Tame Verification Li. st.j. no chlumberger AlasKa (~'omptltin~ Center l-re'AR-1995 P~S8 1 8I~, ALL Tr)TP CURVF.$ WERE 8},~IFTED WITH THE [~OR,t.X P~68 1 8IGN CURVE, hfs FORMAT DATA PAGE: 12 DATA FORMAT SPECIFICATION RECORD ** SET TYPE TYP~ ALIIE I 66 0 2 66 0 3 73 84: 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 1~ 66 0 14, 65 1,5 66 68 16 6~ 0 66 ** SET TYPE - CHAN ** AMF $ RV U .[9. SERV AP1 API AFl FiL NUMS NU"B SIZE EPR RUCESS ~[) ORDEP g LOG TYPE CbASS ~[.)D NtJ~B SA~!P ELFiq C()DE (HEX~ DEPT FT ~00984 00 000 00 0 4 1 1 4 68 SIG~ TDTP CI! 500984 00 000 00 0 4 1 1 4 68 S~GC TDTP Cl.t 500984 O0 000 O0 O 4 1 1 4 68 $IB~ TDTP CU 5u09~4 oo 000 O0 0 4 ]. 1 4 68 SDSI TDTP CU 5o09~4 00 000 00 O 4 1 1 4 6~ SgW~ TD~P CU 500984 O0 O00 O0 0 4 1 1 4 6~ S~Hw TDTP CU 500984 O0 CO0 O0 0 4 1 1 4 68 TPHT ~D~P PU-S 500984 O0 000 00 0 4 1 I 4 68 T~AT TDTP 5009~4 O0 ilO0 O0 0 4 1 1 4 68 TCA~ TDTP CPS 500984 O0 OOO O0 0 4 I ! 4 68 TCAF TD~P CPS 5009~4 O0 000 oO 0 4 1 1 4 68 TCN~ TDTP CPS 50o9~4 o0 000 00 0 4 1 1 4 68 'rCF~ TDTP CPS 500994 0o ()01~ 00 0 4 I 1 4 6~ TSCN TDTP CPS 500984 O0 OOO O0 0 4 ! 1 4 68 TSCF TDTP CPS 500984 00 000 00 0 4 ~. 1 4 68 INND TDTP CPS ~009~4 Oo 00o oo 0 a 1 1 4 68 nO00000000 0000000000 0000000000 0000000000 0000000o00 0000000000 0000000000 O00000000n 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Tape Verificat.~o, chlumberger AlasKa ComputJDq Center 1-MAR-1995 1,6:18 1¸3 ID ORDE]R # L, OG TYPE Cb~a,SS MOP NUMB SA~P gL, EM C[IDE (HEX) "'""'"'" ...... ' ..... ' .......... ' ............. '"'""'"'"'"""'""'"'"'"" N CPS q009~4, O0 000 O0 o 4 I 1, 4 00000000 0 B~CK TDTP CPS 50098~ O0 000 O0 0 4 1 I 4 68 0000000000 FBAC TDTP CPS 50()9~ (* O0 000 O0 0 4 1 1 4 68 0000000000 T~TNS TDTP LB 500984 O0 000 O0 0 4 1 J. 4 6~ 00()0000000 GRCH TDTP GAPI 500984 O0 000 00 0 a i 1 4 68 0000000000 ** DATA g183,000 $,'l Gt~!, TDTP 17.799 $IGC,TDTP 0,251 $IBH.TDTP DEPT'TDTP 0 677 SB}.-~ N ' TD'I~P 90.496 SBHF, TDTP 68.992 TPHI.TDTP TRAT.TDTP 2,221 TCA !~, TD'.'FP 11932,738 TC~F,TDTP 5373,540 TCND.TDTP , . ." ' T' .... TDTP 1438,584 !NND.TDTP TCFD TDTP 4173 093 TSCq TDTP 3!94. 587 I~FD, TI)TP 360,56~, BACK,TDTP 235~983 FbAC.TDTP 58.084 TENS,TDTP GRCN.~rDTP -999,250 DEPT., 9000.000 $ICt'i.'~'r)'vP~,,,,,~ 13.378 S,.T. GC... .TDTP 0 212 SIEH.TDTP 5~SI TDTP 0 3a9 o,6Ha" q,~'vp 82 464 ~BBF,~ TDTP 66:191 TPHI TDTP IRAT.T[)TP 2.1.11 TCAN TI)TD 20598 000 TC ~ T,I,P 9755.750 TCND.TDTP TCFD.TDTP 5745.750 TSCN . TD'.FP 5553~125 TSCF.TDTP 2630.003 INND.TDTP I NPD. Tt.')TP 3~6.957 BACK.??DTP 203.211 FBAC,TDTP 38.200 TF, NS.TDTP G~CM.TDTP )0.703 OEP?' 8804 000 SlG~.'fD~'. 13.116 SIGC.TDF!~, 0 130 . . . .TDTP 87 415 SB~F,TD~.P' 62[224 ~.'PHI. TDTP SDSI' TDTP 0 290 SBH['d _~,~..,~ . . TRAT.TDTP 1,595 TCAN.TDTP 20312.527 TCAF,TDTP 12734.756 TCb~D.TDTP TCFD.TDTP 6939,283 TSCN.TDTP 5444,394 TSCF.TDTP 3413.314 INKD.TDTP I'~FD. TDTP 363.359 BACK,TDTP ~09.600 FBAC.TDTm 38.735 TE~S.TDTP GPCg. TDTP -999,250 ** END OF DATA 14.4.612 28.962 17~2 166 1025,000 124.797 25,485 14992.938 t, 794.846 975,000 iP2,506 14.175 14296.971 1828.71,4 970.000 **** FILE TRAILER FIL~i NA~E : El}IT .004 SERVICE : Fb~.C VERSI~]N : 001C01 DATE : qbl03/ 1 BAX REC S~ZE : ~02~ FILF TYPE : LAST FI!,E : --- .... ---H£dMd Q~J'~MIHgNF{ 3.~N~qYAIll',.O. 2-'-- ...... $ O"96LR 0'E816 000~'0 ;~iN]N~DNI H~dJq :Sa~Oa : :~9Vd O0 89 T I ~ U 00() O0 8 H ~ 0000000000 89 ~ ~ ~ ~ 0 0000000000 89 ~ ~ i ~ 0 0000000000 89 ~ ~ ~ ~ 0 0000000000 ~9 ~ I I ~ 0 0000000000 80 ~ I I ~ 0 0000000000 89 ~ I t ~ 0 0000000000 89 ~ I '[ § 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ t I § 0 0000000000 80 ~ I t S 0 0000000000 89 ~ I '~ S 0 0000000000 89 ~ t I S o 0000000000 8g ~ I I ~ 0 0000000000 89 ~ I I ~ 0 0000000000 89 ~ I [ ~ 0 0000000000 89 ~ t I § 0 0000000000 89 ~ I I S 0 0000000000 89 ~ I I § 0 0000000000 89 ~ i t ~ 0 O0 000 O0 ~8600~ ~dD O0 000 O0 ~fl6OO~ 983 O0 000 O0 ~8600§ ~ciD O0 000 O0 ~8600g gdo d&O& NDS£ O0 000 00 P86005 ~dD O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 OOO 00 V86005 WdD d&Q£ ~NJ$ 00 ~8600§ ~dO d£Q& NVO£ O0 ~8600S d,l,(l~ £VaA O0 ~600h ~-tld d&O£ IHo& O0 P8600S fid di[(]£ AH~9 O0 ~8600S fid d~O& NHdS O0 P860()~ ilo dAG& tgOS O0 ~8600§ t"lD d$(]~ ODIg O0 ~B600~ fid di£l& nDi~ O0 'P8600~ £M &d~O ; 99 0 [ 99 9'I ,I,a ~9 Vt 0 99 Et 99 ~L~ ~9 6 ~'0 89 99 99 0 99 0 99 . ,L,~S ** ,, (l li O 3 :] a .lq [711,1,'¥ 31:11 D 21 d S Z'V ~'80 ¢1 ¥ ~i, ~/(l ,, ,IS Tape Verification Listin<) ;chlumheroer Alaska ComputlnQ Center 1-~AR-1995 1.6:!8 DEP'V. 91~3 000 $IGM.TDTP 17.~98 SIGC.I."'DTP , .... , E~'~ , , ~ [.. SDSY.TDTP 0 687 S['~ T..,)IP 88 637 SBH~ O~'t~ '.I'RAT. TI)TP 2,069 TC.a N, TDTP .~. I114. 109 TCAF, TDTP TCFD,TDTP 4068.850 TSCI~. TDTP 2986.22l TSCF.TDTP iMFD,TDTP 365,44..9 ~3ACK.TDTP 24:0.375 FBAC,TDTP G~C",TDTP -909.250 DEPT, 9000.000 SIG~¢.TDTP SDS!.TDTP 0.432 T~AT.TDTP 2.1~7 TCAt,~. TDTP TCFD,TDTP 5736.8~8 TSC!'!. TDTD INFD.TDTP 342.240 ~ACK. TDTP G~CH.TDTP 4!.594 DEPT. 8884.500 S !G:~'i. TDTP 10.4(,19 SIGC.TDTP SDS].TDTP 0,239 SE~H~. TDTP 95.504 SBHF.TDTP T~AT,TDTP 1.442 TCAN.~''* TC ~[)IP ~3795.297 AF.TDTP ~ 92 TSCF. TDTP TCFD. TDT P. 8253.512 TSCM. TDTP,,. ,, 6340.2o6 I~iFD.TDTP 358,083 RACK. ,I D,I,P ~00. ....... FBAC.TDTP GDCH.TDTP 41 0 4.20 8I[.%H.TDTP 70 ~ 756 TPHI .TDTP 537~.438 TCND.TDTP t44] 50'7 3t~JND. TDTP 53 ],271 TE,NS.TPTP 0 213 SIB}{.TDTP 57 796 TPHI.TDTP 9849 R05 TCND.TDTP 2637 629 IPJND.TDTP 39 985 TE~$.TDTP 0 (t68 $IBF{.TDTP 69~238 TPBI.TDTP !,6504152 TClaD.TDTP 4397i487 IN'~D.TDTP 37 006 TENS.TDTP 134 428 11.081,074 1755.667 9~0.000 I~0.507 26.104 !.5058.467 1699,!71 945,000 1,29.594 10.177 15268,674 1811.042 940.000 **** F,'I [,E TRAILER **** FILE MA~E : F,D!T .005 SERVICE : FbIC VERSIO~J : nO1COl [)IT~ : 95/03/ 1 ~5X REC SIZE : ~..024 FTb~ TYDE : l,O LAST FILE ~ **** FILE }qEADER **** FILE UA~E : EDIT .006 SERVICE : FLIC V~RSiO~ : O01COI DaTF ! 95/03/ 1 ~AX REC $!Z~ : ~024 FILF TYPE : L~ST FILE FI[,~ [lEADER AVEDAGED CURVES Compensated Neutron: Arithmetic averaoe ot edited passes for all curves. Pulsed Neutron: !!naveraoed edited PaSs 1 Gamma R~F and Oackround counts; arithmetic average 0000000000 t,:,,q > I '[ 9 0 O0 000 00 t~'8600h ¢-[ld AVNd .tHd.I, OO000000OO 89 ~ t ~ 9 0 O0 000 O0 1~8600~ fid A ~t' Nd OOOO000000 89 ~ I I 9 O O0 000 O0 ~8600h ltd All.Nd O000000000 89 ~ I I 9 0 O0 000 O0 ~8600~ I'iD AVNd 0000000000 89 ~ I ~ 9 0 O0 000 O0 P8600~ fid A~Nd H9i9 0000000000 89 f2 I ~ 9 0 O0 000 O0 ~860()S [13 A~Nd OOO00Oo000 89 ~ I I 9 0 O0 000 O0 ~8600~ FID A~Nd 0000000000 80 1~ t I 9 0 O0 000 O0 ~8600fi &.~ [ 9 0 89 99 0 99 ET ~l 99 ~'0 89 8 99 I 99 ~8 EL 0 99 0 99 LT ** ¥&~(J ,.,'JO qN::"t ** 000'0~6 86.q'it~£LE 9~ 000~086 tLE'gg86E (")~ E ' .q [ d,J. 0,I, ' HDaD 601~ ' 8 (5 E A V Nd ' (,J.,4 a ! E.'L8' gsb6 A ~' N d ' kia,3,.I, T,L~ ' 0 A~Nd ' 000'96L8 ~'[g'O A~Nd'i. g09 000'~8/6 '~d~O 00000 0 00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O0 O0 89 I t 9 O0 89 ~ I i' 9 0 00 000 O0 000 00 000 O0 000 O0 000 00 000 O0 000 O0 000 O0 000 O0 000 O0 000 00 0 0 0 ~8600~ 00000000 0000000000 89 ~ '[ t 9 0 O0 000 Ou ~U6u05 (X~]H) ~OD W~"iM d~'B ~it'~["tN (ION gg~qD ~d~,~ 90rl ~ a:flO~'tO SS3Dt:iHd ~d~ :~glS ~NitN ENfl,N ~qla idV IdV tar IdV aDIaat3~ &l:afl a lJJJJJJJiJiJJilJJJJJiJiJJi/iJJJJJJilJlJij,jJlJilllJlJllJJiJllJJJJlJJJllllijijj O0 ~8600~ Bq O0 P8600~ 9dO O0 ~8600~ ~dO O0 ~8600~ gdD A~Nd O0 ~8600~ 9dD A'~N~ 00 ~8600~ 960 A~Nd O0 P8600h ~dD A~Nd O0 ~8600~ ~dD A~Nd O0 ~8600~ ~dO A~Nd O0 ~860()~ 9dD A~Nd A~Nd : ,~DYd 8 '[: 91 ,q 6 6 "1: "al V ~- '[ ouI~sI"l 'uoi::~eoi:7t:[a^ aae,£ IS Tape ~eri~l. catJoD ListJ, n~ chlumberger A!aske ComDutJ..nq Center **** FILE TR~!t,ER **** FILE NA~E : EDIT ,006 SFRVlCE : ?LIC VERSION : OOJ. CO1 [);~T~ ~× REC SIZE : ~024 FILE TYPE : LAST FILE **** FILE HEADER **** FIL~7 NAME : EDIT ,007 S~TRV J'.CE : VERSION : O0~CO1 D~,r~ : 95/031 1 ,~aX: ~EC SIZ~.~ = 1024 FIL~7 TYPE', : LO baST F i I,,,E : FILE HEADER FI I.,E NUMBER 7 RhW CIIRVES Curves and~ l. ot.] header data ~or each pass in semarate P~SS NU~BER: DEPT[.{ INCRF,~Et,~T: 0.5000 FILE VENDOR TOUI., CODt~,; START DEPTH STOP DEPTH TDTP 9~04 ~ 8796.0 L~G ~"~AD~/R DATA P~TE LOGGED: SOFTWARE VF~RSIf..)I'~: TIM~ LOGGER ON BOTTO~: WD D~ILLER (FT): TD LOGGER(MT): VOP LOG TNT~PV~Ij BOTTO~ bOG !MTE~VAL (FT): I,()GGTNC SPEED (FPH~): DEPTW CO~4TRO!. I.ISFD (YES/NO): TOOL ST~ING (TOP T~) BOTTOM) VEi'~DOD TOmb CODE TOOL TY~E ............ NEUTRON. TDTP p~ILSF'.[~ TDTP PIII.,SED TDTP PULSED files; raw background pass in last !1-FE~-95 42,2 1055 9188.0 9191.0 8800.0 9184.~ 1200.0 11-FE~a-95 0 g r,,JL'-,'4HM qo0,i, ,.t,~a DI',,IIO0 X'i[}-JO~J "t.lf',lfj{'}.,'i ri'JJf,INVFID ON ',,~;['b8 &~/ 'D°O'O QNflU.;J · 0000[ O 000~t 0 # :{&,..l) MOONIa DalZ:l:'l¥~q~aON ]qBe/it :(i~) ~uJOOi~llM 9NIZIq'V[~iaON dO~ f~9'a $ 8t:9t §66[-aV~i-'f 0000000000 89 t, I T /- 0 O0 O00 Oo ~'~600h C3d3 1;SCt 0000000000 89 1~ '[ i L 0 ()0 000 OO ~'~600S ~dD '[~d ,:~ ~t' ,~,1, O000000OO0 89 ~/ I ~ L 0 Ou 000 O0 t/8600.q grad 0000000000 89 ~ I I L 0 O0 000 O0 ~86o0~ 9a3 0000000000 89 ~7 t I / 0 O0 000 60 ~8~005 [12) I~d i909 0000000000 a9 ~ ~ '~ ~ 0 O0 000 O0 V8600~ 0000000000 89 ~ I I L 0 O0 000 O0 ~8600~ (iD 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~8600~ fid 0000000000 89 ~ I ~ L 0 O0 000 O0 ~86o0g ~dD 0000000000 89 ~ t I l. 0 O0 000 O0 ':P8600S 9dD 'f~ 0000000000 89 ~ I [ L o O0 000 O0 ~8600~ ~D O0000000OO 89 ~ I I L 0 O0 (')00 O0 ~8600~ 9aD 0000000000 89 ~ I '[ L () O0 000 O0 ~8600~ ~dD 0000000000 89 ~ I I L 0 O0 000 ()0 ~8600¢ ~d3 0000000000 89 ~ I t L o Oo 000 O0 ~8600g fid 0000000000 89 ~ '[ I L 0 O0 000 0() ~600S fid 0000000000 89 ~ I "[ L 0 O0 000 O0 ~86005 fid 0000000000 8q 5 I [ L 0 O0 000 O0 ~8600S A [~d [IH~I O000000000 89 ~ I I L 0 O0 000 O0 V8600h Hd 0000000000 89 ~ I t L 0 O0 000 O0 ~8600~ 0000000000 89 ~ T '[ L 0 O0 000 O0 ~8600~ lid [gd 0000000000 89 ~ '[ 't L 0 O0 CiO0 O0 ~8600~ &~ ~[' 99 0 #~mmmmmmmmmmmmm#mmmmmmmmmmmmmm tg L~Ul::~ST"l uo')':lez)"f3'[~toA oOe,£ 9I: ~I$ Tame Verification l.,istir'~c~ ichlumberger Alaska Computing Center PAGE: 22 TCND PS1 CP~ 5009~.. TCF~ p$~ CPS 500984 oo T$C~ PS1 CPS 500984 O0 000 TSCP' PSi, CPS 500984 O0 00() INND PS1 CPS 500994 O0 000 INFD PS1, CPS 500984 O0 000 LCO~ PS1. 500984 O0 000 RN1 PSi CPS 500994 O0 000 R~12 PS1. CPS 500984: O0 000 R~3 PS! CPS 500994 O0 000 ~4 PS1 CPS 500984 O0 000 R~5 PS1 CPS 5(3098.4 O0 000 RN6 PS1 CP6 500984 O0 000 RN7 PS1 CPS 5009~4 O0 000 R~8 PS! CPS 500984 O0 000 RN9 PS1. CPS 500984 O0 000 R~lO PS1 CPS 500984 O0 000 R~ll PS1 C~S 5009~4 O0 000 RNI~ PSi CPS 500984 O0 000 RN'13 PSi. CPS 5009~t O0 000 R~I4 PSi. CPS 500904 OD 000 R~15 PS!. CPS 500984 O0 000 RN16 PS1 CPS 500984 O0 000 RF1 PS1 CPS 5009~4 O0 000 RW2 PS1 CPS 500984 O0 000 RF3 PS1 CPS 5o098~ O0 000 Rv4 PS1 CPS 500984 00 000 Rw5 PS1, CPS 500994 00 000 RV6 PS! CPS 5009~4 00 000 Rw7 PSi. Cp~ 500984 00 000 RF8 mS1 CPS 500994 00 0o0 RF9 PS1 CPS 5009a4 00 00O RFlO P$1 CPS ~009~4 O0 000 ~VI,~ ~S1 CPS 500984 O0 000 R~19 DS~ CvS %009~4 O0 000 RF13 PS1 CPS 5009~4 O0 000 RF14 PSi CPS 5009ga O0 000 R~I5 PS! CPS 500984 O0 Rw16 PS1 CPS 500984 O0 000 T~N$ PS! LB 500994 O0 000 G~ PSi GAPI 500984 O0 0o0 P AP1 A. I I FILE U B N't..I~'~) S .REPR PROCESS OG TYPE CbASS ~OD NUmB SA~P E,LEa CODE (HEX) 000 00 0 '7 1. 1 4 68 000000 000 O0 0 7 I 1 4 68 0000000000 00 00 O0 O0 00 O0 O0 O0 O0 O0 O0 O0 O0 O0 00 OO O0 O0 O0 O0 00 O0 O0 O0 O0 O0 O0 00 00 00 00 00 00 00 O0 00 00 00 0 7 1 1 4 6~ 0000000000 0 7 ! I 4 68 0000000000 0 7 1 I 4 68 0000000000 0 7 i 1 4 68 0000000000 0 7 I i 4 68 0000000000 0 7 I I 4 6g 0000000000 0 7 1 i 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 1 1 4 68 0000()00000 0 7 1 I 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 1. 1 4 68 0000000000 0 7 1 i 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 1 i 4 68 0000000000 0 7 1 I 4 68 0000000000 0 7 1 I 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 I I 4 68 0000000000 0 7 I I 4 68 0000000000 0 7 I 1 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 I I 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 1 1. 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 I 1 4 68 0000000000 0 7 1 1 4 68 0000000000 O 7 1 1 4 68 0000000000 0 7 1 1 4 68 O00000000O 0 7 1 1 4 68 OOOO000000 0 7 1 1, 4 68 0000000000 0 7 1 I 4 68 0000000000 0 7 1 I 4 68 0000000000 0 7 1 1 4 68 0000000000 0 7 1 I 4 68 0000000000 0 7 1 1 4 68 O0000000OO 0 7 1 1 4 68 0000000000 0 7 ! ! 4 68 O00000000O ** DATA ** DFPT 9204.500 SIGbl.PS1 ISgt~[PS1 36.563 SFFD.PS1 S~H~'.PS1 40.598 F'FDT.PS1 A~Fn. PS1 142.522 AFNI.).PS1 SIB~.~S! 40.598 ~laOF.PSl 16.923 STDT.PS1 06.000 TPHI.P$1 iq.149 SFND.PSI 21.722 SBHF.P,.S1 14.2(31 NTDT.PSI 34.522 AFFD.PS1 5o3.].$~ a, BND.PKi 434.010 SIGC.PS~ 1.. 1.09 TRAT.PSI 1,571 SDST,PS1 19.998 31.033 121.706 2.361 0.439 O6~'LO~ ~9d'E~W 69~'L8~ 09E'60g Igd'§~ IMO'SO~ ISd'~Jd S£8'gIf 960'606t ~d'6N~ 08~'~q8 tWd'MN8 SL~'6~EI 8'[g'08~I ISa'§N'~ g86''[6~1 tgd'~N~ tqL'O£O[ ~[L'8~[ tgd'3D~& 8E~'tLEL Igd'~O~i LtL'EP96 8SZ'E9ILt ISd'~DZ O~'6L§9E t~d'N~D& £L~'~Z OI6'g ~Sd'DDi9 OCL'E~9 IWd'(1N~ L6L'Lf~ 6~0'I£ '[~d'~H~g 8Ig'gg tWd*ON~S 0~0'6t g91'6'[ Igd'iHd~ 000'99 000'0~6 oo:,a 100 600'969E ~00:89L[ ~00 O0§t ~00'~8 66£!9~LE 'gO ~gLS* [g~ 0 OEt'g ~6'8E 80L'~ tSd'EtN8 [~d~ODI~ I~d'QM~V [Sd'IHd~ I00'96£ tO0'~OE [00'96[ ~00'~86 800'~8g~ gOO'Og8 [O0,9LEI 6E~'~ 0~'[016 LBO 866 9£ LL~ Lt 000 99 t~d'9[Ma go0'gEo tSd'gI,~a gOO'~q6 Isa'MN8 EO0'O0£1 l:~d'~Na g00'88~ t~d'IOOq 889'ELE tSd'qDg~ tSd'~'VM£ ISa'aa~ tSd'ZCl~N TS.d'Z(t~S '[a6'gl 8t:9t [Wd'i~a IS£'gg Tgd'LN8 O[O'LL8[ ISd'~N~ tSd'EN8 9~6'09t tWd'.Ij,]l( " LO~'6[Og I~d'~aaI' I~d'GjD~ i~t'Z~ggg ~Sd'6~Oi ISd'D~ 06§'6~I ISd'ON,~ ()8I:'L~I tSd'QJ~'V ISd'~Q~ S~9'IV iSd'NH~ tSd'§ [ja £O0'9fig [ 'lSd'liMa gOO'g'[9 iSd'OI~8 tSd'L3a to0'gLf tSd'E,d~ ECS'L[ tgd'~IN~ 800'gLEE lSd'LaM POO'PSL'[ ~gd'gN~ IRd'(ljD£ 990'Eg~Lg [9d'QNO& TSd'aV~a OLa'~T '[~d'(]3j~ IiO'~,i lSd'/iaSI IRd'~)DI~ 000'0006 gLM'gEt ISd*L~8 P69'L~L Igd'Ed8 88E'§9 tSd'SIN~ ~9'~8E 19d'IiNa E[E'g~z[ tSd'oIa8 '[Sd'EN~ ES§*~t tSd'OaNi tEg'LEL~ ISd'QdD/[ ~PM'S:~SE 0 ' 00 Z O'lzRT6 0'0088 O' 0'88[6 :(l~) Q~Aa~&NI DOq :daDDO"i $ [OD[O0 : 800' %I~ : 3;~VN ~qi,J ~u!lsJ~ "aOl'ieoIJT~aA o~ ~I~' ,IS Tame Verification Listino ,chlUmberger AlasKa Computtn~ Center !-~AR-1,995 1.6:!8 pAGE: 25 TDTP PUI]SED NEUTRON TN(;..P-236 $ BOREHOLE AND CASING DATA DRILLERS CA$IN¢ DEPTH LOGGERS CASING DEPTft BOREHO[.,E CONDITIONS F[~.,LI ! D TYPE: FLUID DENSITY CLB/G): S~IPFACE TE~:PERAT1JPE (DEGF); BOTTO~ I'~0~,E TENPERATLI~E (DEGF): FI,U!D $.~bINITY (PP,b~): FLUID LEVEL F[.,UII) :RATE~ AT WELLHEAD ~ATER CUTS (PCT): GAS/OI5 RATIO: CHOKE (DEG): TOOL TYPE (EPITHER~.AL ~'::)P THERMAL): MAT~I:X DENSITY: HOLE CORRECTiOH fIN): BL[JELINE COI~NT RATE NORMALIZATION IN OIL ZONE TOP NOR~ab!ZING WINDOW BASE NORMALIZING WINDOW (FT): BLIJEI.,INE COUNT RATE SCAbES SET BY FIELD FAR COIJNT RATE LON 8CA,[.,~: (CPS): 0 F.A~ COUNT ~ATE HIGH SCABS (CPS): ~2000 NEAR COUNT RATE LOW MCAbF (CPS): 0 k~EAR COU~,~T RATE HIGH ~}CALE (CPS): 30000 TOOL STANDOFF (IN): 9353.0 DEAD CRUDE SANDSTONE 2.65 ~AS~]; PASS 2 TIEr) INTO Z-DENSILOG 3/1/94; ~.A.: GR CIIRVE, [,OOKI. b'"G FOR PrqSSIBLE ........... GAS CHAr~N}.'L g NEW ,7.O.C. PIjPiPED 264 BB[,~ DEAD., CR[iD~7 W}!IbE N~KING 3 ~ASE PASSES. ~(7} BB[,S BORAX Ir'iTU FORM PRiOR TO ~[,)RAX PASS I B0 P, BL,,5 BORAX I~TO FOR~ PRIOR TO BORAX PA,SS 2 FOIJb',D G.O.C. AT 8932' ?,10 C[iAi',~Et_, FOIIi~D. BDR~.X Gl'liN(; }.'gSm T[.'~[)b Wl.4EN AT TD. LIS Fr~RUAT DATA Tape Verification bistinq ;chlu,mberger AlasKa Computi. nq Center PAGE: 26 ,;,~ C IFICATIOM ~ECC,}~D ** 1 66 0 2 66 0 3 73 26O 4 66 5 66 6 7,3 7 65 8 68 0.5 9 65 FT 11, 66 12 fig 13 66 0 14 65 FT 1,5 66 68 16 66 0 66 ! ** SET Typ~] - CHAN ** NN '~ ,. E AP! IP,'Ii apl F,tlr, NU~4B U SIZE RE; PR[)CES8 ID ORDER t~ bOG TYPE cbass., ~OD N"O~B SA~P. EL, E~ C('3~ (HEX) D F, P T F T 5009 R 4 00 000 O 0 0 8 1 I 4 6 ~1 STG}' PS2 Ct~ 500984 00 000 O0 0 8 1, 1 4 68 STDT PS2 ~009R4 00 000 O0 0 9 1 1 4 68 TPHT PSP pll 5009R4 O0 gO0 O0 C 8 1 I 4 6R IS'HI~ PS2 V 500984 O0 000 00 0 8 1 1 4 68 SF'FP PS2 CI) 500994 00 000 ()0 0 P 1 I 4 68 SWMn PS2 CU 5009R4 O0 00() O0 0 9 1 1 4 68 SgHW PS2 CU 5(30984 O0 OOO O0 0 8 1 1 4 68 8BHN PS2 CI.j 5009~4 O0 000 00 n 8 I 1 4 68 FTDT PS2 CPS 500984 O0 000 O0 0 ~ 1 1 4 68 NTDT PS2 CPS 500984 00 000 0O 0 8 1 1 4 6R AFF~ PS2 CPS 5009~4 O0 f)O0 O0 0 9 ! 1 4 69 A~FD PS2 CPS 500984 00 000 no 0 ~ I 1 4 68 AWND PS2 CPS 500984 00 000 O0 0 9 1 1 4 68 ABND PS2 CPS 500994 O0 OO0 00 0 R 1 1 4 68 STGC PS2 CU 500994 00 00O 00 0 8 !. I 4 68 SYB~ PS2 CU 500984 O0 000 O0 0 9 ! 1 4 68 MM~)F PS2 5009~4 O0 000 n0 0 R I J. 4 68 TPAT PSP g00984 00 000 O0 0 9 1 1 4 68 SDST PS~ CU ~(}09R4 O0 000 00 0 8 1 1 4 ~8 BACK PS2 CPS 500984 00 000 O0 0 8 1 1 4 68 FnAC PS2 CPS 500984 O0 000 OO 0 9 I 1 4 68 TCAr PS2 CPS 5(.)09~4 O0 gO0 O0 0 ~ ~ 1 4 ~ TCAF PS2 CPS ~00984 O0 OOO O0 0 8 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00()0000000 0000000000 0000()00000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000o000000 O00nO0000O Tame verification ListJ, no ~chltlmberger Alaska ComplltJ, ng Center 1-~AR-1995 t6:18 PAGE: 27 SE gV~uTC APl lid ORDER ~ [~OG TYP '~S2 CPS 500q~., O0 000 TCFD PS2 CPS 5009~,4 00 000 TSCN P$2 CPS 500984 00 000 TSC~' PS2 CPS 5009~4 00 000 INND P$2 CPS 500984 00 000 INF~ PS2 CPS 500984 O0 OOO bCO~ P$2 5009~4 O0 000 RN1 P$2 CPS 500984 O0 000 RN2 PS~ CPS 5()09a4 O0 000 RN3 P$2 CPS 5009a4 O0 00(11 R~4 PS~ CPS 500984 rio RN5 PS2 CPS 500984 O0 000 RN6 PS2 CP6 50098~ 00 000 RN7 PS2 CPS 5009~4 00 000 RNB PS2 CPS 500984 00 000 RNg PS2 CD~ 500984 00 000 RNI0 PS2 CPS 5009~4 O0 000 RNI~. PS~ CPS 500954 00 000 RNI? PS~ CPS 5009B4 ~0 000 RN1.3 PS2 CPS 500984 O0 000 RN14 PS2 CPS 500984 O0 000 RNI5 PS2 CPS 500984 O0 000 R~16 PS2 CPS 5009~4 O0 000 RF"I PS2 CPS 500984 O0 000 RF2 ¢8~ CPS 500984 O0 000 RW3 PS~ CPS 5009~4 O0 000 RF4 PS2 CPS 500984 OO 00O R~5 PS2 CPS 500984 O0 000 RF6 PS2 CPS 500984 O0 000 RF7 PS~ CPS 500904 O0 000 RW8 PS2 CPS ~00904 O0 000 RF9 PS2 CPS 50098~ 00 000 RWl, 0 PS2 CPS 500984 O0 000 RFI~ PS2 CPS 500984 O0 O00 RFI? PS2 CPS 500904 o0 000 Rwl3 PS~ CPS 500984 O0 000 RWld P$2 CPS SO09g4 O0 000 RF15 PS2 CPS 500954 00 000 Rmi6 PS2 CPS 500984 00 00O TFN~ P$2 b~ 500984 O0 000 G~ PS2 GAPI 500984 00 000 0 ~ 1 1 ,4 ~ 0o00000 0- OO o ~ I, 1 4 68 0000000000 O0 0 8 1 I 4 68 0000000000 O0 0 8 1 I 4 6~ 0000000000 O0 0 8 I 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 8 I I 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 8 1 I 4 68 0000000000 OO 0 8 1 1, 4 68 0000000000 O0 0 ~ 1 I 4 60 0000000000 O0 0 8 1 i 4 68 0000000000 O0 0 8 1, 1 4 68 0000000000 O0 0 g I 1 4 68 0000000000 00 0 8 1 1 4 68 0000000000 00 0 8 1 1 4 68 0000000000 O0 0 8 1 :1 4 68 0000000000 O0 0 8 ! 1 4 68 0000000000 O0 0 8 1 1 4 68 0000o00000 O0 0 ~ 1 1 4 68 0000000000 O0 0 ~ 1. 1 4 68 0000000000 O0 0 ~ I 1 4 68 0000000000 O0 0 ~ 1 I 4 68 0000000000 O0 0 8 1 1 4 68 000O000000 O0 0 8 I 1 4 68 O000UO0000 O0 0 8 ~, 1 4 68 0000000000 O0 0 8 ! 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 8 1 i 4 68 0000000000 O0 0 ~ 1 I 4 68 0000000000 O0 0 8 1 I 4 68 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 8 ! 1 4 68 0000000000 O0 0 8 I I 4 68 0000000000 O0 o a 1 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 ~ 1 I 4 68 0000000000 m~mmMmmmmmmm#mmm mmmmmmmmmmmmmmm~mmmmm~mmm~mm#mmmmmmmmmmmmmmmm DATA ** DEPT. 9203.500 SICH.PS2 ISHII,PS2 37,063 SFFD,PS2 Sgg~,P$~ 41,645 ~TDT.PS2 AgFD.DS2 147,1~0 AFNg. F'S2 STEU.PS2 41.645 ~OF.PS2 16.375 STD'r.P82 66.000 TPHI.PS2 19.n50 SFND.PS2 22.218 8BHF.PS2 14,497 NTDT.PS2 36,034 AFF'D,PS2 537,797 AS;~D.PS2 453,730 $1GC.P$2 ]..J.~2 TRA'I'.PS2 1.551 SD$I.PS~ 19.1,62 31.059 123.506 2.910 0,454 ,IS Tape Verification I.,isti...no :chlumberger A].asKa Con, putino Center B~CK.P$~ 149.590 TCND ~S2 26232-113 TCFD,PS2 INND.:PS2 20].9,407 INFD P .... 2 PNP. PS2 208. 694 RN3. PS2 ~ ~ 6. p S 2 2231.487 R ~:7..P $ 2 R~ 10, pS2 227 3.154 RN !, I. PS2 RNI4,PS2 3865,750 ~N15.PS2 PFC,Po2~ 65.589 RF3. ~F6. PS2 7~6. 854 R~7,PS2 RFlO.PS2 921.299 RFll.PS2 R~i4.P~ 1458.337 R. F15.PS2 (;P.PS2 137. 500 DEPT. 9000,000 $Igq, PS2 'I S H 1!. P S 2 35.563 ,q, F F O. F' "- '~- ,~, ,. SBHN,PS2 41,215 FTDT,PS2 ABF~.PS2 124,035 AFN[).PS2 STBH. PS2 ,41.215 ~qOF. PS2 BAC~". PS2 171.099 FGAC.PS2 TCND,PS2 27066,652 TCFD.PS2 I ~ N ~. P S ~ 1,, 8 ~ 5.853 I t,~ F D. P $ 2 ~N2. PS2 1.60. 497 RN3. PS2 ~NF~. PS2 1792,005 R~7, PS2 R~ii0 . c, 2 1908.005 RN1 :L.PS2 RN14,PS2 3264,008 P ~",~ ~ 5.PS2 ~'"'~. PS2 41. 670 RF3. PS2 ~F6,PS2 519.315 RF7.FS2~ ~ RF10 PS2 613 735 r~Fll ms'~ RF14,. . .... " ],360 5~8 RF15.Po,~., GR.PS2 40,3~.3 DEPT. 8795.500 SIGM.PS2 ISHU.PS2 36.031 SFFD.PS2 SBNN,PS2 40.133 FTDT.PS2 A~FD.PS~ 137,223 AFMD.PS2 SIBN.PS2 40,133 8ACw.PS2 167.,490 F!;;AC.PS2 TCND,PS~ 27!50.077 TCFD,PS2 INND.PS~ ~909,306 INF'I).PS2 ~N~, P~ 178,807 RN 3, ~N6, PS2 1905. 085 R~7. PS2 RM10.PS? 19R9.310 R~ll.PS2 R~,'I ~. PS2 2991.9R6 Rt~! 5. PS2 PF2. PS2 26. 750 RF3.P82 PF6, PS~ 505.716 RF7, PS2 R~10,DS2 672.859 PFll.PS2 R~14.PS2 ~ 341,432 ,Fl 5.PS2 Gm,DS2 ]5,031 ** E'MD (]F DATA ** ! "-~'{A,R-,1 995 16:18 29,1.73 .TCAh, PS2 36579 250 9643,717 T'', SC~,P'. S2 737~438 409.411 LC01.PS2 2.1 3:I 1083.336 RN4.PS2 1467.596 !708,338 R~8.PS2 925.928 3601 ,~qOl RN12.PS2 4097,232 2453.710 ~b!~[6,PS2 1277,781 38a,890 R 4,PS2 532,.409 615,74~ RFS,P82 44a... 446 1412,041 RF12,PS2 1611 11.5 962,9u5 r~F'I6'PS2 481:483 13,632 STDT, PS2 66 000 16,064 SFND,PS2 18~483 13.~6'; ~',IT[.)T. PS 2 35.836 492.513 AEND.PS2 419.565 I..080 TRAT, PS2 1 .781 36.042 TCAN,PS2 43634.609 9296.529 TSCN,PS2 881~,154 3~3.365 LC01 .PS2 2.]48 i024.00] .RN4'PS2 1376.003 1476,004 RNS.PS2 852 002 2928.007 RNI2,PS2 3248:008 2~40.0t)6 ~['~16,PS2 1~1~ 00.3 ~57.511 RF4,PS2 3a6[~67 ~59.229 ~F8.PS~ 300.430 948.500 RF12.PS2 1188 844 ~1,8.457 RF16.P~g2 403~434 16.095 STDT'PS2 66.000 18.400 SF'NO.PS2 20.998 15.296 NTDT.PS2 36.767 495.761. ABND,PS2 456.461 1.1ql TRAT.PS2 ~..546 37.579 TCAN.PS2 38909.836 10~45.453 TSC~.PS2 7958.1,41 402.640 LC01.PS2 ~.106 !038.773 RN4.PS2 1475.939 1355.61~ R~8.PS2 838.~37 305~.146 RNI. 2.P82 3368.992 18~9.042 RIb:lb,PS2 942,516 ?b5.71.5 RF4.PS2 424,287 ~97.1q4 RFS.PS2 312.858 1~4~.574 R~12.PS2 1328.575 ~74.288 RF16.PS2 377.144 TCAF.PS2 TSCF.PS2 RNI,P$2 RN5,PS2 RNg,Ps2 RN13oP82 RFI,PS2 RF5.PS2 RFg. PS2 RFI3.PS2 T:EN$.PS2 TPM!,PS2 SBHF.PS2 AFFD.P$2 $IGC.PSP SD$i.PS2 TCAF.PS2 TSCF,P$2 RNI.P$2 RN5.PS2 R. Ng. P82 RN13,PS2 RFI,P$2 RFS.PS2 RF9,PS2- RF13,P$2 TENS,PS2 TPHI.PS2 SBHF.P62 AFFD.P$2 SlGC.PS~ SD$I.PS2 TCAF.PS2 TSCF.PS2 RNS.PS2 RNg.P$2 R~13.PS2 RF'!.P$2 R~5.PS2 RFg. P$2 RF13,BS~ TENS.PSP 17163.258 3458.734 902.780 1763,893 204 7 444,446 611.113 884.261 1722,2P7 720,O00 24.089 33 162 118: 2,208 0 340 18586i488 3'153 603 812.002 1488.004 1820.005 37~6.009 291..846 399.143 605,152 1377,686 930,000 18.673 35.588 127.758 2,375 0.432 18472.836 3778.208 794.120 !6~8,346 18~8.935 3545,463 257.143 467.144 698.573 1478.575 915.000 28 ..IS Tape verification Li. stin~ ;c..b. lumberoer Alaska Comouti. n.o.. Center 16: 1~ PAGE: 29 [).~T~ : 95/0]/ 1 ~X REC SIZE : 10P4 F'IL~f TYPE : LO b,~ST F%I,g **** FILE I?{E~DER **** FILE NAME : ~:OIT .009 SERVICE : FL!C VERSION : 001C01 MaX RFC S!Z~ : ~0P4 FILM TYPE : LO LAST FILE : FIL~ IqEADER FIL~ MUMBER 9 Ra~ CURVES Curves and loq header data .~or each pass in separate P~SS NU~B~R: 3 DEPTH INCRE~ENT: 0.5000 FILF SUM~RY VENDOR TOOL C[)DE START DCPT~ STOP bEPTH TDT 9202,5 87 6,0 LOG HEADE~ DATA ~ATE LOGGED: SOFTWARE VENSI~I~: TD DRILLKR (~T) TD LOGGE~(FT) wOP LOG IN'rEPVAL (FT): FOTTO~ LOG INTE~VAL LOGGING SPEED ~EPTH CONTROl, I~SED (YES/NO): T~L.)I, STRING (?OP VENDO~ TOOb TDT° PUGSED N El.IT Rt)!'~ TDT~ PULSED ~EUT~ON T~TP PUbSED files~ raw backoroumd pass in last ll-YEB-95 42.2 1156 916~,0 9191.0 ~00,0 91.84,0 120o.0 11-FE.B-g5 CPLC-A-795 CPI..,5- A-812 TDIC-A-816 TNC-P-14i. IS TaMe Verification ListI. nq chlumberger Alas~.a Computing Center 1.-?,AR-!!)95 ,16:18 PAGE: 3O RF~ARKS: $ # ~*OREliOLE A~,ID CAG!Na DATA []PE~ FIOI.,E BIT SIZE I)R!LLER8 CaSlN~ DEPTH LOGGERS CASING DEPTH (FT)I BOREHOI,,E CO?~DITIONS FLUID TYPE: FLUID DE~$.ITY ([,:6~/G): SURFACE ~EMPE~ATURE (DEGF) BOTTO~ HOLE TEi~tPERATURE (DEGF) F[,UID SALINITY (PPN): FI,,UID LEVEL (FT): FbUiD .RAT~7 AT ~ELL, HEA[) (BP~.~ WATER CI!TS (PCT): GAS/OTL R~TIO: C~O~g (BEG): M'EI. ITRON TOOL TYPE; (EPIT~IERHAL Ow HOLF] CORRECTION (IN): BI.~UELT~'~E C(.)Ui~T RATE NOR~1AI..,iZATION l~I Oi.L ZONE TOP ~OR~.ALIZIMG ~tlNDO~ (F'T): ~asg NORF{ALIZINC; ~;~INDOW CFT): BLUELINE COJ~T RATE SCALES SET BY FIELD F, NGIMEER FAR COI~NT RATE bOt~ SCALE (CPS)~ 0 FA~ COUNT RATE HIGH 8CAbE (CP~}; 12000 ~EAR COI. J~zT RATE LOW SCAbE (CPS): 0 ~,~EAR C0~3',: RATE HIGH SCAbE (CPS): 30000 TOOl., STA~tDOFF (IN): 9353.0 i9 E I '17 H E R S A N '" c., ':ii.' r3 ~:~ ~: . , D,.,~ .... 2°65 }iASg PASS 3 TIED INTO Z-DENSILOG 3/1/94; W.A,; Gt4 CURVE. . L, OOI<ING FOP POSSIBDF GAS CHA. N~EL PIJ,~PEP 264 BBI.,S DF:AD CRU[:'E W~i!L,E ~AWI~!G 3 BASE PASSES. ~..0 ~BI,S BORAX INTf'~ FOPi'4 PPlOR TO BOPAX PASS 1 80 a'B[.,8 ~ORAX INTO P'C)~a PRIOR TO ~ORAX PAS8 2 ~'OtJr.~D G,O,C, AT 8932' (~0 C~{A~,I~.:[, F[JI. IF~D. ~OR~X GOING PAST T[]OI.~ ;~}4EN AT TD. LIS FORe, AT DATA Tape VerifJ. catfon f, istlno ~cblumberqerAlaska ComputinO Center PAGE~ DEPT FT 500g~4 n0 000 00 0 9 1 1 4 68 8IG,~ PS3 CU 500904 00 000 O0 0 O ! i 4 6~. STDT PS3 500984 O0 O00 O0 0 q ! 1 4 68 TP}~T PS;] p[.l 500984 O0 000 00 0 9 1 I 4 68 ISHU PS3 V 5009~4 00 ()00 00 0 9 1 1 4 6~ 8FFO P83 CU 500984 O0 000 O0 0 9 I I 4 68 SWN~ PS3 CU 5009~4 O0 000 O0 0 ~ 1 1 4 6a SBH~ P83 CU 50o98~ O0 000 O0 0 o 1. 1 4 68 S~HM PS3 CU 5009~4 O0 000 O0 0 ~ 1 I 4 6~ FTDT PS3 CPS 500984 00 000 00 () 9 1 I 4 6g NTDT PSR CPS 500994 00 000 00 0 9 1 1 4 68 AFFD PS3 CPS 5009~4 00 000 00 o g 1 1 4 6g ABFD PSB CPS 5009~4 00 000 00 0 ~ 1 1 4 68 A~N~ PS3 CPS 500984 00 000 o0 0 9 ! 1 4 68 A~NO PS3 CPS 5009~4 00 000 00 0 O 1 I 4 68 6IGC PS3 CU 500984 O0 000 O0 0 q 1 1 4 69 SI5~ PS3 CTM 500984 O0 000 00 0 9 ! 1 4 68 M~Ow PS3 50o994 o0 go0 00 (') 9 1 1 4 68 TPAT PS3 500904 O0 000 00 0 9 1 1 4 68 $~$I PS3 Ct) 5009~4 O0 0oo O0 0 9 1 I 4 68 B~C~ PS3 CPS ~00984 00 000 O0 0 9 ! 1 4 68 F~Ac PS3 CPS 500984 oo ()00 00 0 9 1 I 4 6~ TCAN PS3 CPS 5009~4 O0 o0o 00 0 O 1 I 4 69 TCAF P83 CPS 500984 O0 000 O0 0 0 1 I 4 68 0000000000 0000000000 0000000000 0O00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000000 0000000000 0000000000 0000000000 00000o0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS Tape Verification L. istlno icbl~.}mberger Alaska Computln.6 (]enter T P S ~ C TCFP PS,3 CPS 5009~4 00 000 00 0 9 T:S C~ PS3 CPS 500984 O0 000 O0 0 9 TSCF PS3 CPS 500984 O0 000 O0 0 9 INND PS3 CPS 500984 O0 000 O0 0 9 IWFD P53 C ~5 50o9 LCO~ PS,] 5009~4 O0 000 O0 0 9 RN1 PS3 CPS 5009~4 00 000 00 0 g RN2 PS3 CPS 5009~4 00 000 O0 0 9 RN3 P~3 CPS 500984 00 000 00 0 9 R~4, PS3 CP~ 500984. 00 000 00 0 9 RN5 P83 CP5 5009~4 O0 000 O0 0 R ~ 6 P S .3 C P 5 500984 0 (,) 000 00 0 9 R h~ 7 P S 3 C P 6 50 n 984 00 o 00 00 o 9 RNg PS3 CPS 500994 O0 000 O0 0 q R t) 9 P S 3 C P 8 5009 ~ 4, 00 000 00 o 9 RNIO PS3 CPS 500984 O0 000 O0 0 9 RN 1. J, PS3 CPS soog~q O0 000 O0 0 g RN17 PS3 CPS 500984 O0 000 O0 0 9 g~t3 PS3 CPS 500994 O0 000 O0 0 9 RNla, PS3 CPS 500984 O0 000 O0 0 9 RN15 P83 CPS 5009~4 O0 000 O0 0 9 R~16 P83 CPS 500984 O0 000 O0 0 RFi PS3 CPS 5009~4 O0 000 O0 0 RF2 PS3 CPS 5009P4 00 000 00 0 9 RF3 PS3 CPS 500984 00 0o0 00 0 g RF4 PS3 CPS 500984 00 000 00 o g RF5 PS3 CPS 5009~4 00 000 00 0 9 RF6 PS3 CP~ 500984 00 000 O0 0 o R~7 PS3 CPS 5009~4 O0 000 O0 0 g [{F8 PS3 CPS 500994 O0 000 O0 0 9 RF9 PS3 CPS 500984 O0 000 00 0 g g~10 PS3 CPS 5009~4 00 000 00 0 9 NFl! PS3 CPS ~009~4 O0 000 O0 0 RFlP P83 CPS 500994 O0 000 O0 0 9 R~'13 PS3 CPS 5009~4 nO 000 O0 0 9 RP'I~ PS3 CPS g009~4 O0 000 O0 0 9 RFI~ PS3 CPS 5009B4 oO OOO O0 () 9 R~16 PS3 CPS 500994 O0 000 00 0 9 TENS P83 bg q009~4 O0 000 O0 0 9 R , iT ,.,,E.<V C AP,! API API FI.,, N ~'!t5 NU}~ D oRr;'t{R ~, Ii,fOG TYP~ CLASS ~,IOD ~,i[.i~E,~ ,..5;A,~,~P EbEM CODE 1 1 6 ~ 0 00 l 1 4 68 0000000000 ! ',!, 4 68 0000000000 1. I 4 68 O000OO0000 I i 4 6 [~ 0000 (,) 00000 1 1 4 68 0000000000 1 I 4 6 ~ 00 () 0000000 1. 1 4 68 0000000000 1 I 4 68 0000000000 ~, 1 4 68 0000000000 1,, 1 4 68 0000000000 1 1 4 68 0000000000 1 t 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 1, I 4 68 0000000000 1, 1 4 68 0()00000000 I 1 4 68 0000000000 1, I 4 68 O0000000OO 1 I 4 6,~ 0000000000 1 1 4 61t (}000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 6~ 0000000000 !, I 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 00000o0000 1 1 4 68 0000000000 1. i 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 6fa 0000000000 1 1 4 6f~ 0000000000 1 I 4 68 0000000000 ! I 4 68 0000000000 ! 1 4 68 0000()00000 1 1. 4 6~q 0000000000 ! 1 4 68 00(.)0000000 ** D.~TA ** STDT.PS3 66.000 TPHI.P$3 8FNO.PS3 0.000 SBMF.PS3 HTDT.P$3 0.000 AFFD.P$3 l~!~i).P$3 0.000 SIGC.DS3 TRAT.PS3 0.000 SI)SI.PS3 0.000 0.000 0.000 0.000 0.000 ¸32 000'0£6 6gg'6SEt E~S'LL~ ~89 ~9E'§T8 8LE'E£L[ 0L/'9o98I t '[8' i 98 E ' e '[ T 6T~'9g O00:05L EL~'SOL OE~'.Tg§ 8§8'[LC 6'[L'~fOg 06Z'~6~t 6~8'g88 000'0 000'0 [gd'gTNH' Egd'ODig Egd'qA~V E~d'l~dlL fgd'~VD~ faO!~§'[T iga'~T,Aa [09"~L6 £08 OOi 6Lg'618 C~d'Si',iH figP'~9fI LE~'E Egd'TOOq ~'[~'~L£ TSg'L~O6 CSd'NDgi 6C~'0696 L6E'L99~ Cgd'N~DZ LLE'9£ 8[8''[ gO9ig£~ [gd'ONiil~ 8gg'SL~ 8gO 8T £~d,"G~'~S'W 6@0'9t 000 99 LSg'~6E L98 EO0 006 9PI LS:~I 000 0 000 0 000 0 ~L~'9[ ESd'LA~t '~00'9~S [~d'i.d~ aOE' T[ /Sd'GaD& L~6'T6ZgE fgd'ONOi iSa'ii,Aa EO0'06gl CSd"LNS. ~[~'l'90~ [ga 9aa [¢d'Oa~l 000'0 fgd'OSD,L C>O0'O ,IS Ta~e Ver!.~'ication I, istir:,q ;chlumberoer AlasKa Comptltin~, Center ~ -~.~AR-1995 16:~8 **** FILE T~AI!,EP **** FILE NA~E : EDIT ,009 $~RVICE : FL!C VERSION : O0~,,C01 DATE : 95/03/ 1, MAX REC SIZE FILM TYPE: : b~ST FILE **** FILE HEADER ' **** FILE NAME : EDIT .010 SE~VICE : EL!(] VERSION ~ 001. C01 [:,,~TE : 95/03/ 1 MAX REC SIZE : 1o24 FILE TYPE : bAST FILE : FI'LW ~IEA[)ER FILE NU~4[)ER 10 RAW C[IRVES Curves and loq header data [or each pass in ser~arate PASS NU}~BER: 4 DFpTH tNCREME~tT: FTbF SUMMARY VENDOR TOOL CODE 'START DEPTM STOP DEPTH [,~G NEADER DATA DATE LnGGED: S[]FTWA~E V~]RSION: TI~E {.,OGLER ~N BOTTO*~: Ti, DRILLER (ET): · D LOGGKW(FT): T(,'.IP LOG INT~PVAL FOTTOM L~G I~TE~VAL (FT): LOGGING SP~iED (FPHR): DEPTH COI,~TFOL USED (YES/NO): TOO[, STPlNG (mOP TF] ~OTTO~) VKNDOP ~OOb CODE TOOL TYPE: TDTP [J . NEUTRON TUTo PI~bSED NEUTRON TDTD PUbSED NEUTRON TDTm PULSED NEUT RO~',~ TDTP PULSED TDTP PU~SEr~ N EtJTRO~ raw bacKqrouDd pass in last fl 42.2 1. 24,5 9].88.0 91 91 .0 8RO0.O 9!84.0 !200.0 ll-FED-g5 Tame V'erlficatl, on Listlno ;chlumberger AlasKa Comput.in(~ Cent;er TD. TP PULSED $ DRILLERS CASING DEPTH (FT)~ LOGGERS CASING [)~PT.~,~ (FT): BO~EHOLE CONDITIO~S FLUID TYPE; FLUID DENSITY (LB/G): SURFACE TE!~PERATUPE (DEC,F); 80T'TO~ HOLE TE~PERATUE'E (DEGF); FLUID LEVEL (FT): FLUID R,aTE a':'[' WELbH~EAD (bP.M); ~ATER CI~TS (PC'F)~ GAS/OIL R.aTIOI CHO~E ([)EG): NEIITRDN TOOL TOOL ~YPE (EP~T~4F.:~,~L OP MATRIX: MATRIX DE:NSI~"Y; HOLE COPRFC~ION (!N): BL[JE[~INE COUNT RATE; NOR~'~ALiZATION 1N OiL ZONE TOP NO~.a. LIZI~!G WINDO~ ( BASE NOR~,~AI.,iZI'MG t~N[)[.)~ (FT): B I,IJ.E [, I N E. CouNT. RA!'.' 'E .... SC. a L F: S' S~,.[""' ~Y. F.I ~q L b. E'~'~ G I ~:~ E E R FA.~? COUNT RATE HIGH SCALE (CPS); NEAR COUNT RATE: [,OW SCALE (CPS): NEAR COUNT RATE HIGd SCALE (CPS): TaG-P-236 9353.0 N E I THER SANDSTONE 2,65 0 1200 0 O 3oo00 TOOL STANDOFF (IN): ,.BORAX PASS ! TIED .INT[I Z-DE~',JSI!.,OG 311/94; W.A.; O~ CURVE. ~O()KING FOR P[)SSIBL? GAS C!.{~r:*~!Lb & PU~,lPED 264 ~[~LS DEAD CRUD;I w~l].~ ~,~AKING 3 iL~ASE PASSE~, ~0 BBl._.5 P~O!{~X INTO FOR~'-I PRIOR 'i0 BORAX PASS 80 ~BLS i~DRAX IldTO ~[)~I P~IflW To BC)~A~ PASS 2 ~'OUND G,O,C, ~T 8937' NO CHAf'.~;,~E[, Ft')U~F), ~OR~X GOI~,~G PAST Tf~OL S FORe'AT D~TA PAGE: 35 ,,iS Tape Verification Listing ;cblumberqer Alaska Computing Center PAGE: 36 ** ~ATA FORMAT SPECIFICATION V,'ECOI~D ** SIG~" PS4 STD? PS4 TPM! PS4 ISHl! PS4 SFFO PS4 SFND PS4 SBHF PS4 FTDT PS4 NTDT DS4 AFFD PS4 A~F~ PS4 AFNP P$4 ABN~ PS4 STGC PS4 S~BP PS4 M~OV PS4 T~A? S~Sl PS4 FBAC PS4 TCAN PS4 TCAF PS4 CU 500984 O0 g00984 O0 PU 500984 o0 v 5009n4 O0 CI! 500984 O0 CU 500984 O0 CU 500984 O0 Ct) 500984 O0 CPS 5009~4 0(.) CPS 500984 O0 CPS 5009aa O0 CPS 500984 O0 CPS 500984. O0 CPS 5009~4 oO CU 5009~4 O0 Ct} 500984 O0 5009~4 O0 5009~4 CU 500984 0() CPS 5009~4 OO CPS 5009~4 O0 CPS 500984 O0 CPS $0098~ O0 000 O0 0 000 00 0 000 OC 0 000 O0 0 000 O0 0 000 00 0 O00 O0 0 OOU O0 0 000 O0 0 000 o0 0 000 O0 0 000 (') C) 0 000 O0 0 000 0() 0 000 00 0 omo oo o 000 00 0 000 00 0 O00 O0 0 O 00 00 0 00 (: 0 0 000 00 0 000 0 O o 10 1 1 4 68 0000000000 10 1 1 4 68 0000000000 !0 1 1 4 68 0000000000 10 1. 1 4 6~ 000000000o lo 1 1 4 68 0()()0000000 10 1 1 4 68 0000000000 10 I I 4 6~ O000000000 10 1 1 4 68 0000000000 10 1, 1 4 6q 0000000000 10 1 1 4 6a 0000000000 1,0 1 1 4 68 0000000000 10 1 1 4 6~ 0000000000 !0 1 1 4 6~ 0000000000 10 1 1 4 68 0000000000 10 1 1 4 68 OOOO000000 10 1 1 4 6a 0000000000 10 1 1 4 68 0000000000 10 1 1 4 6~ 0000000000 10 1 1 4 68 0000000000 lo 1 I 4 6n 0ooooo0o00 !0 1 I 4 6~ 0000000000 lO 1 1 4 68 0000000000 10 1 1 4 68 0000000000 ,I'$ l'ave Verification [,isti..r,c :chl. umberger AlasKa Computin~ Center 9,.05 NAN{F V T ....... PI APl P ..... TD £]RDEIr~ ~t bOG TYPE (,'.LAGS, TCND PS4 CPS 5009~4 TCFD PSi CPS 500984 TSCN PS4 CPS 500984 TSCF P84 CPS 500984 INND PS4 CPS 5009~4 INFD PS4 CPS 500984 bC01 P$4 500984 RNI PS4 CPS 500984 RN2 PS4 CPS 500984 RN3 PS4 CPS 500984 RM4 PS4 CPS 500984 RN5 PS4 CPS 500984 RM6 PS4 CPS 5009~4 R~7 P$4 CPS 500984 RN8 PS4 CPS ~009~4 RN9 PS4 CPS 500984 RNIO P$4 CPS 5009~4 RNll P54 CPS 5009~4 RNi? P$4 CPS 500984 RN13 PS4 CPS 500984 RN'14 PS4 CPS 500984 [{N15 PS4 CPS 500984 RNI6 PS4 CPS 500984 RFI. PS4 CPS ~00984 RF2 PS~ CPS 500984 RD3 PS4 CPS 500984 RF4 PS4 CPS 500984 RF5 PS4 CPS 500984 RW6 PS4 CPS 500984 ~F7 PS4 CPS 5009~4 RrB PS4 CPS 500984 RF9 P84 CPS 500984 RFIO PS4 CPS 500984 RFI! PS4 CPS 500984 ~F12 PS4 CPS 500984 RF13 PS4 CPS 500984 RF14 PS4 CPS 500984 RF15 PS4 CPS 5009~4 RFI6 P$4 CPS 500984 TFM$ PS4 bg 5009~4 00 000 00 0 10 00 000 00 0 10 1 1 00 000 00 0 00 000 00 O 10 1 1 00 000 00 0 10 I. 1 00 000 00 0 10 1 1 00 000 00 0 10 1 1 O0 000 O0 0 !0 00 000 00 0 ! 0 1 1. 00 0 o 0 00 0 10 ]. .1 00 000 00 0 1 (.) 1 1 00 000 00 0 10 1 1 o 0 0 o 0 00 0 10 00 000 00 0 10 1 1 00 000 0 () 0 10 1 1 O0 000 O0 0 10 1 00 000 00 0 1, 0 1 1 O0 000 O0 0 10 1. 1 O0 0o0 O0 0 10 1, 1 O0 000 O0 o 10 1 .1 00 000 00 0 10 1 1. 00 000 00 0 ,1,, 0 ,!, 1, O0 000 O0 0 10 1 00 000 00 0 10 1 1 00 o 00 00 O 10 1 1 O0 000 O0 o 10 1, I 00 000 00 o 1, 0 1 I 00 000 00 0 10 i 1 00 00 t) 00 0 ! 0 I 1 0 0 0 0 0 0 0 O0 000 O0 0 10 1 1 O0 000 O0 0 1, 0 1 1 00 000 O 0 0 10 1 1 O0 000 O0 o 10 ! 1 0o 0o0 O0 0 10 1 1 O0 000 O0 0 10 1 1 O0 000 O0 c 10 1 1 O0 000 O0 O0 OOO O0 0 10 1 1 4 68 0000000000 4 6~ 0000000000 4 68 0000O00000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 68 0000000000 4 68 0O00000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 68 0000000000 4 68 0000On0000 4 6n O000OO0000 4 68 O00OOOOO00 4 6~ 0000000000 4 6F 0000000000 4 68 0000000000 ** DATA ** DEPT, ISHI~,P$4 GRH~Y,PS4 ARFD.PS4 9202,500 SIGM.PS4 i6.292 46,063 SFVI.).PS4 16,7a6 SFNO.PS4 a0,775 FTDT,PS4 6.d16 NTI)T,PS4 6b.402 ~FND,PS4 296.900 128.463 ~OF.PS4 !.133 TP~'.r. PS~ 66,000 IPHI,PS4 17,047 SBHF,PS4 15.956 AFFn. P84 263.222 STGC.P$4 1,~37 SDSI,PS4 35.384 75.174 66.838 0.143 0,398 37 000'0£6 fO0'OgOI ~Lg'L86 L~§'~LL ~8~'89L 9~L'~ELEI 06g'O OEt'O O00'§L6 g[8'L68 q9f'O~£ 9LS'O~g @61'6LE 68L ~£0"[ 968'Pggg 60g'O 0~P'99 O00'OEL £S8'L~L 8LI'ggE tO~'PLOI 668'E98 £SS'L~L L88'80L8 ~d'SNMZ L89'88E PSd'E[aS' gEL~OOL ~gd'g'[Aa EL6["[P~ ~d'6Aa 86l 6LE P~d'SA~ [g9 ~6~ ~Sd'6~a 6[71'~g@ ~gd'a~8 OfiE'i98 ~d'~ 90t,L06 ~d*~Na: :~SL'6L8 ~9~'tN~ ~I"[i g ~Sd'lOOq 809'9Z£ 9~d'~V'D& £90 '[8~Og ~gd'DDI~ 89~'0§~ P~d'Oa~' EPO'a'[E ~gd'll;td,~ 000'99 ~Sd'a;Oi;g ~Sd',HVD~ 9E6!EL£ ~19 8P9 9gE [,:E90g~l 8t8 ~891 OEg'~L~tg P~d'E'IAH EL6'68'V ~9d*9[:g~ P~d'¥N8 E~g'868 ** ¥£VU aO (IN~ ~6S'S~ ~gd'aD ~gd'S[,da g60'68I'[ ~d'L~a £8I'BEE ~d'[.t8 999'§E ~gd'ItNa O£L'EE6 fSd'Otl~e:! PSd'LNh 6gL'gL8 ~gd'gNa P'~d't]AN~ ~[L'SgS[ ~Sd'aNNI fWd'(]AO& IL6'96~'I ~gd'dNO~ P S d ' q A A o ' ~, · ., 69P t~ 9d ~'Sd'14DI9 00S'E688 EOL'O[ ~gd'gtd~i 086'896 ~Sd'/[,aa g~6'£[£ ~gd'OIa8 VSd'[:aa ~98'E~ ~'gd PSd'§'[Nd ~Lg'L6~E ~9d'~ta8 ~Sd't[Na 9L§'§90[ ~gd'OIN~t ~Sd'LNa £L01686 ~d'9aa PWd'CN'8 0[9 ~t~'[ Pgd'~Na ~9d'rlSNi LSS'~6/~ ~9a'~aaI ~9d'<laD~ LOI:'L86~; ~gd'D~qS 'Pgg'Eog Pgd'ON,,~V £0E':~9 ~gd'&ClilA 6BP'g8 ~9<t'daAS lES'IV ~d'¢i~I¢ 000'0006 Y, sd S~,,Ja 6V~ 9~L ~Sd'LA8 gLO SLi ~9d'gAa ~gd'IIN8 ig§'[EOI ~gd'OINa ~o'aaa f~L'g96 ~9d'gaa ~Sd*QANI ~g~'918'[ ~Sd'QNNI ou'['~s~'q uor,':l, eol:~'t:'.za^ acle..~ 0 ' 00 g 0 ' '~ 8 '[ 6 0'0088 6'I6'~6 0'88[6 ~ ~Set u'l: ssed puno~bMo~q ~;1 :s@t!~ 6E :3DVd ~uIls['l uo'~eo'[~t~oA aue& ~I ,,IS Ta~e Ver1.~ication t, istinq ;chlUg~berger Alaska Computlnq Center 1-NAR-1995 16:18 TDTP BOREHO[,E AND C.A~5!NG DATA OPEN }lObE BIT SIZE (IN): DRILLERS CA~'I'DG DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FL[lID TYPE: FLUID DENSITY (LB/G): SURFACE TF:MPERATURE (DEGF): BOTTO~,~ HOLE TFMPERAT[JR~; (DEGF): FLUID S.ALIN!T~ (PP~4); FLI,iID LEVEL (FT): FbUID R,.~TE AT ~ELbHEAD (6Pt'~); W~TER, CUTS (PC'r): CHOKE (DEG)I NEUTRON TOOb TOOL mYPE MATRIX: ~ATRIX DENS"rTY: }lObE CORRECTIOi>~ (][~): T N d - P - 236 9353.0 BORAX ~ ATER S A N D $ 'T O N E 2.65 Bt, UEb.T. NE C('.'IIiNT RATE NOR~4ALIZATI[~N i'¢,' OIL ZONE TOP NORN~,A. LIZING WI'~,}DC~ (FT): BASE NOR~4AL1ZING WINDI'3W (FT): Bt, UE[,IME C.OONT RATE' SCAt, ES 5ET BY FIELI'> FA~ COUr4T RAT~,; l,,O~ S. CALk; (CPS): ~AP COUNT RATE HIGN' SCabE (CPS): 12000 NEaR COUNT RATE LOW .... CAk, E (CP~) ~E.aR COUMT R~TE HIGH SCALE (CPS : 3000() # TOOL STAMD~FF BIN): INTO Z-I)Ei~SII,OC 3111041 w.A.: GR CURVE, ~OOK'ING FOR PI"iSSIBLE GAS CtqA~:t",iE6 g NEw G,O,C. PU~'~PED 264 BBLS DEAD C[{IIDF. qHI[.,E t4AKI. NG 3 BASE PA.SSES, .~o 1~!4L5 6ORAX IN[i'~ FORM PPI. r~R 'I'O BORAX PASG 1 80 BHL$ BORAX I~TT['() FOP,~'~ F'[~Ir~R ~'O BOPA7, ['ASS 2 ~fli.JMD G.O.C. AT 8932' $ LIS FflRMAT DATA PAGE: 40 Verification LiSti. n~ ;chl, umberger Alaska Computin0 Center 41 ** DATA FOR~IAT SPF. CIFICATION PEC[tPD ** ** SET TYPE ,,, 64EP, ** I 66 0 2 66 0 4. 66 ~, 5 66 6 73 7 65 ~ 6~ 0.5 9 65 M!l' .Il. 66 3 17 6a 1.3 66 0 1~. 65 PT 15 66 68 16 66 ~ 0 66 1 S?G~" PS5 STDw PS5 TPMT PS5 ISHU PS5 SFF~ PS5 SBHr PS$ S~H~! PS5 FTDT PS5 NTDT DS5 AFFP P55 AqFD PS5 AFND PS5 ABN~ PS5 S!GC PS5 STFu ~S5 N~OW PS5 TRAT P85 sfaS? 5~C~ PS5 FBAC PS5 TCA~3 ~S5 TCAW 5009~4 O0 000 O0 500994 O0 000 O0 500984 O0 000 O0 V 5009a4 oo cu 5009~4 O0 CU 5009~4 O0 CU 500984 O0 CU %009~¢ O0 CPS 500984 O0 CPS 5009~4 O0 CmS 500984 O0 CPS 500994 O0 CPS 500984 O0 CPS 500984 CT, 5009~4 OO 5009~4 00 500994 o0 CU 5009~4 CPS 5oo9~4 O0 CPS ~009~4 o0 CPS g009g4 O0 CPS 5009~4 o 11 1 1 4 68 0 !1 1 I 4 68 0 11 1 1. 4 6~ 000 00 0 11 1 1 4 68 000 O0 0 11 1 I 4 68 000 O0 0 1! 1 1 4 68 000 O0 0 11 ! 1 4 69 000 O0 O 11 1 I 4 6a 000 O0 O 11 1. 1 4 68 000 00 0 !1 J. I 4 6~ 00() O0 0 1. l. 1 1 4 69 000 O0 0 11 1 1 4 6a 00O O0 O 11 1 I 4 68 000 O0 () 1I ! 1 4 69 000 O0 (~ 1 i 1 1 4 b8 009 00 <) ~ ! ! 1 4 6~ 000 O 0 ~: '1 I I 1 4 6 ~ ooo oo ~ !. 1 1 1 4 6a O0o O0 (~ ! 1 ! 1 4 69 000 O0 ~' 11. 1 1 4 6~ 000 nO ~" 11 ! 1 4 0~ 000 O0 :~ 11 1 1 4 68 000 O0 ~! !! 1 I 4 6~ 0000000000 O0000000OO 0000000000 0000000000 0000000000 0000O00000 ooooooooon OOt, O000000 0000000000 0000000000 0000000000 O000000OO0 O000OO0000 OOO0000000 OO0000000O Oc~CO000000 O000OO0000 0000000000 O000OO0000 O00Ot}O0000 0000000000 0000000000 0000000000 :,l$ Tare ver.~.flcation I~isti. nq ¢chlumberqer A!~s~a ¢::OmPUt:Inq Cent:er J-l',;AR-1995 :i6::1;3 PAGE: 42 N a M E S K R V UNI ICKT S E ~ V A P 'I ! P .1.: ~ P I 'ID ORDER ~ hOG TYPE: TeND ,$5 5009~. C}O TCFD PS5 CPS 5009~4 O0 T,q C ~'~ PS5 C~S 500984 oo 0o0 O0 0 TSCW PS5 CPS 500984 oO 000 O0 I ~'~':{ D PS5 CPS 500984 O0 000 O0 INFn PS5 CPS 500984 O0 0o0 O0 LCO1 PS5 500984 oo 000 00 R N 1 P S S C P S 5009 ~ 4 00 00 (J 00 R~2 PS5 CPS 500984 O0 000 O0 0 RN] PS5 CPS 500984 O0 000 0(,) 0 R ~ 4 P S 5 C P S 5009 B 4 0 o 000 00 R :~ 5 P S 5 C P S 500984 00 000 00 R ~:~ 6 P S 5 C P S 5009 R 4 00 000 00 R N 7 ~ S 5 C [~ S 500984 00 000 00 ~'~ R~'8 PS5 CPS 500984 O0 000 O0 R ~ 9 P S 5 C P S 500984 00 00 O o RNIO PS5 CPS ~;0098,! O0 000 O0 R~31~ PS5 CPS 500984 O0 000 O0 R~IP PS5 CPS 500984 O0 000 O0 RN1] PS5 CP6 500984 O0 000 O0 0 R~'1~ PS5 CPS 5009 ~,4 O0 000 O0 0 R*'~ 15 PS5 CPS 5009q4 oO 000 O0 0 RNI6 ~S5 CPS 500984 O0 000 O0 0 R F 1 P S 5 C P S 500984 00 0 (,) 0 0 () 0 P. V2 PSS CPS ~00984 O0 O00 O0 0 RF3 ~85 CDS 5009g4 O0 000 O0 0 RF4 P85 CPS 500984 O0 000 O0 0 R~5 PS5 CPS 500984 O0 000 O0 RF6 PS5 CPS ~00984 O0 000 O0 0 RF7 PS5 CPS 5009~4 O0 000 O0 0 RF8 mSS CPS 500984 O0 000 O0 (') RF9 PS5 CPS ~009~4 O0 o00 O0 0 RFIO PS5 CPS 500984 O0 000 RFI~ PS5 CPS 500984 O0 000 O0 0 RV12 PS5 CPS 5009~4 O0 00() O0 o ~F13 PS5 CPS 500984 O0 000 O0 RFI,~~ PS5 CPS 500984 O0 000 00 0 ~F 1., 5 PS5 CPS 500984 OO 000 O0 0 RF'I& PS~ CPS 500984 o0 000 O0 00 0 0 1 000 00 o I~ I 1 4 68 0000000000 1 1 I 4 68 0000000000 ! 1 I 1 4 68 0000000000 1, 1 I I 4 68 OOO0000OO0 11 1 I 4 68 0o0o000000 11 1 I 4 68 0000000000 1.1. I I 4 68 0000000000 11 1. I 4 68 0000000000 11 1, 1 4 68 0000000000 Il 1 I 4 68 0000000000 11 1 1 4 68 0000000©00 11 1 I 4 68 0000000000 11 I I 4 68 0000000000 1.1 I 1 4 68 0000000000 11 I I. 4 68 0000000000 11 1 1 4 68 0000000000 11 1 I 4 68 0000000000 ~, 1 1 I 4 68 0000000000 11 t l, 4 68 0000000000 1. 1. 1.. I 4 08 0000000000 11, 1 1 4 68 0000000000 11 1 I 4 68 0000000000 11 1 1 4 ,68 0000000000 11 1 1 4 68 0000000000 1.1 1 1 4 68 0000000000 11 1 1 4 68 0000000000 11 1 1 4 68 0000000000 1! 1 I 4 68 0000000000 1.1 1 1 4 68 0000000000 1.1 1 1 4 68 0000000000 I1 1 1 4 68 0000000000 11 1. 1 4 68 0000000000 1.1 1. I 4 68 0000000000 11 i 1 4 68 0000000000 11 1 1 4 68 !.1 l 1 4 68 O000000OO0 !1 1 I 4 68 O00000000O 1.1 1. 1 4 68 0000000000 1! 1 1 4 68 0000000000 oooooooooo £ ooooo ! mm m~mmmmmm~ DJ:PT. q203.000 S,IC~.PS5 ISHII,PS5 43.031 SFFD,PS5 SBN~,':.PS5 ~8.486 ST. BW.PS5 1a1.174 ~r4~lF.P$5 17.215 17.537 6.543 1. 096 STDI'.PS5 66.000 TPHI.PS5 SF'NI), PS5 17.89~ SBHF.PS5 ~T~)T. PS5 15. 124 A['FD. PS5 ABNO.PS5 255.385 SIGC.PS5 TI~AT. PS5 !.705 SDSI.PS5 31,655 70.642 71.079 0.I04 0.439 Tape Yerificat.ion I.,istlr~q .~chlu~l~berger AlasKa Computing Center BACK.PS5 244,281 TCND,PS5 12392,1~1 TCFD,PS5 INND,mS5 1783,304 ~NT, PS5 272,793 ~.{3, PS5 RN6,DS5 861,113 RN7,PS5 RN~O,PS5 944,447 RN14,PS5 ~773,153 ~"~, DS5 53,664 RF3, PS5 ~F~, PS5 277. 778 RF7, PS5 RFIO.PS5 3~4,8!6 RFII.PS5 RFI4,PS5 685.1~7 9f'~5,PS5 G~,PS5 1~1,938 DEPT. 9(,)00. 000 SIG~.PS5 ISM!I.PS5 41,563 SFFD,P,$5 SCM~.~,PS5 79,8.39 FTDT,PS5 ABF'D, PS5 61,819 AF~I'), PS5 SIBM,PS5 12().5~6 MMOF,PS5 BAC~,PS5 199,B52 FBAC,PS5 TCND,¢S5 1.4879,0~0 TCFD,PS5 INND,PS5 ~ 673. 192 INFD,PS5 ~N ~, PS5 178. 655 RN'3, PS5 ~N6,PS5 I 0~1.860 RN7.PS5 R[~iO,PS5 1136.615 RNII.PS5 R~'I4.PS5 2387.9~1 RN15.PS5 ~F'2. PS5 29. 722 RF3, PS5 DF6, PS5 300. O01 RF'7. PS5 RFI0,DS5 343.63'! RF11 ,PS5 RFI4,PS5 905.457 ~F15,PS5 GP,PS5 38.6~5 DFP, T, 8g¢3.500 8Igg. P85 ISHI~.PS5 44.063 SFF[).P85 SBHt~,PS5 O5,50-i FTDT,PS5 ABFD,PS5 Q3,016 SIB~,PS5 179,594 BACK.PS~ 200.295 FGAC,PS5 TC*OD. PS5 15268.674 TCFQ,PS5 IMl~Jn, PS5 ! 811 .042 I{~FD. PS5 ~N?,PS5 169.414 RN3.PS5 ~N6, PS5 900,002 R~7, PS5 RN10,P~5 905,457 Rall.PS5 RN14.PS5 2645.461 P~'~, PS5 35. 666 RF3. PS5 ~f'6, PS5 370, OO 1 Rm7. PS5 RF'I4. PS5 15a0.0C4 ~ 5.P85 GP. PS5 41.8 ! 3 DATA ** ~.-~AR-!995 1,6:18 ,1. 15.4~,j 'rca ~;,. PS5 19203 n9.1, 4395.07n TSC!~,:I. PS 5 3840~566 359.9"16 L, CO,1.P$5 2.~64 893,521 RN4,PS5 958,336 ~(.15.558 RNa,PS5 828,706 1259,~6~ RN!2,PS5 1606.486 1537.04! RN16,PS5 1.180.559 217,593 ~F4,PS5 2q5,371 ~50 Ot,~] RFS,,.S,:~ 310 4,45 47~.~;~53 RF12.PS5 592~594 57'}.,~. 7 u 5 RF!6.PS5 328.705 i 4.0 o 6 S T P',r. P S 5 66.000 i,!.126 SFND,PS5 15.468 7.~5e NTDT,P$5 18.5'16 33~>.073 A. BNO.PS5 246.014 · .i .~70 TRAT,PS5 1,694 .3~,367 TCAN,PS5 :20386,707 5574.746 TSCN,PS5 5458,346 ~33 ~.. 273 L C 01 · P S 5 2. ~ 59 8C~3.390 RN4,PS5 972,680 ° {~ :'i 64.1, RNS,PS5 852.461 167?~135 R?~12.PS5 2098.366 19'72.682 PN16,PS5 1120 221 1 ~': q,,'. O00 RF4..PS5 223~637 3it'.glO RFS.PS5 278 .1,82 5~5.456 RF'I, 2,PS5 709.093 736.365 RF16.PS5 3B7.~74 lO,409 ,STDT, PS5 66.000 I {,~. 576 SF~<~O. PS5 !1.506 ,~, {'~. ?. 33 ?~! TD'i". P $ 5 16.051 ~ .189 TRAT.PS5 !.205 37.006 TCA~.PS5 23795.297 825~.512 TSCN.PS5 6340.192 35g.0~3 [,CO1 .PS5 9a7.~75 RN4.PS5 932.730 927.275 RNa,PS5 818 184 1~e:1.82~ RN12.PS5 1876~36~ 231F:. I {{8 ~NI ~.PS5 1451~ 822 25~. () (.} .1 RF4.PS5 330,001 415. OO 1 ~["~. PS5 275. O01 615.0i)~ R?'12.PS5 880.002 136C..0t;3 RF'I~.PS5 765.002 TPMI,P$5 SBHF,PS5 AFFD.PS5 $IGC,PS5 SDSI.PS5 TCAF.PS5 TSCF,PS5 RNI.PS5 RN5.PS5 R.Ng.PS5 RN13,PS5 RF1,PS5 RF5,P$5 RFg.PS5 RF13oP$5 TENS,PS5 TPHI,PS5 SBHF.PS5 AWFD.PS5 SIGC.PS5 SDSI,PS5 TCAF.PS5 TSCF.PS5 RNI.PS5 RN5.PS5 RN9.PS5 R~I3.PS5 RF1.P85 RFSoPS5 RFg.P$5 RW 13. P55 TEh: S. PS5 PAGE: 81.807 ~6 268 796,298 861.113 t032.410 1805,560 259,260 259,260 319,445 657,409 740,000 27,063 59.724 72,964 0,246 0,436 9442,707 2528,194 754,~00 863.390 1027.325 2404,377 218.182 245.455 3~1.819 938.194 950,000 10,177 69,238 89.939 0.068 0,239 16504,152 4397,487 763,638 840,002 943.639 2405,460 230.001 305,001 395.001 1250.0(!3 [,iS Tar,.>e Yerification I..ist.inq Schlumberger AlasKa Co,'.p!lt,~,n~ Center PAGE: 44 FILE biA, t~E : ~;1)IT .011 SERVICE : Fb!C VERSION : O01COi D~TE ~ 95/0.3/ 1 M~,X t"~EC SIZE : 1.024 FILE TYP~ : [,.0 b l 8'r F I b E : **** TRPE TRAIl, ER **** S~RVIC}~fl NA!gE : EDIT D~,TE ,' 05103/ l OPlGIM : MLIC TIP~'; NAaE : q5058 CONTI, NUATIO~ ~ ~ 1 P~EVlOUS ~A~E : CO~.!M~;NT : ~aCO ALASK~ It~IC., D8 ll-O~tA, PRtiI'.)HOE ~AY, APl 50-029-20480-01 **** REEL TRA I!,EP *~** SERVIC~ NA~,,t.F.. : EDIT D,~TF RFE[, ~'A~E : 95058 CONTINUATIOM ~ : PREVIOUS CO~!uEMT : ~RCO ALASKA INC., DS l~-04a, P~'~UDFIOE BAY, API 50-029-20480-01 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6164.00 R. ECK NEWSOM/LEARY REMARKS: OPEN HOLE D.S. 11 - 04A 500292048001 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 14-MAR-94 RUN 2 RUN 3 33 liN 15E 54.52 54.52 28.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7786.0 8.500 9355.0 Y 5951120, X 707562.80 DLL/ZDL/CN/GR. CIRCULATION STOPPED AT 16:30, 01-MAR-94. SURFACE LOCATION: DID NOT LOG BACK UP INTO CASING DUE TO A DOGLEG JUST BELOW WINDOW. TEMPERATURE INSTRUMENT WAS VERIFIED WITH TWO MAXIMUM READING THERMOMETERS. ALL THREE READ 170 DEGF. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. THE REPEAT PASS WENT SLIGHTLY FURTHER UP-HOLE THAN MAIN PASS. THE TOP PORTION OF THE REPEAT PASS WAS SPLICED ONTO THE MAIN PASS FOR COMPLETE DATA COVERAGE. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; depth shifted and clipped curves; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 8410.0 9289.0 8462.0 9341.0 8435.0 9314.0 8466.0 9296.0 GR (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH all runs merged; no BASELINE DEPTH LL3 RHOB NPHI 8384.0 8384.0 8384.0 8384.0 8447.0 8446.5 8463.5 8463.0 8469.0 8468.5 8468.5 8472.0 8472.5 8472.5 8473.0 8475.0 8475.5 8478.0 8478.5 8487.0 8486.0 8487.0 8487.5 8487.5 8490.0 8489.5 8493.0 8493.5 8499.5 8500.0 8500.0 8500.5 8506.0 8506.0 8518.0 8518.0 8518.5 8518.0 8518.5 8530.5 8530.5 8530.5 8545.5 8545.0 8546.0 8546.0 8545.5 8550.5 8551.0 8561.0 8560.0 8561.0 8583.0 8583.0 8583.0 8583.0 8598.0 8598.0 8598.5 8598.5 8598.0 8600.0 8600.0 8614.5 8614.0 8620.5 8620.0 8620.5 8631.0 8631.0 8632.5 8632.0 8632.5 8649.0 8649.0 8649.5 8649.5 8651.0 8650.0 8657.0 8657.0 8657.5 8663.5 8663.0 8664.0 8663.5 8664.0 8676.0 8676.0 8695.5 8694.0 8696.5 8696.5 8700.5 8700.5 8704.0 8707.0 8709.0 87.1.3.0 8713,5 87!7.5 8718.0 8720.0 8720.5 8726.5 8729.5 8732.0 8734.0 8734.5 8735.0 8743.0 8760.0 8766.0 8768.0 8777.5 8778.0 8786.0 8796.5 8805.0 8807.0 8810.0 8810.5 8812.5 8815.5 8816.0 8821.0 8821.5 8826.5 8839.5 8841.0 8843.5 8849.0 8849.5 8855.0 8861.0 8864.5 8865.0 8865.5 8869.5 8872.0 8873.5 8874.0 8895.0 8895.5 8911.0 8917.0 8922.5 8927.5 8952.5 8979.0 8999.5 9000.0 9008.0 9011.5 9014.5 8703.5 8712.5 8717.0 8734.0 8760.0 8776.5 8786.0 8796.5 8804.0 8809.0 8815.0 8838.5 8843.5 8848.5 8865.5 8869.0 8873.0 8894.5 8952.5 9008.5 9014.5 8704.0 8714.0 8720.5 8726.5 8729.5 8731.5 8733.5 8741.5 8760.0 8767.5 8777.0 8810.0 8812.5 8820.5 8825.5 8840.5 8848.5 8855.0 8861.5 8864.5 8869.0 8871.5 8874.0 8895.0 8916.5 8922.5 8927.5 8980.0 9000.5 9011.5 8707.0 8708.5 8718.0 8720.0 8726.5 8734.0 8766.0 8777.5 8807.5 8810.5 8815.5 8821.5 8827.0 8839.0 8843.5 8849.5 8864.5 8873.5 8911.0 8999.5 9014.0 9020.0 9025.5 9026.5 9044.0 9046.0 9046.5 9050.0 9052.5 9055.5 9056.5 9057.0 9060.5 9061.0 9062.5 9063.0 9077.5 9080.5 9084.0 9089.5 9092.5 9099.5 9100.5 9104.5 9112.0 9123.5 9124.0 9133.5 9138.0 9144.0 9152.0 9160.0 9168.5 9173.5 9174.5 9192.5 9205.5 9207.5 9239.5 9246.5 9250.0 9250.5 9251.5 9361.0 MERGED DATA SOURCE PBU TOOL CODE GR GR DLL DLL SDN SDN 2435 2435 $ REMARKS: 9027.0 9046.5 9055.0 9059.0 9062.0 9077.0 9056.5 9059.5 9062.0 9079.5 9092.5 9100.5 9019.5 9025.0 9044.0 9046.0 9050.0 9O52.5 9056.5 9063.0 9084.5 9090.0 9098.5 9104.0 9111.0 9111.5 9123.5 9122.5 9134.0 9138.0 9144.0 9152.0 9152.0 9151.5 9160.5 9168.5 9173.0 9174.5 9193.0 9206.5 9208.0 9240.0 9239.5 9240.0 9246.0 9251.0 9249.5 9251.5 9361.0 9361.0 9361.0 RUN NO. PASS NO. MERGE TOP 1 4 8410.0 1 3 8450.0 1 4 8462.0 1 3 8500.0 1 4 8435.0 1 3 8473.0 1 4 8466.0 1 3 8520.0 MAIN PASS. LLD, SP, MTEM, DRHO, MERGE BASE 8450.0 9289.0 8500.0 9341.0 8473.0 9314.0 8520.0 9296.0 TEND, & TENS WERE SHIFTED WITH LL3. PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. THE TOP PORTION OF THE REPEAT PASS WAS SPLICED ONTO THE MAIN PASS FOR COMPLETE DATA COVERAGE. CN WN FN COUN STAT / ? ?MATCH!. OUT / ? ?MATCH2. OUT /??MATCH3. OUT $ : ARCO ALASKA INC. : DoS. 11 - 04A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 2 LL3 DLL 68 1 OHMM 3 LLD DLL 68 1 OHMM 4 SP DLL 68 1 MV 5 MTEM DLL 68 1 DEGF 6 TEND DLL 68 1 LB 7 TENS DLL 68 1 LB 8 RHOB SDN 68 1 G/C3 9 DRHO SDN 68 1 G/C3 10 PEF SDN 68 1 BN/E 11 CALl SDN 68 1 IN 12 NPHI 2435 68 1 PU-S 13 FUCT 2435 68 1 CPS 14 NUCT 2435 68 1 CPS 4 4 57 515 01 6 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 98 211 23 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 123 Tape File Start Depth = 9361.000000 Tape File End Depth = 8384.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29326 datums Tape Subfile: 2 376 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8448.0 9301.5 DLL 8500.0 9353.5 ZDL 8472.5 9325.0 2435 8504.5 9303.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL KNJT KNJT TEMP PCM MIS DLL FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 01-MAR-94 FSYS REV. J001 VER. 1.1 1630 01-MAR-94 126 02-MAR-94 9355.0 9353.0 8475.0 9341.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 3967XA 1229MA/1229EA 8.500 7786.0 0.0 GEL-FREE KCL POLY 9.80 40.0 9.2 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 11 - 04A : PRUDHOE BAY : NORTH SLOPE : ALASKA 6.2 170.0 0.142 0.071 0.122 0.000 0.175 0.000 THERMAL SANDSTONE 0.00 0.000 0.0 85.0 170.0 62.0 0.0 65.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E SHR ZDL 68 1 CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 57 515 01 6 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 11 639 82 1 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 37 715 66 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 72 * DATA RECORD (TYPE# 0) Total Data Records: 289 994 BYTES * Tape File Start Depth = 9361.000000 Tape File End Depth = 8425.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 71156 datums Tape Subfile: 3 371 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8410.0 DLL 8462.0 ZDL 8435.0 2435 8466.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON ZDL Z-DENSITY KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT TEMP TEMPERATURE PCM PULSE CODE MODULATOR MIS MASS ISOLATION SUB DLL DUAL LATEROLOG FTS FEED THROUGH SUB $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): STOP DEPTH 8748.5 8800.0 8772.0 8750.0 01-MAR-94 FSYS REV. JO01 VER. 1.1 1630 01-MAR-94 205 02-MAR-94 9355.0 9353.0 8475.0 9341.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222MA/2222EA 3921NA 3921NA 2806XA 3506XA 3967XA 1229MA/1229EA 8.500 7786.0 0.0 GEL-FREE KCL POLY 9.80 40.0 9.2 6.2 170.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 11 - 04A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0. 142 0.071 0.122 0.000 0. 175 0.000 THERMAL SANDSTONE 0.00 0.000 0.0 85.0 170.0 62.0 0.0 65.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 2 RS DLL 68 1 OHMM 3 RD DLL 68 1 OHMM 4 SP DLL 68 1 MV 5 TEMP DLL 68 1 DEGF 6 CHT DLL 68 1 LB 7 TTEN DLL 68 1 LB 8 SPD DLL 68 1 F/MN 9 ZDEN ZDL 68 1 G/C3 10 ZCOR ZDL 68 1 G/C3 11 PE ZDL 68 1 BN/E 12 SHR ZDL 68 1 13 CAL ZDL 68 1 IN 14 CNC 2435 68 1 PU-S 15 CNCF 2435 68 1 PU-S 16 CN 2435 68 1 PU-L 17 LSN 2435 68 1 CPS 18 SSN 2435 68 1 CPS 4 4 57 515 01 6 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 11 639 82 1 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 37 715 66 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 131 Tape File Start Depth = 8808.000000 Tape File End Depth = 8384.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 61570 datums Tape Subfile: 4 211 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 5 is type: LIS 3/14 01 **** REEL TRAILER **** 94/ 3/16 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 16 MAR 94 4:14p Elapsed execution time = 14.45 seconds. SYSTEM RETURN CODE = 0 CO~PA~tY ~A~k~ : BP E×PLO~ATION ~ELL ~IA~E : NK- 16 FIELD NA~E : NIAKUK 9ORUUGH : NORTH SLOPE APl NU~E~ : 50-029-22447-00 ~]F'ERENCE ~[! : 95168 ,IS Tape veriti, catioP Listino ~chlu.v, berq~r alaska Co~[:~ltInq ('er~ter 22-D~&Y-1995 i5:39 : HP EXPLORA~'!O~,! (~LASKA), i'~IAKUK NK-16, APl ~50-0~,9-22447-00 TAPE H~A[)ER nlAFUK LOGGI[~JG C~)~PA~Y: ~'Ap~" CREATION DATF:: dOi3 DATA SURFACE LOCATION FNL: FSL: gEL: E;LEVATIQ~(FT FRO(,q /"}SL 0) GRO[.i:5:~O LEVF:L= IST STRING .... ST. MK-16 500292244700 BP LXPLORATION SCMLUSBERGER ~ELL SERVICES 22-~qAY-95 BIT RUN 2 RUN 3 36 892 59. 59, a0 19,i0 0,~75 PAGE: ,IS TaDe Yer!,~icatJon t, istlnq ,cblumber(~er ;%lasKa Com~;~utinq Center 22-!AY-19Q5 i5:]9 ~ell drilled 26-APR tbrouqt~ 28-APR-95 with CDR only. All data ~as collected in a stnqle bit run. $ YFRSIOi'.i : O01COI D~T~ : 051o5122 M~X REC ~IZ~ : 1~24 F!LF TYDE : LEi L~S~' FII, E : DeDth sni~t, ed ssd clipped curves~ all bit runs ~er~ed, [)EPT~ 'I~NC~ENT: 0.5000 LDWG TOOI~ CODE START D~jPTH STOP DEPTF~ ['~ CURVE FOR SHIFTS: (.,CCH.CBT CURVE ~F~!FT DATA (MEASURED 13EPT~) ...... ----EOU~VALENT [I~}SMIFTED DEPT}i--- .... --- , 12721,~ ~2701.,0 12698.0 12688.5 1.2674'0 12649,5 12637,5 12604.0 ~2595.0 12578,0 12566.0 12561,0 !.25!.0,5 1.2434,~ 123nS, 12372.5 I2361.,© 8~892.5 12726.0 12724.5 12706.0 12702,5 !2693.0 12680.0 12655,0 1.2643.5 126!0.O 12600.5 12584,5 1P573.5 !.2567.5 12517.5 !2440.5 ~239~,5 1.2378,0 12367.5 a.,. verifl, cstio~ ListInq Chlt]mber:.~er Alaska Computir, g, C.e~,ter 22-~Y-1995 15:~9 PAGE= 3 I 23~5. 123~6.5 !23~7.0 122~-,4.5 12z40o 121o4.,,') !2! 1 ~TS.O 12046.0 12026.5 11989.5 11982.0 [,.['~wG moor, COPE 12351.e 12341.5 12322.5 12293.5 12269.5 12245.5 t2216.0 1211q.o 120~1.5 12029,0 11994.5 11986,5 ~04,5 The ¢ieptaTadjust. ments shown above reflect the MWD GR to the Ski' GRCH lo9ged by Atlas IO-'gAY-gb. Alt otiler MWD curves ~ere carried ~lth l t']e GR. This file also contal~]s the Very Enhanced ORO resisitivity with 2~ average that was reprocessed at GeoQuest, $ LIS FCR~,,!AT DATA ,:,t,: DA~'A FORMAT SPECTF!CATION i 66 0 ~' 66 0 3 73 4~ 4 66 1 6 73. 7 65 8 6,8 0,5 9 6"'~ FT 11 66 25 12 6~ 1.3 66 0 1'4 65 FT 15 66 68 i. 6 66 I ,IS Tape veri£ication b,tst;ivn 77-t~'A¥--!995 15:39 ;chlumberqer AlasKa Com[:~oti. r:c] (.'.enter PAGE; 4 mmmmmmm m m mm~m~*mmmmm mmmm m m m mm m 0 66 0 ** SET TYPE - CFIA~ ** I!) r)R, DE~ ~ bOG-TYP~i CLASS ~0D ~IL,~B SAMP FLEN CODE (HEX) F T 6 !. o 0 () _ 00 O 1 4 0 0 H ~q ~.~h45321 cO 000 O0 0 1 1 1 4 68 0000000000 RP h; ~.,,, r'_..0 H t,~ ~'., ~45321 O0 00(') oO 0 I I 1 4 68 0000000000 VP.A ,v ,~. p OHF~ v, 645321 00 ()00 00 0 i l 1 4 68 0000000000 V~P ~," >, F, 0 t4 a ,,',~ 645321 O0 000 O0 0 i 1 i 4 68 O00OO00000 hER ~,: ;:,: q OH t4 s', 645321 O0 000 O0 0 1 1 1 4 68 0000000000 ROP ~,'~ ':~ I) FPHR 645321 o0 ()o0 O0 O 1 1 I 4 68 0000000000 G~ ~,.r, GAPI 6~53~1 O0 OOC) O0 O I 1 I 4 68 0000000000 FET ~'. ~,: L) HR ~4532!, O0 000 O0 n ! 1 !, 4 68 0000000000 GP C ~:.'r GAPI 645321. oO 000 O0 u 1 1 1 4 68 0000000000 * * t.) A T A ** -999.250 VR.A.MWD -999.250 GR.~WD :99~,250 VRA.N~D 99,-.250 GR.N'~D 2999 250 999:250 -999.250 -999. 50 **** FT[.,E ~RAILER **** FILE NA~E : Et)IT ,001 SERVICe; : FL!C VERSIO:~,i : aO!.COI DATF : 95105/22 Nh× ~FC SIZE : !924 FILF: TYP~ : LC; L~$? ViLE : ,IS l"a~e ,/eriii, catJon Listing ;cblU~i',ber'¢er Al. asPca Com;..~ut.~.ns cer;ter LaST F fLE : 2~.-?~AY-1995 15:39 PAGE: FILM ~! ;J" ~Ff~ 2 Curves and loq header data ior each mit run !n se~arate files. DEP?~! [ ,.'~ C P E ~; E !':~T: 0.5o00 # FIL~' LOG HEADER DATA DAT~ bOGGED: SURFACE SO~'T~-JA~;E VERSIO~J: 90~NtqOhF SOFT%~ARE' 'VERSIE~: DATA TYPE (~v~FiNOR~ or REAL-Ti~qE): TP D~I, LLER (FT): TOP LOC INTERVAL ~OTTOa LOG I~TF:aVAL BI.T ROTATING SPEED HOLE I NCblNATI r'~ .?~ I N ! M IJ~,i ANGLE~ CDR Res S iv /oah~,ma Ray ~O[~}{Hi]LE AND C~.$1~';G DATA OPEN HOI.,E }:fit SIZE DRILLERS CASJ'.~,tG DEPTH ~;')REHOLE C['li~ D I ~',iUD TYPE: ?;; U D P H: ;q!~C, CfqLO~IDE5 t, PP~,~): STOP OEPTH 12787,0.: 28-APR-95 FAST2.5 V4.0C MEMORY 12787.0 12019.0 !2787.0 TOOL, NUMBER ---;;;----- RGS 9.875 4342,0 10,00 ,I8 Tar~e Yeri. ticatlon ;¢hlUmber~.;~er alaska .Co~putin~ Ce~er g2-~AY-I. 995 15:1)9 2 · 57 2.210 i,:' AT~ 1 × DE:~S] TYt tiCkLE CO~ECTII')i'i (I~'~): Drilled from 12n19' to !.2787' ~i.t to GR: 57,39' tO ResistlvitF: 46.97' b!S ~'~R~,~.AT DATA 69°0 69°0 PAGE: ** PATA Fn~.,. AT SPECtFICATIL.}t'; PECORD ** ** SET TYPE - 64gg ** TYP~ REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 7.3 7 65 S 68 0,5 9 65 FT 1! 66 28 12 6a 13 66 0 i, 4 65 FT 15 66 68 1~ 66 1 0 6O 1 :IS ?ape Yerif!.cation chlumberger AlasKa Com~putinO Center 22-~AY-1995 15:39 PAGE: [i) O~D~ ~ bO~ T'fP~ C6A$S ~O0 NUTS5 SASP EbEH CODE (HEX) --.--..~.~. .. ..~..... . . . mm m .!mm~ ~m~., ''--m----m~mmmmm'mmmm.mmm-- m DFPT FT 645321 O0 000 Ov 0 2 1 I 4 68 0000000000 0000000000 0000000000 O000OO0000 O000oO0000 OOOOOO0000 0000000000 0000000000 0000000000 mmmmmmm-mm~m-mmm~mmmmmmmmm-mmmmm--~mmmmmmmmmm~mmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmm! DEPT. 12786.500 PSVP.L~I -999.250 TAP.!..,!:.~I -999.250 DEPT. 11.963. OOt? ATR. b;~ I PSVP. L?-41 -999.2:%0 PER. b~~ 1 TAB. L?-~ 1 -999. 259 END (,)F' DATA ** -999.250 PSR.L~i -999.250 ROPE,L~I -999.250 PSR.B~I -999.250 ROPE.LWl -999.250 ATVR.L~I 38.335 GR.L~I -999.~50 ATVR.LWl -999.250 GP.L~I -999.250 -999,250 -999.250 110.028 **** FTbE TRAILER **** F!L~ N;~!~E : EDIT . ~ER,¥ ICE : F'LIC VERS lr).h~ : OO1COI DAT~ : 9St05i22 MAX RE;C SIZ ,, : 102 FILF TT'P[; : LO LAST FILE bT. ERV !CP; N A~ E DATE : 95/05/22 ORIGIN : FLIC TAP~ N A ~,~ lt; : P~EVIOL)S TAPE CO~'i~E?'.~T : ~.P EXPL[~PATION (ALASKA), NIAK][.iK NK-16, APl ~50-029-22447-00 chl~lm~er~,er Alask& Co~p~t.in~ Center 22-~AY-1995 15:~9 PAGE;
