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184-058
STATE OF ALASKA ALOCA OIL AND GAS CONSERVATION COMMSN RECEIVED REPORT OF SUNDRY WELL OPERATIONS SEP 26 2013 1.Operations Abandon Li Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ GC4. Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well {� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory ❑ 184-058-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99519-6612 50-029-21105-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028330 • PBU 12-23 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL• 11.Present Well Condition Summary: Total Depth measured 9380 feet Plugs measured None feet true vertical 9272.44 feet Junk measured None feet Effective Depth measured 9334 feet Packer measured 8523 feet true vertical 9226.45 feet true vertical 8415.54 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 30-110 30-110 Surface 2448 13-3/8"72#L-80 29-2477 29-2476.66 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 776 7"29#L-80 8604-9380 8496.53-9272.44 8160 7020 Perforation depth Measured depth 8900-8923 feet 9000-9040 feet 9052-9092 feet 9106-9144 feet 9144-9164 feet True Vertical depth 8792.5-8815.5 feet 8892.48-8932.47 feet 8944.47-8984.47 feet 8998.47-9036.47 feet 9036.47-9056.46 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 22-8642 22-8534.53 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker S-3 Perm Packer 8523 8415.54 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8900'-8923',9000'-9040',9052'-9092',9106'-9164' CC..� p aa Treatment descriptions including volumes used and final pressure: . uL)\j [a f I3V- 108 Bbls 12%HCL,139 Bbls 9:1 Mud Acid,488 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 6352 0 271 - Subsequent to operation: 0 0 0 0 0 14.Attachments: '15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG Ell .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: 313-426 Contact Garry Catron Email Gar .Catron• BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 9/25/2013 1/7. f ,•01/01)--47,•01/01)--47 RBDMS OCT 11 J"i Jai/51/ -5 Form 10-404 Revised 10/2012 ORIGINAL Submit Original Only Casing / Tubing Attachment ADL0028330 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"91.5#H-40 30 I - 110 30 - 110 1490 470 LINER 776 7"29# L-80 8604 - 9380 8496.53 - 9272.44 8160 7020 PRODUCTION 8609 7"26#L-80 25 - 8634 25 - 8526.53 7240 5410 PRODUCTION 7726 9-5/8"47#L-80 26 - 7752 26 - 7644.93 6870 4760 PRODUCTION 333 9-5/8"43.5#S-95 7752 - 8085 7644.93 - 7977.64 7510 4130 PRODUCTION 733 9-5/8"47# N-80 8085 - 8818 7977.64 - 8710.51 6870 4760 PRODUCTION 76 9-5/8"47#L-80 8818 - 8894 8710.51 - 8786.5 6870 4760 • SURFACE 2448 13-3/8" 72# L-80 29 - 2477 29 - 2476.66 4930 2670 TUBING 8620 4-1/2" 12.6#L-80 22 - 8642 22 8534.53 8430 7500 • • • 1 E :a (/) O o ^ . c5 - 0) .- o chQ -0 � co Z F- � °O o � (1) rn — LC) O M © 2C)0j LL c II o E - � v0 °O N cn N O O O v v o t I = W = o o a) ) 4. + a3� r a Z� ga) 005 1 o Q = N Z X E - O ? � o in Z Z o Q 0 Z M o L Q v U Z a Q C N 2 Q Q = E �.n _a 3 a) CC W o L c�) r. 0 a) CV LL m CV ACV NNTSU_ COO to N — - co CO W 6) d 3 3 000 — i rO _ 0._ w _ a) inb FE c a) � caw (po - O •+:+ 'I: 2 o carn = ca a)@ `tC tiOO J i _ J 2 � 0 � .c •N Q�° '- w ry cnU C. � � W N � - d u) 0 L o ©U5 WY 0 p 3 (nJZJ a • o � c 20) u Y0 M U H F v •- c I- � 0 0 CI °ID d CO ©� °I3 I- ? Q .;� - 3 C D U) 0 I 02 p O W U O c O W M N 0J J Q' W * w p Y in �w W W L O tL O J i . - v) a• N 0 •0 _j W Z 0 t CI TS c > u t > u Q o CO CO Z U + O Q = O C JO _jH a, cn E °) cnw w a == Ew - � Q .ioc, .6o _ J � a Oa, f J O W ± t W O .. I O p Q a) O J J = O H H �+ > H I� O) -0 J O co JD J ° Q O- > H < > U) < .....M � ZWZJ Z -o0 � `- � -OQ in .5 v r Y0- 0 CC W Y W _ ,O O 2 OO rn O co ,_ o * � Z - U U w < 000T- •= ZE- rn E •5Z -073c° -C3 `4•• 0UO Z - _ - (DH O O c o0 -> > c6N � ZO J = Z Ocoo0CV05 - O - o .- - - j as o o QOb .z XU0_ cch1M ©Yw N- � ° a) a) � TO •� c 45 _c E ' Ln C') 5 (n -- � J 0 J d & = = co C O N - O (n (.'j ,_ (n J > O > HHJ a7N o +- +Ea) N +-. UJ � N op2J c.wI- JI- HCnw ** 30 0 oa* 3 `o ( o oW > LIJC) 0w * EE � EE 0Q F- = 8UVEO- = - 2o * * .5 � QWQ : * OdOJH * UMrn * * UMd cn Qtf) * * 0U) 03cnH * co co co c,-)r- c- C) O O O o N N (NJ N r a) a) a) ... 'TEE= C / WELLHEAD= FMC 0 r-117110TES:***H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C 1 2-2 3 mi.WELL REQUIRES A SSSV WHEN ON A ti I***9-5/8"CASING CUT @2023 MD"**9 COME URAL KB.ELE 71' TIPPLES*** BF.REV= i ■ 440Y 4.4v ■•#4,•,o *■*. 44 11•• 414. "ix Angle=-----17"662oor ■.o. .0 4, 11•• •1.4: Datum MD= 8979'' ■. •. 141 --EMX-111VD= 8800'SS is 1 )j •■ I 2198' —14-1/2" -ES X NP(9-CR),D=3.813" .4 A * * ,6 11 13-3/8"CSG,7211,L-80 BTRS,ID=12.347" H 2477' A 4. A 4 #i A 7"CSG,26#,L-80 Tal X0 TO L-80 BTC-M H 2710' 4. 4 0,6 11 • 74 11 4, • Minimum ID=0.795"@ 8557' .4 4, 11 A 4-112"X LOCK CHOKE r ,4 A 4, 4 6, 11 14.1 9-5/8"CSG,47#,L-80 BTRS,D.=8.681" H 7752' 4 4, • ■• 11 4, A 4 t * (9-5/8'CSG,43.5#,S-95 BTRS,ID=8.755" H 8084' 4' ■• H 4, • • 8492' H 4-1/2"FES X INF(9-CR),I)=3.813' i. y44 .6 H 4, • 4 - 8523' H7"X 4-112'BKR S-3 FKR,ID=3.875' ,6 mr4 * * 4 11 4, 4 A _ 8557' (-4-112'HES X NP(9-CR),0=3.813" I •■ • ■4 M 4, 8557" —4-1/7'X LOCK,DH CHOKE ASSY, ■6 A 4, A 7'CSG,26#,L-80 BTC-M,13=6.276" H 8605' I (09/10/13) 4, • ■6 11 1, 4 8595' —7"LTC HGRw/TIE BACK SEAL ASSY o‘O III — TOP OF 7"LNR —[ 8605' 0=6.280' 11 • 8629' —4-1/2-HES XN NIP(9-CR),ID=3.725" 4-112'TBG,12.6#,L-80 TO, H 8642' 8642' H4-1/2"WLEG,ID=3.958" .0152 bpf,0=3.958' 9-5/8"CSG,47#,L-80 B11 ,0=8.681' H 8895' PERFORATION SUMMARY REF LOG BHCS ON 05/16184 • 8995 H MARKER J080- I ANGLE AT TOP PERE:1"@8900' Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 8900-8923 0 06104/89 3-3/8" 4 9000-9040 0 11/30/84 3-3/8" 4 9052-9092 0 11/30/84 3-3/8" 4 9106-9144 0 11/30/84 3-3/8" 4 9106-9164 0 11/10/92 3-3/8" 4 9144-9164 0 08/07/87 FBTD H 9334' V44444.44444.4 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —I 9380' rayeeWe'ri DATE REV BY COMMENTS DATE REV BY COMENTS FRUDHOE BAY UNIT 05/19184 PKR 176 INITIAL COMPLETION 01/11/12 TIVINOMD ADDED F2S SAFETY NOTE WELL: 12-23 01/26197 0-14 RWO 07/12/13 TRACTIVD SET DH CHOKE(06/27/13) PERMIT No:'1840580 05/24/09 PQ RWO 08/15/13 SWCIJAID RUN DH CHOKE(07/29113) AR/ski: 50-029-21105-00 05/24/09 RIC DRAWING CORRECTIONS 09106/13 STF/PJC PULL DH CHOKE(9/4/13) SEC 18,T1ON,R15E,288'FSL&701'Fa. 07/13/09 FR/JM3 DRLG DRAFT CORRECTIONS 09/18/13 GJB/PJC SET DH CHOKE(09/1013) 02/09/11 1143/JMD ALOE)SSSV SAFELY NOTE - BP Exploration(Alaska) • • VOF To 0).' I%%s THE STATE Alaska Oil and Gas ALASKA. o '�,o11ServaYoll Commission GOVERNOR SEAN PARNELL 1114 - �, 333 West Seventh Avenue Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 G W� 4�'J �: � Fax: 907.276.7542 Higino Dos Santos Petroleum Engineer /. g' BP Exploration (Alaska), Inc. g V -�' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-23 Sundry Number: 313-426 Dear Mr. Santos: 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, fP oerster Chair DATED this (Le day of August, 2013. Encl. III �Q: • STATE OF ALASKA '‘' AUG 0 6 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION V 7S e//S/1 \ APPLICATION FOR SUNDRY APPROVALS AO G ,. �_:= 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0 Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ - Operations Shutdown El Re-enter Susp.Well❑ Stimulate 0 Alter Casing❑ Other ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 184-058-0 . 3.Address: Stratigraphic El Service El • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21105-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 12-23 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028330 ' PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9380 • 9272 - 9334 9226 None None Casing Length Size MD TVD Burst Coliaps* Structural Conductor 80 20"91.5#H-40 30-110 30-110 Surface 2448 13-3/8"72#L-80 29-2477 29-2476.66 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 776 - 7"29#L-80 8604-9380 8496.53-9272.44 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(It): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service U 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG U . Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Higino Dos Santos Email Higino.Dos SantosOBP.Com Printed Name / 1 Higino Dos Santos Title Petroleum Engineer Signature !-'°''-' - - Phone 564-4342 Date + -43 Prepared by Garry Catron 564-4424 COMMISSION USE ONLY 2) (/� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `3/3 - LID co Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBI- OCT 10 20 Other: Spacing Exception Required? Yes ❑ No Ei Subsequent Form Required: r 9 4. APPROVED BY ! Approved by: _ P COMMISSIONER THE COMMISSION Date: g_/‘--13 1loY015- 13 0 \ , 1� Form 10-403 Revised 1/2010 Approv 1r l Enths from the date of approval. Submit in Duplicate h l\ Casing Summary ADL0028330 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR Length 20"91.5#H-40 30 110 30 110 1490 470 H-40 LINER 7"29# L-80 8604 9380 8497 9272 8160 7020 L-80 PRODUCTION 9-5/8"43.5#S-95 7752 8085 7645 7978 7510 4130 S-95 PRODUCTION 9-5/8"47# L-80 26 7752 26 7645 6870 4760 L-80 PRODUCTION 9-5/8"47# N-80 8085 8817 7978 8710 6870 4760 N-80 PRODUCTION 9-5/8"47# L-80 8817 8894 8710 8787 6870 4760 L-80 • SURFACE 13-3/8" 72# L-80 29 2477 29 2477 4930 2670 L-80 TUBING 5-1/2" 17# NT8OS 8481 8517 8374 8410 7740 6280 NT8OS TUBING 4-1/2" 12.6# N-80 8537 ' 8636 8430 8529 8430 7500 N-80 TUBING 5-1/2" 17# L-80 28 8481 28 8374 7740 6280 L-80 • • • Perforation Attachment ADL0028330 Well Date Perf Code MD Top MD Base TVD Top TVD Base 12-23 6/4/89 APF 8900 8923 8793 8816 12-23 11/30/84 PER 9000 9040 8892 8932 12-23 11/30/84 ' PER 9052 9092 8944 8984 12-23 11/10/92 RPF 9106 9144 8998 9036 12-23 11/10/92' RPF 9144 9164 9036 9056 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 1 • • Packers and SSV's Attachment ADL0028330 Well Facility Type MD Top Description TVD Top 12-23 PACKER 8487 5-1/2" HBBP-T Packer 8380 12-23 PACKER 8561 4-1/2" Baker FHL Packer 8454 • • • bP 0 To: Len Seymour/Clark Olsen Date: August 5, 2013 Wells Service Team Leaders Jerry Middendorf& Robert Liddelow D&C Wireline Team Leaders Reviewed: Michael Hibbert, 07/24/2013 From: Higino dos Santos AFE: APBINJEC DS 03 & 12 PE Est Cost: $ 250 K Subject: 12-23 FCO and Acid Stimulation IOR: 8,000 bwpd (112 bopd equivalent) Type Desc. Step Unit Operation 1 S D&T TD with TEL and Sample Bailer. 2 0 Collect wellbore fluid sample from offset producer 3 C FCO to 9,144'MD or TD. Acid Stimulation w/wax oilseeker diversion Current Status: Injector-Online Max Deviation: 17° @ 6200' and Last Test: 5,055 bwpd on 06.05.2013 Last SBHP: 3,258-psi and 116F @ 8,800 SS on 05.30.2009 Min. ID: 3.725" @ 8,629' (4-1/2" HES XN Nipple) Last Tag: 09.17.2009 -Tag @ 9,055' SLM Last DH Ops: 09.19.2009- !PROF Last H2S: NA Last MIT: 06.02.13: AOGCC MIT-IA passed @ 2458psi OBJECTIVE Perform a FCO in order to remove fill and restore 45P, 44P and 43P injection to support offset producers 12-09 and 12-10A lower 45P perforations. Clean the wellbore of potential scale and ✓ stimulate all Ivishak open perforations. Background: 12-23 pattern is in the middle to northern part of DS 12. Offset producer 12-22 shows -40% Sag contribution, but other offsets don't show significant Sag production. 12-23i has better interactions with the Southern part of the pattern, where 12-10A is, than the Northern. 12-23 6Jun13 FCO.doc • • Current recommended injection rate is 8,000 BWPD. 12-23 had a RWO in May 2009 to repair TxIAxOA, and the September 2009 IPROF showed 100% into 46P, although warmback passes indicate possible injection into the Sag. 12-23 is part of a project to install downhole chokes in DS-12 as deep as possible, below the production packer, to avoid cavitation. The purpose is to split the large differential pressure across two chokes, one on the surface and one that will be installed downhole. This will help surface chokes last longer, reduce metal fatigue and reduce harmonics that requires operators to use double hearing p rotection. Supporting Analysis 12-23 is currently only injecting into 46P according to IPROF done in 19Sept09. Tag of fill @ 9,055' shows 45P, 44P and 43P covered by fill. FCO is needed to support offset producer 12-09 lower 45P perforations. In addition; 12-10A 6Mar12 PPROF shows no oil contribution coming from 45P perforations. This should help swept some of the oil towards the offset producers and FCO should be performed prior to installing the downhole choke. 12-23 supports offset producer 12-09 and 12-09 PPROF, done in 31May09, shows no oil contribution from the Sag. In addition, 12-23i (PROF, done in 19Sep09, showed all water entering Ivishak 9000' MD to 9040' MD, Warmback passes indicated that some water may have been going into the Sag. Furthermore; In 02Jun12 a 3" Drive Down S-Bailer tagged scaling/sand/gravel in the tubing at 8,497' SLM and recovered -2 gallons of scale in 12-09. Laboratory results of the samples analyzed in June showed positive for carbonate. Higino dos Santos @ 564-4342 (W), 713-269-3879 (C). Cc w/att: Well File Suggested Documents Recommended Practice: CTU Operations- Cleanout Procedures Stimulation Target Zone MDT MOB H 6/26/2013 SI Sag 8900 8923 23 PER OPEN 46P 9000 9040 40 PER OPEN 45P/44N/44P 9052 9092 40 PER OPEN 43P/42SB 9106 9144 38 PER OPEN 43P/42N/HOT 9144 9164 20 PER OPEN Open Ivishak Footage 118 Total Footage 161 1. Slickline Procedure 1. MIRU SL Unit. PJSM 2. Drift and Tag with TEL and Sample Bailer 12-23 6Jun13 FCO.doc • • • Send collected sample to BP Lab for solubility analysis 3. POOH, RDMO SL unit 2. Other: 1. Obtain 1 liter of weilbore fluid from offset producer 12-09 and deliver to SLB for Emulsion/Sludge test. 3. Coil Procedure 1. MIRU CT Unit. PJSM 2. RU coil and RIH with 2.00" Jet Swirl Nozzle. 3. RIH while pumping 1% Xs KCL at minimal rate (-0.25 bpm)to avoid plugging the nozzle. • Slick Line last drift was to 9,055'SLM on 09.17.2009 4. Dry tag fill and PU 20' to get full weight and establish pump rate. • If a hard tag is encountered POOH to PU 3.625"Baker DB Under-reamer • See contingency Coil procedure below 5. Jet across the liner with Xs 1% KCL, taking short bites and picking up frequently to prevent burying nozzle into fill (fluff and stuff). • Pump 5 bbl pills of Geovis if needed during fluff and stuff • Fluid pack the weilbore to ensure all debris are swept into the formation 6. Once 9,144' MD or TD is achieved, PU above the initial tagged depth and pump down back side to sweep debris into the formation. 7. Shut down pump, drift and tag TD. • Wait 30 min and reconfirm tag 8. If desired depth is achieved POOH. Contingency Coil Procedure (if hard tag encountered) 1. At surface MU tool string with 3-1/8" CTC, 3-1/8" DCV, 3-1/8" Jars, 3-1/8", Disco, 3- 1/8" Dual Circ Sub, 2-7/8" Motor, 3.625" Baker DB under-reamer. • Ensure to measure and document all the components of the BHA • PT the lubricator and BOP by pumping through the P-sub since testing through the coil will open the under-reamer arms • Tape the under-reamer arms together before raising it into the lubricator to avoid been opened while RIH 2. Shut in well and RIH without pumping to gently tag top of the fill. • Ensure to record the tagged depth 12-23 6Jun13 FCO.doc • • • Ensure to fluid pack the wellbore 3. PUH 50' and begin slowly pumping to check if BHA is functional. 4. Gradually increase pump rate as per Baker Engineer's recommendation using slick 1% KCI to begin mill fill. 5. Periodically pump 5 bbl Geovis to mill with under-reamer. • Ensure to put a max. weight between 500 — 1000 lbs depending on the rate of penetration 6. Once 9,144' ctmd or TD is achieved, PUH and back ream to 10' above CT initial tagged depth. • Do not try to under-ream sand to avoid sticking sand under the arms of the under-reamer 7. PUH shut down pump and dry tag TD 8. Once satisfied with the depth uncovered, POOH CT Acid Treatment Procedure 1. Ensure the followings before starting this job: • Current MSDS for this job is onsite and acid safe handling procedures are followed • Ensure that the acid shower trailer is on site and functional • Keep out all personnel not associated with this job 2. MU CTU tool string with 2.00" JSN. 3. Load well by pumping down backside with -240 bbls (1.5 x wellbore volume) of 3% NH4CL (80-110 degF) at 4-5 bpm if possible while RIH. Note that it may be necessary to load well from bottom if injectivity is poor. 4. RIH CT and gently tag top of sand at 9,144' MD. PU 20' and flag pipe. Establish injection test using 50 bbls of 3% NH4CL not exceeding 2,000 psi WHP. 5. RU acidizing equipment. PT surface lines to 4500 psi. 6. Jet acid as per pumping schedule across the perforations down CT at maximum rate not exceeding 0.65 psi/ft gradient. • Reciprocate coil between 9,124'MD and 8,980'MD. 7. Exceed frac. gradient if necessary to establish injectivity or complete the job, reduce pressure after injection is established. • Note max WHP is 2000 psi 8. Once over flush is out of the nozzle, displace tubing with 70 bbls of 3% NH4CL. • Note injection rate while over displacing. 12-23 6Jun13 FCO.doc • S 9. POOH and freeze protect top of well with 32 bbls of diesel. 10. RDMO. 1 „,/,/y ,/,..2., , ,fri,,,, ,,,,,...„,,,-2,- , ,, . -,/, ,,,„/„2„ ,/,..„- ., ,..7,7,, ..,.... 7 ' 7,''''' , . / /i / •''; , ,i ' � i �d' i ep:',/,'S,;1;4' 2,4,i7„:97:": *."--:';',A05.".;;;77/p.:"Y,, /),•%' 4,,,z,47„,,p44,4;v1',,, "A /'" 1:°,7';://y/./. //I',;',""/4"//X441/;;;'/>/,',40"** Afi' zi"- ' -1 Load 3% NH4CI+0.2% F103 236 236 2 Acid 12% HCI 47 282 3 Mud Acid 9:1 Mud Acid 47 329 4 Oherflush 3% NH4CI+0.2% F103 70 399 5 Dixerter Oilseeker 12 411 6 Pre Flush(Spacer) 3% NH4CI+0.2% F103 446 7 Acid 12% HCI 443577 493 8 Mud Acid 9:1 Mud Acid 540 9 O�erflush 3% NH4CI+0.2% F103 70 610 10 Di�erter Oilseeker 12 622 11 Pre Flush(Spacer) 3% NH4CI+0.2% F103 35 657 12 Acid 12% HCI 47 704 13 Mud Acid 9:1 Mud Acid 47 751 14 Tubing Wash 12% HCI 21 821 15 Oxerflush 3% NH4CI+0.2% F103 70 842 ril 3/r/r/A/''''''A'17' .,,''7'.1//' ri:/;1//7/2/, *i*'''''''''1''.'...' ',*,172-.4/1.,', ./. `p,,,,,,,,,--7."'- "r":,;,,,,,u,-„,;,-0 „, , //piii?/4,,,,„://". --- ,, -,/;,,,,/,‘,/‘ ,-.„,,f, ,,,,,/,,,o,,/,," '7/1,..,/*//1"/17////1/,56:::;14„',41 ok.,,c,'"*P%---- m 1 Load/O�erfush/Pre-Flush 3%NHu4CI+i F103 511461601 516 2 Acid/Tubing Wash 12%HCI 678 3 Mud Acid 9:1 Mud Acid 818 4 Dieerter Oilseeker 24 842 Mixing Recipe 50 bbls 9:1 Mud Acid Composition A264 Corrosion Inhibitor 4 Gal/Mgal F103 Surfactant 2 Gal/Mgal L058 Iron Control 20 lb/Mgal W054 Antiemulsifier 5 gal/Mgal U067 Mutual Solvent 50 gal/Mgal 50 bbls 12% HCI Composition A264 Corrosion Inhibitor 4 Gal/Mgal F103 Surfactant 2 Gal/Mgal L058 Iron Control 20 lb/Mgal W054 Antiemulsifier 5 gal/Mgal 12-23 6Jun13 FCO.doc • • Note: 3% NH4CL, 0.2% F103 Note: Ensure correct additives are used. BHST 116 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +1-1% for HCI. Fluids should be 90-110 F. 12-23 6Jun13 FCO.doc . _ • • Tom= (211U SAFETY NOTES:H2S READINGS AVERAGE 125 ppm WELLHEAD= FMC _ WHEN ON MI.WELL REQUIRES A SSSV WHEN ON= BAKER C 12�2 3 Ml.7"CASING @ SURFACE 9-518"CASING CUT @ KB.B.EV= 71' 2023'MD"'CHROMENIPPLES"'" H BF.ELEV= i . - - 444 i KOP 4 1.44 141441 Max Angle=___17s @ 6200 0.4± '4414! Datum MD= 8979' II ` E I, I 2198' H4-1/2"HES X NIP(8 Cti(,ID=3.813 Datum1VD= 8800 SS ►1 1 13.3/8"CSG,72#,L-80 BTRS,ID=12.347" --I 2477' • j 1 4 141 • IT'CSG,26#,L-80 TCII XO TO L-80 BTC-M H 2710' ( 1 /41/ Minimum ID=3,725"@ 8629' ;4; 4-112" HES XN Nipple 1;1 141 it 14.4 9-5/6'CSG,47#,L-80 BTRS,ID=8681" H 7752' ►4j I41 1t1 1 9-5/8"CSG,43.5#,S-95 BTRS,ID=8.755" H 8084' ■41 141 ►e1 • I I 141 I 8492' —14-1/2'HES X NIP(9-CR(,ID=3,813" I 141 111 1.� 8523' (HrX41/2"BKRS-3PKR,ID=3-875" I MI A 111 ►a/ ' ,4, 8557' H4-12"HES X NIP(94R),ID=3.813 I IT'CSG,268,L-80 BTC-M,ID=6.276" H 8605' : 141 IA 8595' I—7"LNR HGR w/TIEBACK SEAL ASSY TOP OFT LNR H 8605' .ID=6280" 412 TBG,12.6#,L•80 TCII, —I 8642' , I 8629' H 4-1/2"HES XN NIP(9-CR),ID=3.725" I .0152 bpf,ID=3.958" 19-58"CSG,476,L-80 BTRS,ID=8.681" H 8895' ^ / I 8642' —1412"WLEG,ID=3.958" PERFORATION SUMMARY \\v ' REF LOG:BRCS ON 05/16/84 ANGLE AT TOP PERT 1'©8900' Note:Refer to Production DB for historical pert data I 8995' —17"MARKER JOINT I SIZE SPF INTERNAL Opn/Sqz DATE I 3-3/8" 4 ' 8900-8923 O 06/04/89 3-3/8" 4 9000-9040 0 11/30/84 I3-3/8" 4 9052-9092 0 11/30/84 3-3/8" 4 9106-9144 0 11/30/84 ' 3-3/8' 4 9106.9164 0 11/10/92 3-3/8' 4 9144-9164 0 08/07/87 I PBTD H 9334' I 17"OR 29#,L-80 BTC,.0371 bpf,ID=6.184" H 9380' 1:a a a a a DATE REV BY COMMENTS DATE I REV BY COMMENTS PRUDHOE BAY UNIT 05/19184 PKR176 ORIGINAL COMPLETION 011 11/12;TMPYJMD ADDED FOS SAFETY NOTE WELL: 12-23 01126/97 D-14 RWO I PERMIT No: 1840580 05124/09 N2ES RWO AR No:50-029-21105-00 05/24/09 PJC DRAWNG CORRECTIONS SEC 18,T10N,R15E,288'FSL&701'FEL 07/13/09 FR/JMD DRLG DRAFT CORRECTIONS 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE ._ BP Exploration(Alaska) 12-23 6Jun13 FCO.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,June 04,2013 e P.I.Supervisor (" n q, 3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 12-23 FROM: Bob Noble PRUDHOE BAY UNIT 12-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry� - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 12-23 API Well Number 50-029-21105-00-00 Inspector Name: Bob Noble Permit Number: 184-058-0 Inspection Date: 6/2/2013 Insp Num: mitRCN130603160617 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 12-23 (Type Inj W' TVD I 8416 IA — 737 737 2501 - 2464 2458 PTD 1840580 Type Test SPT ! 36 � I 36 'Test psi I 2104 OA 36 37 n I - terval 'avRTST P/F P g � Tubin i 412 412 • 413 413 - Notes: SCANNED FEB 2 0 Z014 Tuesday,June 04,2013 Page 1 of 1 1OI08109 Scbimberger (; ZV� N0.5410 T Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job k Log Description Date BL Color CD MPC -05A 11661124 MEMORY PROD PROFILE 01/25/07 1 L4 -03 AY1 M -00032 PRODUCTION PROFILE 09/09/09 1 LS -05 AP3O -00061 PRODUCTION PROFILE 09/15/09 1 03 -24A AZCM -00042 LOL 09/14/09 1 07 -328 BOCV -00027 JEWELRY LOG/GR W /PRESS/TEMP /15/09 1 W -214 AYS4 -00095 INJECTION PROFILE 09/12/09 1 04 -26 B5JN -00014 PRODUCTION PROFILE / 09/25/09 1 07 -21 AYS4 -00098 PRODUCTION PROFILE 1 09117/09 1 W -04 68K5 -00003 PRODUCTION PROFILE _ 09/24/09 i P2 -53 AP3O -00060 PRODUCTION PROFILE 09/13/09 1 5-43 WKII -00037 PRODUCTION PROFILE 09/25/09 1 12 -23 AWL8-00035 INJECTION PROFILE 09/19/09 1 05 -38 AYTO -00029 LDL 09/18/09 1 W -29 AWJI -00050 MEM INJECTION PROFILE 09/20/09 1 W -30 AY1M -00034 PLUGBACK W/X -FLOW CHECK 09/12/09 1 3- 37/L -35 83SO -00024 PRODUCTION PROFILE V 09/16/09 1 NK -09 AP3O -00057 USIT 09/07/09 1 W -07A AWJI -00047 MEM CEMENT EVAL ATION 09/07/09 i 11 -10 AYTU -00054 USIT 08/28109 1 02 -068 ANHY -00111 USIT 09/21/09 1 G-1 SA AWJI -00048 MEM CEMENT BOND LOG 09/17109 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 995032838 i > ✓Q STATE OF ALASKA + A OIL AND GAS CONSERVATION CO SION REP T OF SUNDRY WELL OPETIONS ~ is o9 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing - ®Pull Tubing .. ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 184-058 - 3. Address: ®Service . ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21105-00-00 - 7. KB Elevation (ft): 71, 9. Well Name and Number: PBU 12-23 - 8. Property Designation: 10. Field /Pool(s): _ ADL 028330 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary ' , Total depth: measured 9380 feet true vertical 9272' - feet Plugs (measured) None <~1~JN ~ ~C;Q~- Effective depth: measured 9334' feet Junk (measured) None true vertical 9226' feet ~~I~Sk a ~~ ~~S Gang. Goir~m6SSI0rl Casing Length Size MD TVD fttBQ~ Collapse Structural . Conductor 80' 20" 80' 80' 1490 470 Surface 2477' 13-3/8" 2477' 2477' 4930 2670 Intermediate 8895' 9-5/8" 2023' - 8895' 8788' 6870 4760 Production Liner 776' 7" 8604' - 9380' 8497' - 9272' 8160 70230 Tieback Liner 8580' 7" 8498' 8605' 7240 5410 tt~~ p~ ~1~}~}t`~. ~ ~a f J', t."jC ~~/i ^ ~ V V d ~ . i B ~ L ~F J Perforation Depth MD (ft): 8900' - 9164' Perforation Depth TVD (ft): 8793' - 9056' 4-1/2", 12.6# L-80 8642' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer 8523' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut & pulled tubing. Cut 8 pulled 9-5/8" casing from -2023'. Run 7", 26#, L-80 tieback to 8605'. Cemented w/ 236 Bbls Class'G' (1.16 yield) & 157 Bbls Class 'G' (1.16 yield). Pumped top job of 28 Bbls of Class'G' (1.16 yield) & then topped off conductor and 13-3/8" annulus w/ 2 Bbls Class'G' (1.16 yield). Ran 4-1/2" Completion. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 10,430 140 723 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 Frank Roach, 564-4373 309-123 Printed Name rrie Hubble Title Drilling Technologist e Prepared ey Name/Number: Signature Phone 564-4628 Date 1 Terrie Hubble, 564-4628 Form 10-404 Revised 0412006 ~ y Submit Original Only • 12-23, Well History (Pre Rig Workover) Date Summary 4/3/2009 T/IA/OA= SSV/380/380 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 4950/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "Standard" all were in good working condition PPPOT-IC RU 2 HP BT onto IC test void 0 psi. flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torqued LDS "Standard" (1) LDS Q 4:00 tight left in out position, all other were in good working condition. """` LDS on IC will move, left in out position will be tapped & replaced during RWO per FMC Clint Miller *"' 4/5/2009 WELL S/I ON ARRIVAL. MIT-T W/TRIPLEX TO 1000 PSI PASSED RAN 4 ~,5" CENT GA- MPLE BAILER TO XO C~ 8541' SLM, ALL CLEAR. RDMO. LEFT WELL SHUT IN,TURNED WELL OVER TO DSO. 4/5/2009 T/I/O =SSV/400/400 Temp = S/I (RWO prep) Road to location & spot in equipment. 4/6/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 300/300/320 RU ELINE, HEAD / 2WB /CCL /SHOCK MANDRELS / 4.15" SCP POW ER JET CUTTER, MAX OD = 4.15", LENGTH = 24', WEIGHT = 300#. CCL TO CUT DEPTH = 8.1', CUT DEPTH = 8483'. CONFIRMED AT SURFACE, CUTTER DID FIRE. FINAL T/I/O = 600/240/200 SSV = C, MASTER = C, WING = C, SWAB = C JOB COMPLETE. 4/6/2009 T/I/O =SSV/400/400 Temp = S/I MIT IA to 3000 PSI FAILED 3 attempts. MIT OA to 2000 PSI PASSED (RWO prep). Speared into IA w/ 2 bbls neat followed by 3.7 bbls ambient diesel to test. 1st 15 min loss of 240 PSI & 2nd 15 min loss of 210 PSI for a total loss of 450 PSI in 30 min. Established a LLR based upon volume of fluid to bring IA back to test PSI over time, as leak to small for bi Apr.0.87 GPM Q 3000 PSI) Bled IAP down. (APR. 5 bbls) Pumped 0.8 bbls diesel for OA test. 1st 15 min loss of 40 PSI & 2nd 15 min loss of 20 PSI for a total loss of 60 PSI in 30 min. Bled OAP down. (Apr. 1 bbl) DSO notified upon departure of following: SWV, WV, MV, SSV = S/I. IAV, OAV =OPEN. Tags hung, FWHP's = SSV/260/320. 4/9/2009 T/I/O = 280/300/300 Temp = S/I Circ- out TxIA (RWO prep). Rigged up and pressure tested surface equipment. 4/10/2009 T/I/O = 5/0/0 Set 5" FMC ISA BPV. 1-2 Ext used, tag C~ 90", Plug # 539, Pre Rig, Nabors 2ES. 4/10/2009 Circ-Out TxIA (RWO). Pumped 5 bbls meth, 893 bbls 9.8# brine down Tbg thru jet cut Q 8483' up IA taking returns thru hardline jumper to flowline of 12-35. Freeze protected TxIA with 135 bbls diesel, U- tubed across for 1 hr. Freeze protected hardline jumper to 12-35 with 1 bbl meth, 3 bbls diesel. Final WHPs 0/0/0. SV, WV, SSV =Shut. MV, IA, OA =Open. 5/2/2009 ..~Y~ce~ ANGI flange on OA valve with 5000 psi rated API flange PT to 5000 psi for 15 min (PASS). JOB COMPLETE. Page 1 of 1 BP EXPLORATION Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT 5/4/2009 ~ 15:00 - 21:00 ~ 6.00 ~ MOB ~ P 21:00 - 23:30 ~ 2.50 MOB ~ P 23:30 - 00:00 0.50 MOB P 5/5/2009 00:00 - 02:30 2.50 MOB P 02:30 - 13:00 ~ 10.501 RIGU ~ P 13:00 - 14:00 1.00 WHSUR P 14:00 - 15:30 1.50 WHSUR P 15:30-18:30 ~ 3.OO~WHSUR~P Perform MIT-OA test to 2000 psi -good test. Lose 60 psi in 1st 15 minutes, lose 10 psi in last 15 minutes. RD LRS. 18:30 - 20:00 1.50 WHSUR P DECOMP RU DSM. Pull BPV. RD DSM. 20:00 - 21:00 1.00 KILL P DECOMP RU to reverse circulate in cellar. 21:00 - 00:00 3.00 KILL P DECOMP Reverse circulate at 164 gpm, 500 psi to clear diesel from tubing. Switch direction and clear diesel from annulus. Well still flowin . Line up to take returns to pits and circulate SS thru tubing cut ' at 8483'. Circulate at 125 gpm, 125 psi. 5/6/2009 00:00 - 02:30 2.50 KILL P DECOMP Finish circulating SS at 125 gpm, 125 psi. Well is static. 02:30 - 03:30 1.00 WHSUR P DECOMP Dry rod in BPV. Test to 1000 si for 10 minutes - filed. BPV leaking. 03:30 - 08:00 4.50 WHSUR N WAIT DECOMP Waiting for DSM. 08:00 - 10:00 2.00 WHSUR P DECOMP RU DSM. Pull leakin BPV and re lace with new BPV. Test from below to 1000 osi for 10 minutes -good test. RD DSM. 10:00 - 12:00 12:00 - 14:00 14:00 - 16`.00 16:00 - 21:00 21:00 - 22:00 22:00 - 23:00 23:00 - 23:30 23:30 - 00:00 2.00 WHSUR P 2.00 BOPSU P 2.00 BOPSU P 5.00 BOPSU P 1.00 BOPSU P 1.00 BOPSU P 0.50 PULL P 0.50 PULL P 5/7/2009 100:00 - 01:00 I 1.001 PULL I P Start: 5/4/2009 Rig Release: 5/26/2009 Rig Number: Page 1 of 11 Spud Date: 5/6/1984 End: 5/26/2009 Phase Description of Operations PRE PJSM. Rig down Bridle up and lay down cattle shoot, Lower derrick. Move sub off well. clean area of herculite and malts. Survey rig height. Move pits, camp shop and outbuildings from 11-12 to 12-23i. PRE Move sub from 11-12 to Schlumberger area in Deadhorse where security stopped rig and wait on Doyon 14 to move off DS12 and clear road. PRE Wait for Doyon 14 to move.-Stopped by security. PRE Moving rig from Schlumberger to DS12-23 on location (~? 0200 hrs. PRE MIRU Nabors over injector well 12-23. Rig accepted at 13:00 hours. DECOMP PJSM /pre-spud with rig crews. DECOMP Install secondary annulus valves on OA and IA. RU lines in cellar to kill well. DECOMP RU LRS. Perform MIT-OA to 2000 psi -test ff is 1ed• Lose 80 psi in 12 minutes, bleed port leaking on 9-5/8" void. Bleed off and fix leak. DECOMP ND Tree. DECOMP Install blankin lu and NU BOPE. DECOMP RU to test BOPE. DECOMP Test BOPE to 250 psi low / 4000 psi high with 4" and 5-1/2" test joints. Test annular preventer to 250 psi low / 2500 psi high with 4" test joint. All tests good. Witness waived by AOGCC Rep. Bob Noble on 5/5/09. BOPE Test witnessed by NAD Toolpusher Chris Page and BP WSL Dick Maskell. DECOMP LD BOPE testing equipment. DECOMP RU DSM. Pull BPV. RD DSM. DECOMP RU to unseat 5-1/2" tubing hanger. DECOMP PU to 170k to unseat tubing hanger. PU 155k after unseating. Establish circulation at 120 gpm, 150 psi. DECOMP Circulate at 460 gpm, 340 psi. Printed: 6/8/2009 11:36:24 AM • • BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Spud Date: 5/6/1984 Event Name: WORKOVER Start: 5/4/2009 End: 5/26/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/26/2009 Rig Name: NABOBS 2ES Rig Number: Date I From - To Hours li Task Code NPT Phase Description of Operations 5/7!2009 01:00 - 02:00 1.00 PULL P DECOMP RU to pull 5-1/2" completion. 02:00 - 12:00 10.00 PULL P DECOMP POH with 8483' of 5-1/2" tubing. Tubing does not appear to have anv corrosion or erosion present. Recover: 1 - 5-1/2" tubing hanger w/ XO pup 208 - 5-1/2" tubing joints 1 - 5-1/2" cut joint (2.26') 1 - SSSV assembly 47 - SS control line clamps (9 left in hole) 12:00 - 12:30 0.50 PULL P DECOMP RD tubing pulling equipment. 12:30 - 13:30 1.00 BOPSU P DECOMP RU to test lower set of VBR's with 4" test joint. 13:30 - 14:00 0.50 BOPSU P DECOMP Test bottom set of VBR's to 250 psi low / 4000 psi high with 4" test joint. Good test. Witness waived by AOGCC Rep Bob Noble. BOPE test witnessed by NAD Toolpusher Chris Page and BP WSL Dick Maskell. 14:00 - 14:30 0.50 BOPSU P DECOMP RD BOPE testing equipment. 14:30 - 15:00 0.50 CLEAN P DECOMP Safety Meeting with BP Reps Steve Robinson and Paul Forman. 15:00 - 16:30 1.50 CLEAN P DECOMP MU BHA #1 9-5/8" casin cleanout; 8-1/2" bit, 9-5/8" casing scraper, bumper sub, DC's) to 291'. 16:30 - 23:00 6.50 CLEAN P DECOMP RIH from 291' to 8475' on drillpipe singles. Tag stub at 84~'. PU - 175k, SO - 150k. 23:00 - 00:00 1.00 CLEAN P DECOMP Circulate surface to surface sweep at 519 gpm, 1816 psi. 5/8/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Finish circulating at 519 gpm, 1816 psi. 00:30 - 04:00 3.50 CLEAN P DECOMP POH from 8475' to 291'. 04:00 - 05:00 1.00 CLEAN P DECOMP LD 9-5/8" casing scraper BHA (BHA #1). 05:00 - 06:00 1.00 EVAL P DECOMP R SWS E-line. 06:00 - 11:30 5.50 EVAL P DECOMP E-Line: USIT log from 8400' to surface. Find TOC at 2 11:30 - 12:30 1.00 EVAL P DECOMP E-line. 12:30 - 14:00 1.50 FISH P DECOMP MU BHA #2 (packer mill; 8-1/2" mill shoe, 8-1/8" washover pipe, 7"junk baskets, jars, accelerator, bumper sub, drill collars) to 337'. 14:00 - 17:00 3.00 FISH P DECOMP RIH from 337' to 8426'. 17:00 - 00:00 7.00 FISH P DECOMP Wash over stump at 8475' to top of packer at 8478'. Mill pac er to 8479', appear to mill top slips, at 19:00. Make no progress since, backup rings below top slips are now spinning. PU - 175k, SO - 155k, ROT - 165k. Circulate at 210 gpm, 400 psi. TO - 4k off / 3k to 9k on bottom. RPM - 70. 5/9/2009 00:00 - 12:00 12.00 FISH P DECOMP Continue milling packer at 8479'. PU - 175k, SO - 155k, ROT - 165k. Circulate at 100 to 210 gpm, 200 to 500 psi. TO - 4k off / 3k to 8k on bottom. RPM - 40 to 100. WOB - 5k to 10k. Progress v. slow -suspect cone and rings below slips are spinning and not allowing the mi I to bite. Have made -13" from start of milling. 12:00 - 12:30 0.50 FISH P DECOMP Monitor well, pump dry job. 12:30 - 15:00 2.50 FISH P DECOMP POH from 8479' to 337'. 15:00 - 16:30 1.50 FISH P DECOMP LD packer milling BHA (BHA #2) from 337'. Mill still has adequate cutting structure but the box connection is flared. Printed: 6/8/2009 11:36:24 AM • BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date From - To Hours Task Code NPT 5/9/2009 16:30 - 17:30 1.00 FISH P 17:30 - 20:30 3.00 FISH P 20:30 - 00:00 3.50 FISH P Spud Date: 5/6/1984 Start: 5/4/2009 End: 5/26/2009 I Rig Release: 5/26/2009 Rig Number: Phase ~ Description of Operations DECOMP MU BHA #3 packer milling; (new mill shoe, washover pipe, boot baskets, bumper sub, accelerator, jar, DC's, HWDP) to 605'. DECOMP RIH from 605' to 8475'. DECOMP Mill packer from 8479'. PU - 180k, SO - 160k, ROT - 170k. RPM - 70, TO - 4k off / 3k to 6k on btm. WOB - 2k to 25k. Circulate at 210 gpm, 310 psi. 5/10/2009 00:00 - 06:00 6.00 FISH P DECOMP Continue to mill packer from 8479'. Have made _ 5" progress since starting this mill run. Total length milled to date - 18". 06:00 - 10:30 4.50 FISH P DECOMP PU - 180k, SO - 160k, ROT - 170k. RPM - 70, TO - 4k off / 3k to 6k on btm. WOB - 2k to 25k. Circulate at 210 gpm, 310 psi. Continue milling on TIW HB-BP production packer. Mill down to 8481.5' and packer finally broke free and moved downhole_onto next packer down. 10:30 - 11:30 1.00 FISH P DECOMP CBU at 430 gpm & check for packer gas. No gas from bottoms u. 11:30 - 14:30 3.00 FISH P DECOMP POH from 8482' to 605'. 14:30 - 16:00 1.50 FISH P DECOMP LD packer milling BHA (BHA #3) from 605'. 16:00 - 17:00 1.00 FISH P DECOMP MU BHA #4, packer fishing (spear, jars, bumper, DC's, HWDP), to 597'. 17:00 - 20:00 3.00 FISH P DECOMP RIH from 597' to 8404'. PU - 175k, SO - 160k. 20:00 - 22:30 2.50 FISH P DECOMP Cut and slip drilling line. Service top drive, crown, and drawworks. 22:30 - 23:00 0.50 FISH P DECOMP Engage fish at 8478'. No go with spear at 8482'. 3k to 4k overpull on PU. Set back down to verify latch up -good latch up. Monitor well, pump dry job. 23:00 - 00:00 1.00 FISH P DECOMP POH from 8482' to 6712'. 5/11/2009 00:00 - 02:30 2.50 FISH P DECOMP POH from 6712' to 597'. 02:30 - 03:30 1.00 FISH P DECOMP LD packer fishing BHA (BHA #4) from 597' to top of fish. 03:30 - 04:30 1.00 FISH P DECOMP LD is .Cut pup joint was sheared off from the top of packer assembly at the connection. Recover 1 -cut pup joint of 5-1/2" tubing 1 -milled packer w/pup jt. below 1 - 5-1/2" overshot assembly 04:30 - 06:00 1.50 FISH P DECOMP MU BHA #5 PBR fishin (itco spear, circ sub, jars, bumper sub, DC's, HWDP) to 597'. 06:00 - 08:00 2.00 FISH P DECOMP RIH from 597' to 8488'. PU - 180k, SO - 160k. 08:00 - 09:30 1.50 FISH P DECOMP Attem t to latch into fish at 8510' -unsuccessful. Suspect junk from first packer milling run is precluding us from entering stub. POH. 09:30 - 12:00 2.50 FISH P DECOMP POH from 8500' to 597'. 12:00 - 13:30 1.50 FISH P DECOMP LD PBR fishing BHA (BHA #5) from 597'. 13:30 - 15:00 1.50 FISH P DECOMP MU BHA #6, PBR overshot w/ mill (mill shoe, overshot, overs of extension, circ sub, bumper, jars, DC's, HWDP, accelerator) to 589'. 15:00 - 16:00 1.00 FISH P DECOMP RIH from 589' to 2472'. 16:00 - 16:30 0.50 FISH P DECOMP Service brakes on top drive. Printed: 6/8/2009 11:36:24 AM • BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: 1 2-23 Common W ell Name: 1 2-23 Spud Date: 5/6/1984 Event Nam e: WORKO VER Start : 5/4/2009 End: 5/26/2009 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 5/26/2009 Rig Name: NABOR S 2ES Rig Number: Date From - To Hours Task Code 'i NPT ~~, Phase Description of Operations 5/11/2009 16:30 - 19:00 2.50 FISH P DECOMP RIH from 2472' to 8489'. PU - 180k, SO - 160k, ROT - 170k. 19:00 - 20:00 1.00 FISH P DECOMP Circulate at 126 gpm, 110 psi and engage fish at 8510'. Overpull up to 190k over - no go. Jar up at 140k to 170k over, fish came free after 12 jars. Monitor well -static. Set back down to confirm acker still in lace -verified. PU - 180k, SO - 160k. 20:00 - 21:00 1.00 FISH P DECOMP CBU. While circulating, perform derrick & drawworks inspection. 21:00 - 21:30 0.50 FISH P DECOMP Finish inspecting derrick and drawworks -level drawworks. 21:30 - 00:00 2.50 FISH P DECOMP POH from 8510' to 1717'. 5/12/2009 00:00 - 01:00 1.00 FISH P DECOMP POH from 1717' to 589'. 01:00 - 02:30 1.50 FISH P DECOMP LD PBR Overshot BHA (BHA #6) from 589'. LD fish. Recovered only the 5-1/2" cut joint w/ pin end sheared off. 02:30 - 04:00 1.50 FISH P DECOMP MU BHA #7, PBR overshot # mi s oe, overs o , circ sub, bumper sub, DC's, accelerator, HWDP) to 588'. 04:00 - 06:30 2.50 FISH P DECOMP RIH from 588' to 8484'. Up weight 180k, down 160k. 06:30 - 10:00 3.50 FISH P DECOMP MU top drive. RIH tag up at 8529'. Engage overshot. Work 40k down and begin jarring. Jar at 250k, 300k and 325k. Jar 13 times until free. Break circulation at 130 gpm with 200 psi. Work packer element across collar until seals q~ygy evere losses: +/- 200 bph. Begin filling hole with seawater. Returns to surface at 240 gpm with 270 psi. 10:00 - 12:00 2.00 FISH P DECOMP Unable to break out top drive due to well being out of balance. Displace 9.8 ppg brine with seawater. Perform post jarring derrick and top drive inspection. 12:00 - 15:30 3.50 FISH P DECOMP POOH with fish to 583'. 15:30 - 17:00 1.50 FISH P DECOMP Lay down HWDP. Stand back DC. Lay down fishing assembly. 17:00 - 21:30 4.50 FISH P DECOMP Punch holes in tail i e assembl . assembl .Break down overshot assembly. Clear and clean floor. 21:30 - 22:00 0.50 CLEAN P DECOMP PJSM. PU/MU 7" scraper clean out assembl to 23'. 22:00 - 00:00 2.00 CLEAN P DECOMP RI to 6232'. 5/13/2009 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM. RIH to 8206'. 01:00 - 01:30 0.50 CLEAN P DECOMP PU 4" drill pipe to 8866'. Up weight 160k, down 145k. 01:30 - 02:30 1.00 CLEAN P DECOMP PJSM. Cut and slip 110' of drilling line. 02:30 - 03:30 1.00 CLEAN P DECOMP PJSM. Service drawworks and top drive. 03:30 - 04:00 0.50 CLEAN P DECOMP Pull 2 stands. MU top drive. Circulate at 450 gpm with 1630 psi for 15 minutes. 04:00 - 08:00 4.00 CLEAN P DECOMP PJSM. Fluid weight in and out 8.5 ppg. POOH with 7" scraper. 08:00 - 08:30 0.50 CLEAN P DECOMP Lay down 7" scraper BHA. 08:30 - 13:00 4.50 DHB P DECOMP PJSM. MU 7" RBP and RIH to 8830'. 13:00 - 14:00 1.00 DHB P DECOMP Set 7" RBP at 8830'. Set down 15k to verify set. Pull up. Fill Hole at 450 gpm with 1850 psi. Monitor well for 10 minutes. Well static. 14:00 - 14:30 0.50 DHB P DECOMP Test RBP to 1000 psi for 10 minutes. Lost 150 si. 14:30 - 18:00 3.50 DHB P DECOMP POOH and lay down RBP running tool. Clear and clean floor. 18:00 - 20:30 2.50 BOPSU P DECOMP PJSM. Change top rams from 3-1/2" x 6" variables to 4-1/2" x 7" variables. PU/ U tools or testing OPE. Run in test plug. 20:30 - 21:00 0.50 BOPSU P DECOMP Monitor well. Well bubbling. No pressure. 21:00 - 00:00 3.00 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 4000 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Printed: 6/8/2009 11:36:24 AM • BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Spud Date: 5/6/1984 Event Name: WORKOVER Start: 5/4/2009 End: 5/26/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/26/2009 Rig Name: NABORS 2ES Rig Number: Date .From - To I Hours Task Code 5/13/2009 21:00 - 00:00 3.00 BOPSU P 5/14/2009 i 00:00 - 05:00 i 5.00 ~ BOPSUp P 05:00 - 05:30 0.50 BOPSU P 05:30 - 08:30 3.00 DHB P 08:30 - 09:30 1.00 DHB P 09:30 - 13:00 3.50 DHB N 13:00 - 14:00 1.00 DHB P 14:00 - 15:00 1.00 DHB P 15:00 - 19:30 I 4.501 DHB I P 19:30 - 21:00 I 1.501 DHB I P 21:00 - 23:30 2.501 DHB P 23:30 - 00:00 0.50 DHB P 5/15/2009 00:00 - 01:30 1.50 DHB P 01:30 - 02:00 I 0.501 DHB I P 02:00 - 02:30 0.50 DHB P 02:30 - 04:00 1.50 DHB P 04:00 - 05:00 I 1.001 DHB I P 05:00 - 06:00 1.00 DHB P 06:00 - 06:30 0.50 FISH P 06:30 - 08:00 1.50 FISH P 08:00 - 09:30 1.50 FISH P 09:30 - 10:00 I 0.501 FISH I P 10:00 - 16:00 ( 6.001 FISH I P 16:00 - 17:30 1.50 FISH P 17:30 - 18:00 0.50 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:00 0.50 FISH P NPT 'i Phase Description of Operations DECOMP Skinner and Tourpusher Sloan Sunderland. Test upper pipe rams with 4-1/2" and 7" test joints. Test lower pipe rams and Hydril with 4" test joint. DECOMP PJSM. Test BOPE to 250 psi low, 4000 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Mitch Skinner and Tourpusher Sloan Sunderland. Test upper pipe rams with 4-1/2" and 7" test joints. Test lower pipe rams and Hydril with 4" test joint. DECOMP Rig down BOPE testing equipment. DECOMP PU/MU 7" RBP. RIH to 7631'. DECOMP Service rig and drawworks. RREP DECOMP Change out clutch plates on main clutch for drawworks. DECOMP RIH to 8800'. DECOMP Set 7" RBP at 8800'. Set down 15k. Release from plug. Pull up and verify. Test RBP to 1000 psi for 5 minutes. DECOMP Dump 1300 Ibs of river sand on top of RBP, Let settle for 1 hours. Tag sand at 8782'. POOH to 7914'. DECOMP Circulate out breakout gas at 550 gpm with 1720 psi. Monitor well for 20 minutes. DECOMP Fluid in and out 8.5 ppg. POOH and lay down 7" RBP running tool. Clear floor. DECOMP MU 9-5/8" RBP running tool, RBP and single of drill pipe. DECOMP PJSM. RIH with RBP to 2140'. Set plug. Set down 15k. PU and verify set. POOH with 2 stands. DECOMP PJSM. Test 9-5/8" RBP to 1000 psi for 10 minutes. Lost 20 psj. DECOMP Circulate S-S due to well being out of balance. DECOMP Dump 2200 Ibs of river sand on top of RBP. Let sand settle for 1 hour. '- DECOMP Displace well with 9.8 ppg hot brine. Tag sand at 2120'. Brine in and out 9.8 ppg. DECOMP POOH with RBP running tool. Lay down running tool. DECOMP PU 9-5/8" casin cuttin BHA to 285'. DECOMP RIH to 2043'. DECOMP Circulate brine around to 130 degrees at 200 gpm with 420 psi. Rig up LRS. DECOMP Locate collar. Work up and cut 9-5/8" casing at 2023'. Establish circulation through cut. DECOMP PJSM. Finish hooking up LRS. Pump diesel to fill lines. Pressure test lines to 4500 psi. Pump 20 bbls diesel down drill pipe to cutter. Close Hydril and pump remaing 50 bbls 180. degree diesel through cut into the 13-3/8" x 9-5/8" annulus. Follow with 30 bbl Safe-Burt-O at 95 degrees. Spot in OA and let soak 1 hour. Circulate out Arctic Pac and diesel and displace with 9.8 ppg brine. Follow with seawater until to su ace. pen y ri an isplace well with seawater. Circulate at 250 gpm with 600 psi. Fluid in and out 8.5 ppg. DECOMP POOH to 285'. DECOMP La down cutter BHA. Clear and clean floor. DECOMP PJSM. PU 9-5/8" spear assembly. DECOMP Run in and en a e 9-5/8" casin .Back out lock down screws. OA - 0 psi. Pull hanger to rig floor. Pull free with 115k. Printed: 6/8/2009 11:36:24 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours'. Task 'Code' NPT 5/15/2009 ~ 19:00 - 20:30 ~ 1.50 FISH . P 20:30 - 00:00 I 3.501 FISH I P 5/16/2009 100:00 - 02:30 I 2.501 FISH I P 02:30 - 03:30 1.00 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 06:00 2.00 CLEAN P 06:00 - 07:30 1.50 CLEAN P 07:30 - 08:30 1.001 CLEAN ~ P 08:30 - 09:30 1.00 CLEAN P 09:30 - 10:00 0.50 CLEAN P 10:00 - 10:30 0.50 CLEAN N 10:30 - 11:30 1.00 CLEAN P 11:30 - 14:00 2.50 CLEAN P 14:00 - 15:00 I 1.001 CLEAN I P 15:00 - 16:00 I 1.001 CLEAN I P 16:00 - 16:30 I 0.501 CLEAN I P 16:30 - 17:30 1.00 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 18:30 0.50 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 20:30 1.00 FISH P 20:30 - 21:00 I 0.501 FISH I P 21:00 - 22:00 1.00 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 23:00 0.50 FISH P 23:00 - 00:00 1.00 FISH P 5/17/2009 00:00 - 00:30 0.50 FISH P 00:30 - 02:00 I 1.501 FISH I P DECOMP PU/MU tapered milling BHA to dress off Run in to 307'. DECOMP RIH to 2002'. Make up top drive. Rig up blower hose. Run in to 2021'. Up and down weight 75k. DECOMP Mill 9-5/8" casin stump. Pump at 200 gpm with 100 psi. Rotate at 65 rpm with 1k torque. Work into stump. DECOMP Fluid weight in and out 8.5 ppg. POOH to 307'. DECOMP l_ay down milling BHA. DECOMP PU/MU 9-5/8" RCJB BHA to 311'. DECOMP IH to 2020'. DECOMP Make up top drive. RIH and tag up at 2120'. No problem going through 9-5/8" stump. Dry drill 2'. Kick in pumps to 250 gpm with 850 psi. Wash down to 2130'. Rotate at 40 rpm with 1 k torque. DECOMP Pump hi-vis sweep surface to surface at 424 gpm with 3650 psi. DECOMP Fluid weight in and out 8.5 ppg. POOH to 311'. DECOMP PJSM. One large piece of centrailizer recovered, with 2 sm , pieces of the same, from the RCJB. Break boot baskets and dump -only sand recovered. DECOMP Make u same RCJB BHA to 311'. DECOMP RIH to 1911'. DECOMP PJSM. RIH to 2005'. Rig up blower hose. Run in to 2021' at top of 9-5/8" stump. Up and down weight 75k. Tag up with 5k down. PU rotate 1 turn left, slack off - no go. PU rotate 1 turn right slack off and enter 9-5/8" stump. Continue in hole to 2132'. Tag up on sand. DECOMP Mill on top of sand and junk. Rotate at 50 rpm with ik free torque. Slack off to 2133' with 3k down. Torque 3-4k while dry Start: 5/4/2009 Rig Release: 5/26/2009 Rig Number: Page 6 of 1 1 Spud Date: 5/6/1984 End: 5/26/2009 Phase Description of Operations DECOMP Circulate at 355 gpm with 80 psi. Bring handling equipment to rig floor. Lay down spear assembly. DECOMP _Pull 9-5/8" casin from 2023'. Average break out torque 18k. DECOMP PJSM. Pull 9-5/8" casing from cut at 2023' and lay down. Average break out torque 18k. Casing appears in good shape. Recover 49 full joints, 1 cut joint at 20.25', 2 centralizers and 1 hanger with pup. DECOMP Rig down casing handling equipment. Clear and clean floor. DECOMP Change out handling equipment. PU tools for scraper run. DECOMP PJSM. MU 13-3/8" scraper BHA to 342'.. DECOMP RIH to 2021'. Up and down weight 75k. Establish circulation at 84 gpm with 114 psi. Tag top of 9-5/8" stump. Try to work_ through - no go. Rotate at 10 rpm, slack off. Unable to enter 9-5/8". Pick up. DECOMP Circulate aSafe-O-Surf sweep S-S at 463 gpm with 515 psi. Rotate at 45 rpm with 1.5k torque. Break out, blow down top drive. Remove blower hose. DECOMP Fluid weight 8.5 ppg in and out. POOH to 342'. DECOMP Rack back drill collars. RREP DECOMP Repair Iron Roughneck. DECOMP Service rig while repairing Iron Roughneck. DECOMP Lay down scraper. Break bit and lay down. Clear and clean floor. Printetl: 6/8/2009 11:36:24 AM • BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Spud Date: 5/6/1984 Event Name: WORKOVER Start: 5/4/2009 End: 5/26/2009 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 5/26/2009 Rig Name: NABORS 2ES Rig Number: Date 'From - To Hours Task Code ' NPT '~ Phase Description of Operations 5/17/2009 00:30 - 02:00 1.50 FISH P DECOMP milling. PU 3 feet and circulate at 420 gpm with 3640 psi. Shut down. Slack off to 2134'. Pick back up and repeat several times. PU 3 feet and kick in pumps to 420 gpm with 3600 psi. Shut down and remove blower hose. 02:00 - 02:30 0.50 FISH P DECOMP Fluid in and out 8.5 ppg. POOH to 311'. Change handling equipment. 02:30 - 03:30 1.00 FISH P DECOMP PJSM. Lay down RCJB. Recovered 2 centralizes. Lay down boot baskets. 03:30 - 04:00 0.50 FISH P DECOMP PU/MU magnet with cutting head. 04:00 - 05:00 1.00 FISH P DECOMP RIH with magnet BHA to 2005,.• Rig up blower hose. 05:00 - 05:15 0.25 FISH P DECOMP Run in to 2021' at top of 9-5/8" stump. Work through into 9-5/8" casing. Tag up on top of junk/sand at 2136'. Rotate at 5 rpm. Slack off to 3k, drill off. Slack off 2k. Pump 2 bbls fluid. PU. 05:15 - 06:00 0.75 FISH P DECOMP Seawater in and out 8.5 ppg. POOH with maanet BHA. No i metal recovered. Lay down magnet. ~~ 06:00 - 06:30 0.50 FISH P DECOMP MU RCJB BHA to 311'. 06:30 - 07:30 1.00 FISH P DECOMP RIH to 2126'. Circulate at 406 gpm with 3251 psi. Work down to top of sand. PU. 07:30 - 08:30 1.00 FISH P DECOMP Circulate hi-vis sweep surface to surface at 400 gpm with 3200 psi. 08:30 - 09:30 1.00 FISH P DECOMP Seawater in and out 8.5 ppg. POOH to 311'. 09:30 - 10:00 0.50 FISH P DECOMP POOH with RCJB BHA. Clean out and lay down. No significant 10:00 - 10:30 10:30 - 12:00 0.50 1.50 DHB DHB P P DECOMP DECOMP PJSM. PU 9-5/8" RBP running tool. RIH to top of RBP at 2140'. Up and down weight 60k. Kick in pumps at 500 gpm with 500 psi. Work over RBP fishing neck. Close Hydril. Pump through kill line and fill up lines and gas buster. Have man standing by at choke. Shut down pumps. Open bypass on R~p_No gas break out to surface. Release RBP. A ain no influx to surface. O en H dril. Pull lu above 9-5/8" stub at 2023'. 12:00 - 12:30 0.50 DHB P DECOMP Circulate BU at 500 gpm with 500 psi. 12:30 - 13:30 1.00 DHB P DECOMP Fluid in and out 8.5 ppg. POOH to RBP. 13:30 - 14:00 0.50 DHB P DECOMP Lay down RBP and running tool. 14:00 - 15:30 1.50 CLEAN P DECOMP PJSM. PU/MU polish mill assembly to 307'. 15:30 - 18:00 2.50 CLEAN P DECOMP RIH to 8584'. 18:00 - 18:30 0.50 CLEAN P DECOMP Service top drive. 18:30 - 20:30 2.00 CLEAN P DECOMP PJSM. Cut and slip 245' of drilling line. Double cut due to condition. 20:30 - 22:30 2.00 CLEAN N RREP DECOMP PJSM. Make repairs to electrical wire on top drive. 22:30 - 23:00 0.50 CLEAN P DECOMP Run in and tag up at 8603.5'. Circulate ai 200 gpm with 330 psi. Rotate at 50 rpm wit -6k torque. Up weight 180k, down 155k, RT 167k. Set 5k down with rotation and 20k down without rotation. Worked up and down PBR several times. 23:00 - 00:00 1.00 CLEAN P DECOMP Pull up and circulate sweep at 520 gpm with 1750 psi. 5/18/2009 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM. Circulate sweep at 520 gpm with 1750 psi. Small amount of sand back to surface. 01:00 - 04:00 3.00 CLEAN P DECOMP POOH to 307'. 04:00 - 04:45 0.75 CLEAN P DECOMP PJSM. Lay down drill collars. 04:45 - 05:30 0.75 CLEAN P DECOMP PJSM. Lay down boot baskets and polish mill. Clear and clean floor. 05:30 - 07:30 2.00 CASE P DECOMP Pick up casing running equipment. Rig up to run 7" casin 07:30 - 23:30 16.00 CASE P DECOMP Run 7", 26#, L-80, BT - - to at 8595'. Make up Printetl: 6/6/2009 11:36:24 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To I Hours Task. Code NPT 5/18/2009 107:30 - 23:30 16.00 CASE P 23:30 - 00:00 ~ 0.50 ~ CASE ~ P 5/19/2009 ~ 00:00 - 01:00 ~ 1.00 ~ CASE 01:00 - 01:30 0.50 CASE 01:30 - 04:55 3.42 CASE Start: 5/4/2009 I Rig Release: 5/26/2009 Rig Number: Page 8 of 11 Spud Date: 5/6/1984 End: 5/26/2009 Phase Description of Operations DECOMP BTC-M to mark with average torque to 7200 fUlbs. Average TC-II torque 10,100 ft/Ibs. Make up pup joints. RIH and tag no-go at 8605'. Up weight 225k, down 210k. Set down 20k and `~ confirm no-go. DECOMP Make up XO to cement head. WSL Mitch Skinner loaded plugs, verified tattle tail and function tested valves and rods. Hook up lines. DECOMP PJSM. Confirm space out. Finish rigging up cementers and cementing tools. DECOMP Hold PJSM with truckers, cementers and rig crew. DECOMP Prime up cement unit. Add dye to spacer. 01:45 pump 40 bbl spacer with red dye, follow with 5 bbls water. 01:56 shut down pressure test lines to 4500 psi - OK. 02:01 drop plug and batch up lead. 02:08 start 15.8 ppg, GASBLOK lead slurry. 02:12 - 25 bbls away with 333 psi at 5.7 bpm. 02:26 - 100 bbls away with 365 psi at 5.8 bpm. 02:44 - 200 bbls away with 384 psi at 5.6 bpm. 02:54 - 236 bbls away with 278 psi at 4.5 bpm. Switch to 15.8 ppb, lass G tail slurry. 02:57 - 10 bbls away with 269 psi at 4.5 bpm. 03:04 - 50 bbls away with 374 psi at 5.6 bpm. 03:13 - 100 bbls away with 430 psi at 5.5 bpm. 03:29 - 150 bbls away with 118 psi at 5.8 bpm. 03:33 - 157 bbls away, shut down, drop plug and kick out with 5 bbls water. 03:39 -switch to rig pumps. 03:41 - 29 bbls away with 800 psi at 12 bpm. 03:44 - 58 bbls away with 800 psi at 12 bpm. 04:46 - 87 bbls away with 1500 psi at 8 bpm. 04:05 - 175 bbls away with 2550 psi at 7 bpm. 04:15 - 233 bbls away with 3261 psi at 5 bpm. 04:23 - 268 bbls away and red dye back to surface. Shut dowJ close bap. Divert returns to cuttings tank. 032 - 292 bbls away with 3300 psi at 3 bpm. 04:34 - 297 bbls away, lost returns to cuttings tank. Shut down, open I~ycTril. Kick pumps back in. Continue to pump and pump plug with 3870 psi, 500 psi over pump rate. Lower seal assembly below second set of seals. Bleed pressure and Ian on no-go. ec oat - OK. CIP at 04:55 hrs. Lead Slurry: Pumped 236 bbls. Sacks 1141. Yield 1.16 cu ft/sk. Tail Slurry: Pumped 157 bbls. Sacks 757. Printed: 6/8/2009 11:36:24 AM . • • BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Spud Date: 5/6/1984 Event Name: WORKOVER Start: 5/4/2009 End: 5/26/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/26/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations __ _ --_ __ ___ 5/19/2009 01:30 - 04:55 3.42 CASE DECOMP Yield 1.16 cu ft/sk. Lost 15 bbls just before bumping plug. Appear to have lost returns near end of cement job. Did not get cement return; 04:55 - 06:30 1.58 CASE 06:30 - 10:30 4.00 REMC 10:30 - 11:30 1.00 REMC 11:30 - 12:00 I 0.501 REMC 12:00 - 16:00 4.00 16:00 - 18:00 2.00 18:00 - 19:00 1.00 19:00 - 20:00 1.00 20:00 - 23:00 I 3.001 BOPSUR P 23:00 - 00:00 1.00 BOPSU P 5/20/2009 00:00 - 01:30 1.50 BOPSU P 01:30 - 02:00 0.50 BOPSU P 02:00 - 03:00 1.00 BOPSU P 03:00 - 04:30 1.50 BOPSU P 04:30 - 05:00 0.50 BOPSU P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:30 2.50 CLEAN P 08:30 - 12:00 3.50 CLEAN P 12:00 - 13:00 1.00 CLEAN P 13:00 - 15:30 2.50 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 17:00 0.50 BOPSU P 17:00 - 17:30 0.50 CLEAN P 17:30 - 18:30 ~ 1.00 ~ BOPSUF{ P DECOMP Rig down cementers. LD cement head. Clear and clean floor. DPRB DECOMP Wait on cement for top job and 1 1/4" top job pipe. DPRB DECOMP RU handling tools. Run 1 1/4" top job pipe down 7" x 13 3/8" annulus to 235' BRT. MU x-over to cement line. DPRB DECOMP sta is circ. irc t ru top jo pipe at 2 bpm @ 230 psi.4G~t returns to surface after pumping 33 bbis. - Returned viscous spacer with re ye and traces of contaminated cement. DPRB DECOMP Continue waiting on delivery of cement and pumping unit and finalising lab test results. DPRB DECOMP Pump 5 bbls water ahead. Test lines to 1000 psi. Pump 5 bbis water with red dye. Batch mix & pump 28 bbls (172 sx) Class G Gas Blok slurry at ppg. ie : 1.16 cu Wsk. 1 bpm ~ 100-150 psi. Got back cement returns at 25 bbis away. CIP at 18:00 hrs. DECOMP Top off conductor x 13 3/8" annulus with 2 bbis 15.8 ppg Class cement. DPRB DECOMP POH with 1 1/4" top job pipe and wash out each joint. LD same. DECOMP ND BOP stack & tubing spool. Install emergency slips & slack off 190 klbs string weight to energise slips. Cut off 7" casing with Wachs cutter. Remove old tubing spool from wellhead. DECOMP Install bushing packoff in new tubing spool and NU tubing spool. DECOMP Finish NU tubing spool and BOPE. Test void between starting head & tubing spool to 4200 psi for 30 min -good test. DECOMP Install turnbuckles on riser and run mousehole. DECOMP Install 3 1/2" x 6" VBR's in top ram cavity. Install test plug. DECOMP MU TIW valve to 4" test joint. Test upper VBR's and tubing spool break to 250/4000 psi for 5 min each - OK. Pull & LD test joint. DECOMP Install wear ring. DECOMP MU BHA #17. 6" bit (HTC ATJ-4). 2 x 4 3/4" boot baskets. Bit sub with float. 9 x 4 3/4" DC's. DECOMP RIH with drillout BHA #17. Install blower hose. DECOMP Control drill cement and float eauioment from 8468' to 8585'. 355 gpm ~ 1300 psi increasing to 400 gpm ~ 1770 psi. Maintain 2 klbs WOB. Pump sweep surf>surf at 500 gpm. RIH and tag top of sand at 8758'. Dry drill on top of sand down to_ 8768'. DECOMP irc sweep Surf»surf 400 gpm 1700 psi. Remove blower hose. DECOMP POH to BHA. DECOMP LD BHA. DECOMP Pull wear bushing. DECOMP Test casing to 4000 psi for 30 minutes. Lost 50 psi in 1st 15 minutes and 0 psi in 2nd 15 minutes -good test. DECOMP Test upper VBR's to 250/4000 psi for 5 min Printed: 6/8/2009 11:36:24 AM ~~ i • BP EXPLORATION Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date 5/20/2009 5/21 /2009 From - To ~ Hours Task Code NPT 17:30 - 18:30 1.00 BOPSU P 18:30 - 20:00 1.50 CLEAN P 20:00 - 22:30 2.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 00:00 - 03:15 3.25 CLEAN P 03:15 - 04:00 0.75 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 06:30 2.00 CLEAN P 06:30 - 08:30 2.00 CLEAN 08:30 - 11:30 3.00 CLEAN P 11:30 - 13:30 2.00 CLEAN P 13:30 - 15:30 2.00 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 18:30 2.00 CLEAN N 18:30 - 19:30 1.00 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 22:30 2.00 CLEAN P 22:30 - 00:00 1.50 CLEAN N 5/22/2009 00:00 - 03:00 3.00 CLEAN P 03:00 - 05:15 2.25 CLEAN P 05:15 - 06:30 1.25 CLEAN P 06:30 - 07:30 1.00 CLEAN P 07:30 - 08:30 1.00 CLEAN P 08:30 - 09:30 I 1.001 CLEAN I P 09:30 - 18:30 I 9.00 I CLEAN I P 18:30 - 19:30 1.00 CLEAN P 19:30 - 20:30 1.00 WHSUR P 20:30 - 21:30 1.00 RUNCO P Start: 5/4/2009 I Rig Release: 5/26/2009 Rig Number: Page 10 of 1 1 Spud Date: 5/6/1984 End: 5/26/2009 Phase Description of Operations DECOMP joint. DECOMP MU BHA #18: RCJB. Dbl pin sub. 7" csg scraper. 2 x 4 3/4" boot baskets. Bit sub. 9 x 4 3/4" DC's. XO. DECOMP RIH with BHA #18 to 8570'. DECOMP Drop ball for RCJB. RIH to 8765'. PU single & tag top of sand at 8770'. PU & break circ C~3 225 gpm. Saw ball land on seat. SD pump and dry drill on top of sand - no indication of any large pieces of junk on top of sand. Break circ and wash down to -8783' (-15' above to of RBP. Increase circ rate to 225 gpm above sand for 5-10 min. LD single. DECOMP POH with RCJB BHA #18. DECOMP Rack back DC's. Inspect boot baskets -empty except for v. minor debris. RCJB had 2 large pieces of metal -possibly centra iser parts plus 1 small piece metal plus one chunk of cement. Decision made to re-run BHA for second attempt to recover junk off sand. DECOMP MU RCJB assembly__ BHA #19. Run ball for RCJB on seat. DECOMP RIH with BHA #19. DECOMP Tag sand at 8773'. 170 k up. 145 k dn. 145 k rot. Rotate dry on top of sand. Break circ and circ do at 335 gpm/2000 psi to 8790'. PU to 8727'. Let sand fall back down for 10 min. Re-tag sand at 8789' & dry drill down to 8791'. Break circ at 350 gpm/1970 psi. Pump sweep surf»surf. Pump dry job. DECOMP POH to BHA. DECOMP LD BHA #19. V. minor pieces in RCJB. Boot baskets clean. MU Howco RBP retrieving tool. DECOMP RIH with RBP retrievina tool to 4750'. DECOMP Chain on high transmission failed. Pull covers and inspect. RREP DECOMP Repair broken link on draw works chain. DECOMP Continue RIH to retrieve upper RBP. DECOMP Tag top of sand at 8793'. PU & break circ. Wash down to top of RBP at 8800'. Engage plug and PU 5 klbs over to confirm. Circ sweep around to get sand out of hole - 500 gpm C~? 2000 psi. SD pump and release RBP - OK. Pump pill. DECOMP POH with RBP to 8323'. RREP DECOMP Draw works chain too loose and acts like trying to jump tooth on sprocket. SD and replace full link previously installed with half link. DECOMP Continue POH with upper RBP. LD RBP -found piece of centraliser approx 3" x 1" x 1/2" on top of RBP. Clean floor. DECOMP RIH with retrievin tool to recover lower RBP from 7" liner. DECOMP Slip & cut drilling line. DECOMP Service rig & top drive. DECOMP RIH to RBP at 8830'. Engage RBP and release same - 165 klbs up. 140 klbs dn. DECOMP Circ at 500 gpm C~ 1600 psi. Hole taking fluid. No gas from CBU. DECOMP POH with HES RBP laying down 4" DP. LD RBP and running tool. DECOMP RIH & LD DC's from derrick. DECOMP Pull wear bushin from wellhead. LD wellhead tools. RUNCMP Rig up tubing tongs and associated handling equipment for running completion. Pflntetl: 6/8/2009 11:36:14 AM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: 12-23 Common Well Name: 12-23 Spud Date: 5/6/1984 Event Name: WORKOVER Start: 5/4/2009 End: 5/26/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/26/2009 Rig Name: NABORS 2ES Rig Number: Phase I Description of Operations Task Code NPT Date From - To Hours II - 5/22/2009 21:30 - 22:00 0.501 RUNCOI~YIP RUNCMP Hold PJSM for running tubing. 22:00 - 00:00 2.00 5/23/2009 100:00 - 11:30 I 11.501 RU 11:30 - 12:30 I 1.001 RUN 12:30 - 14:00 I 1.501 RUN 14:00 - 16:00 I 2.001 RUN 16:00 - 18:00 I 2.001 RU 18:00 - 20:00 I 2.001 BOPSURP 20:00 - 00:00 I 4.001 WHSUR I P 5/24/2009 ~ 00:00 - 03:00 ~ 3.00 ~ W HSUR ~ P 03:00 - 12:00 9.00 WHSUR P 12:00 - 00:00 I 12.001 DEMOB I P 5/25/2009 100:00 - 12:00 I 12.001 DEMOB I P 12:00 - 20:00 ~ 8.00 ~ DEMOB P 5/26/2009 100:00 - 06:00 I 6.001 DEMOB RUNCMP MU &_bakerlock packer and tailpipe assem~. MU X nipple assembly above packer. Run 4.5" 12.6# L-80 TC-II tubing. Hole taking fluid -filling hole at 90-100 bph wit seawater. RUNCMP Continue running 4.5" 12.6# L-80 TC-II tubing and completion equipment - 202 jts total. MU pup jts and tubing hanger. Land hanger and RILDS. RUNCMP RU Little Red. Pump 30 bbls down tubing to freeze protect to 2000'. Drop ball & rod. RUNCMP Circ in 145 bbls seawater with corrosion inhibitor followed by 46 bbls diesel from Little Red to freeze protect IA to 2500'. RUNCMP RU lines and fluid pack tubing. Pressure uo to 4000 osisp_sEi. production packer. Hold for 30 mi to test tubin - ood pressure oss. eed o pressure. Pressure u on annulus to 40 in t packer and IA -good test. Lost 20 psi in 1st 15 min and 0 psi in 2nd 15 min. RUNCMP RD Little Red and pull landing jt. Install TWC with T-har and test from above to 4000 i. Suck out BOP stack. RUNCMP Remove riser. ND BOPE & remove mousehole. Set BOP back on pedestal. RUNCMP Bring tree and tubing head adaptor in to cellar. Nipple up tree and test adaptervoid and flange to 5000 psi. Fill tree with diesel and test to 5000 psi - no leaks visible. RUNCMP RU DSM. Pull TWC and i .Install needle valves and gauges. Clean cellar area. Secure well. RUNCMP Finish emptying pits & cleaning same prior to de-mob. Remove operator equipment from rig. Prepare SAA/RAA areas for final pickup of products. Chg engine oil in prime movers. Chg oil in top drive. will now be on turnkey move rate until all components in NOC and in Deadhorse. POST Continue rigging down Nabors 2ES for de-mobilisation and stack out at Nabors Operations Center Deadhorse. Estimate move to start approx 16:00 hrs on 5/25/2009. POST Continue rigging down Nabors 2ES for de-mobilisation and stack out at Nabors Operations Center Deadhorse. Continue cleaning pits. Pressure wash skate area and clean under draw works. POST Lay derrick over. Pull pit complex away from sub. Move camp over to NOC yard. Move sub complex off well. Remove BOP rams and clean ram cavities. Pump hydraulic oil out of Koomey system for stack out. Move sub to NOC Yard -arrived at 24:00 hrs. Prepare to move pits to NOC. POST Move sub complex from DS 12 to NOC yard in Deadhorse. All major components now in NOC Deadhorse yard. End of exception move at 06:00 hrs. De-mobilization fee of $300,000 to cover all charges associated with rig stack out. This cost to be split evenly between wells X-05, 11-12 and 12-23i. Printed: 6/8/2009 11:36:24 AM JELLHEAD FMC e CTUATOR = ' AXELSON B.1=LEV'= 71' _ F. ELEV = _ OP = 4400' lax Angle = 17 @ 6200' Datum MD = _8979' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2477' '" CSG, 26#, L-80, TGII, .0383 bpf, ID = 6.276" 2710' Minimum ID = 3.725" @ 8629' 4-1 /2" HES XN Nipple 7" CSG, 26#, L-80, BTC, .0383 bpf, ID = 6.276" ~ 8604' TOP OF 7" LNR 8604' -1/2" TBG, 12.6#, L-80, TGII, .0152 bpf, ID = 3.958"~~ 8640' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 8895' PERFORATION SUMMARY REF LOG: BHCS ON 05/16/84 ANGLE AT TOP PERF: 1 @ 8900' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8900-8923 O 06/04/89 3-3/8" 4 9000-9040 O 11/30/84 3-3/8" 4 9052 - 9092 O 11/30/84 3-3/8" 4 9106 - 9144 O 11/30/84 3-3/8" 4 9106 - 9164 O 11/10/92 3-3/8" 4 9144 - 9164 O 08/07/87 PBTD -1 9334, 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9380' 12 2 3 SAFETY NOTES: 7" casing at surface. 9-5/8" ~ ca ut at 2023' M D. 2198' 4-1/2" HES X NIP, ID = 3.813" 8493' ~4-1/2" HES X NIP, ID = 3.813" 8524' 7" X 4-1/2" BAKER S-3 PKR 8557' 4-1/2" HES X NIP, ID = 3.813" 8629' 4-1/2" HES XN NIP, ID = 3.725" ss4~'--~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 05/19/84 ORIGINAL COMPLETION 01/26/97 RWO 05/24/09 N2ES RWO 05/24/09 PJC DRLG CORRECTIONS PRUDHOE BAY UNff WELL: 12-23 PERMff No: 1840580 API No: 50-029-21105-00 SEC 18, T10N, R15E, 288' FSL & 701' FEL BP Exploration (Alaska) • MEMORANDUM TO: Jim Regg P.I. Supervisor ~~/ ~+~1~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 15, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-23 PRUDHOE BAY UNIT 12-23 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~.) <- Comm Well Name: PRUDHOE BAY UNIT 12-23 Insp Num: mitLG090612112530 Rel Insp Num: API Well Number: 50-029-21105-00-00 Permit Number: 184-058-0 ~ Inspector Name: Lou Grimaldi Inspection Date: 6/12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 12-23 TYPe Inj. W TVD 8417 IA 240 24]5 ~ 2385 2380 P.T.D lsaosao TypeTest SPT Test psi zaoo pA o 0 0 0 Interval I~T^~- ' P/F P - Tubing 720 7zo 7zo 720 Notes: 1.9 bbls pumped and returned. Good post RWO initial test. Cu.~-~ ~ o CPS f ~~ ~J W~ Monday, June 15, 2009 Page 1 of 1 06/08/09 ~~ S~hiube~ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK ~ 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE _ 05/15/09 1 1 06-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 ~A-44 AWLB-00017 SCMT 05/25/09 1 1 12-07A BOCV-00018 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP q 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - , 05/06/09 1 1 15-45B ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - 9 ~ 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 BiJJ-00018 MEM CNUSTP ~ s 05/18/09 1 1 X-30A B2WY-00005 C MEM PROD PROFILE 05/10/09 1 1 12-23 AYKP-00021 USIT 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 L1-21 B2NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT ~ - Q {fl G 05/22/09 1 1 H-196 • B2WY-00004 MEM PROD PROFILE L 05/07/09 1 1 G-16 AYKP-00022 SCMT f / - 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 / L f - 05/21/09 1 1 18-30 B1JJ-00015 MEM PROD PROFILE jG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - ~ 1 05/11/09 1 1 3-37/L-35 AWL9-00035 PRODflNJECTION 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 ~} / fj f,'S 04/26/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING' AND RETURNING ONE GUPY EAGR TO: 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 _3 ~.., J ~~ ~ ~ CO1Y5~RYA ATIO Cp ~ Iplti • Greg Hobbs . Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Y '~ t ±~,{ ~ ~; ~' ~ ~ ~ ~' u v Anchorage AK 99519-6612 SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay FYeld, Prudhoe Bay Oil Pool, PBU 12-23 , ~~ Sundry Number: 309-123 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Corrimission an application for rehearing, A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of April, 2009 Encl. "' ,a~ ~O~ STATE OF ALASKA 1 ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL APR ~ ~ 2009 20 AAC 25.280 .G~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perfc,k~i~i~e ~n ® Alter Casing - - ®Repair Well ^ Plug Perforations ^ Stimulate ~.Re-~~3~~n ded Well ^ Change Approved Program ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 184-058 - 3. Address: ®Service _ ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21105-00-00 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 12-23 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028330 - 71' - Prudhoe Bay Field / Prudhoe Bay Oil 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): 9380' ' 9272' - 9334' 9226' 8624' None in Len h i MD TVD Burst II e ru r I n 0' 14 47 Surface 477' 13- /8" 477' 2477' 4930 2 70 In rm is 88 5' 9-5/8" 8895' 87 6870 4 Pr i n Liner 776' 7" 804' - 380' 497' - 9272' 160 70230 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8900' - 9164' 8793' - 9056' 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 8636' Packers and SSSV Type: 9-5/8" x 5-1/2" TIW 'HB-BP' packer; Packers and SSSV MD (ft): 8487 ; 9-5/8" x 4-1/2" Baker'FHL' packer 8561' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch " ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for ID 16. Well Status after proposed work: Commencin O erations: April ~3; 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: - ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foreg ing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Name Greg bb Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-4191 Date l!v Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~- Conditions of approval: Notify Commission so that a representative may witness ~ ~~ S~ S /a-per ^ Plug Integrity ~-BOP Test ,Mechanical Integrity Test ^ Location Clearance ~^ ~ ~_/v' i y Other: t-.`© J ~QI~'~il \q ~~~ ~7Q 5 : 'c'G~~r S`~ ~`~6~a ~ ~ ~ , i ` ` / \ ~ f~~r'C'~S~a'~~~`~> ~ ~~7~~.5 ~ ~ ~~ "~ ~LC~P~0.~J ~rc ~~CC\C' I ~ Subsequent Form Required: ~~ APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 i~evi~d'06/2006 ~ 4`~t~,i~~t~?t~~.. SutY n~Duplicate ~~~/~/ f ~ r~is~ ~~ ~l' X00 by cr,~~ 12-23i Expense Rig Workover 5~ Scope of Work: Pull 5-'h" completion, cut and pull 9-5/8" casing, mill and recover first packer and overshot, recover second packer and tailpipe, run 7" tieback and cement to surface, run 4-'/2" L-80 premium thread completion. 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. MASP: 2300 psi Well Type: Injector Estimated Start Date: April 15, 2009 Production Engineer: Trina Cooper Intervention Engineer: Frank Roach Pre-Rig Work: W 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. F 2 MIT-T to 3000 si to confirm DBP lu barrier. MIT-IA to 3500 si to establish leak rate in IA S 3 Drift w/DMY 'et cutter 8550' S-1/2" x 4-1/2" crossover E 4 Power Jet Cut tubing @ --8483' MD (jet cut desired to be in the top 2' of the 6.05' pup joint above the TIW acker F 5 CMIT-TxIA to 3500 si and see if leak rate is similar to re-cut MIT-IA. F 6 Circulate well to seawater. FP with diesel to 2000' V 7 Set BPV in tubing hanger. Remove the well house & flow line. Level the pad as needed for the ri . Proposed Procedure Summary: 1. MIRU. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. ND tree. NU BOPE and pressure test to 250 psi low / 4000 psi high. 3. Pull and LD 5-'/z" tubing string to the cut. ~ .~,~~~~ 4. Run USIT log to determine top of cement in 9 5/8" z 13-3/8" annulus. 5. Set retrievable bridge plug 100' below the top of cement. 6. Cut and pull 9 5/a" casing from above the top of cement. Note: Pipe rams will not be changed to 9- 5/e" as the well has two tested barriers (shallow RBP and tested DBP plug and packer) to the reservoir. 7. Retrieve RBP. 8. Mill and retrieve first packer and overshot. 9. Retrieve second packer and tailpipe. 10. Set RBP below existing 7" liner hanger C~ 8600' MD. 11. Run new 7" casing from 7" tieback sleeve to surface and fully cement same. • 12. Pressure test new casing and drill out shoetrack. 13. Clean out to retrievable bridge plug and retrieve same. 14. Run 4-'/z" L-80 completion with Baker S-3 packer. 15. Displace the IA to completion fluid and freeze protect and set the packer. 16. Test tubing and IA to 4000 psi. 17. Set BPV. ND BOPE. NU and test tree. RDMO. F = FMC GE WELLHEAD = FMC ACTUATOR = AXELSON KB. E•lEV = 71' BF E•LEV = KOP = 4400' Max Angle = 17 @ 6200' Datum MD = 8979' Datum TV D = 8800' SS ~ 12-23 I 13-3/8" CSG, 72#, L-80, ID = 12.347" H 24n' Minimum ID = 3.813" @ 8624' 4-1 /2" Camco DB-5 LDG Nipple 5-1 /2" TBG STUB ~ 8517' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 8510' 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 8550' TOP OF 7" LNR I~ 8604' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" i 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORAT~N SUMMARY REF LOG: BRCS ON 05/16/84 A NGLE AT TOP PERF: 1 @ 8900' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8900 - 8923 C 06/04/89 3-3/8" 4 9000 - 9040 C 11/30/84 3-3/8" 4 9052-9092 C 11/30/84 3-3/8" 4 9106 - 9144 C 11/30/84 3-3/8" 4 9106 - 9164 C 11/10/92 3-318" 4 9144 - 9164 C 08/07/87 ~ PBTD ~ 9334' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9380 SAFETY NOTES: ***PRODUCTION CASING LEAK. OP LIMITS: MAX LAP = 500 PSI, MAX OAP = 1000 1/05/05 WAIV9~'""` FHL/TIW HBBP PKRS HAVE REDUCED TEST PRESSURE LIM ITS IN SOM E CASES. CONTACT WIE (x5102) PRIOR TO TESTING. 2229' H 5-1/2" HEM HRQ SSSV NIP, ID = 4.562" ${ 487' I--j 9-5/8" X 5-1 /Z" TM/ HB-BP T PKR $503' 5-1/2" HEM XN NIP, ID = 4.455" $504' 5-1/2" XO PERFD PUP 8510' S-1/2" OVERSHOT $~ 53~~ 5-1 /2" BAKER PBR ASSY $$$()' S-1/2" X 4-1/2" XO 8561' 9-5/8" X 4-1/2" BAKER FHL PKR 8624' 4-1/2" CAM DB-5 LANDAVG NIP, ~ = 3.813" 8624' 4-1/2" DBP PLUG (06/06/08) 8635' 4-1/2" BAKER SHEAROUT SUB $636' 4-112" TUBING TAIL $633' ELMD TT LOGGED 02/15/89 DATE REV BY COMMENTS DATE REV BY COMMENTS 05/19/84 ORIGINAL COMPLETION 01/26!06 RPH/TLH WANERSAFETY CORRECTION 01/26/97 LAST WORKOVER 06/23/08 KJB/SV SET DBP PLUG (06/06/08) 01/06/02 RN/TP CORRECTIONS 02!09/03 ATD/TP SAFETY NOTE CHANGE TO WI 10/31/03 JJ/TLP CORRECT XN NIP ID TO 4.455" 01/06/05 RDJ/PAG WANER SAFETY NOTE PRUDHOE BAY UNfT W~L: 12-23 PERMfT No: 1840580 API No: 50-029-21105-00 SEC 18, T10N, R15E, 5110.58' FEL & 5028.5' FNL BP Exploration (Alaska) TREE = FMC GEN 3 WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV = 71' BF: E3EV = KOP = 4400' Max Angle = 17 @ 6200' Datum MD = 8979' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 7" CSG, 26#, L-80, TGII, .0383 bpf, ~ = 6.276" ~ Minimum ID = 3.725" @ -'8633' 4-1 /2" HES XN Nipple 7" CSG, 26#, L-80. BTC, .0383 bpf, ID = 6.276" TOP OF 7" LNR 4-112" TBG, 12.6#, L-80, TGII, .0152 bpf, ID = 3.958"I 9-5/8" CSG, 47#, L-80, ID = 8.681" 12 X23 SAFETY NOTES: 7" casing at surface. 9-5/8" ca ut at XXXX' M D. PROPOSED I -8645' I PERFORATION SUMMARY REF LOG: BRCS ON 05/16/84 A NGLE AT TOP PERF: 1 @ 8900' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8900 - 8923 C 06/04/89 3-3/8" 4 9000 - 9040 C 11 /30/84 3-3/8" 4 9052 - 9092 C 11 /30/84 3-3/8" 4 9106 - 9144 C 11/30/84 3-3/8" 4 9106 - 9164 C 11/10/92 3-3/8" 4 9144 - 9164 C 08/07/87 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" I 9334' I ^2200' I-I4-1/2" HES X NIP, ID = 3.813" -$493' ~ 4-1 /2" HES X NIP, ID = 3.813" 8524' 7" X 4-1/2" BAKER S-3 PKR -8559' 4-112" HES X NIP, ID = 3.813" -8633' --I4-1 /2" HES XN NIP, ID = 3.725" -~ wLEG DATE REV BY COMMENTS DATE REV BY COMMENTS 05/19184 ORIGINAL COMPLETION 01/26/06 RPHITLH WANERSAFETY CORRECTION 01/26197 LAST WORKOVER 06/23/08 KJB/SV SET DBP PLUG (06/06/08) 01!06/02 RN/TP CORRECTIONS 04;0'-C9 rVR PROI~SE:~ R`~NC 02/09/03 ATD(TP SAFETY NOTECHANGETO WI 10/31 /03 JJ/lLP CORRECT XN NIP ID TO 4.455" 01/06/05 RDJ/PAG WAVER SAFETY NOTE PRUDHOE BAY UNfT WELL: 12-23 P6~Mff No: 1840580 API No: 50-029-21105-00 SEC 18, T10N, R15E, 5110.58' FEL & 5028.5' FNL BP Exploration (Alaska) • • ~.~ ~ ~ rM s i ~ i ~ SARAH PAL/N, GOVERNOR AI,ASii~A OIL L>u`D GA.S 333 W 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COM11II5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Katrina Cooper East WaterIlood Team Leader ~ ,,~~ A U G ~ ~ 2 ~ ~ 8 4~ BP Exploration Alaska Inc. ~w ~` PO Box 196612 Anchorage, AK 99519-6612 ~ 5 ~~ ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-23 Sundry Number: 308-290 Dear Ms. Cooper: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, i' 7~'~i~ Cathy P. Foerster Commissioner DATED this~~ day of August, 2008 Encl. STATE OF ALASKA f `-' ~~ ALASKA OIL AND GAS CONSERVATION COMMISSIC., ~ i'at3 ~.'I~~ APPLICATION FOR SUNDRY APPROVAL~y 20 AAC 25.280 .~. :~ ^~;~ ~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe ~ Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ SEAL TITE Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 184-0580 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21105-00-00' 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 12-23 - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028330 ~ 71 KB ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9380 ~ 9272.44 i 9334 9156 8624' 6/6/08 NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 110 30 110 1490 470 Liner 776 7" 29# L-80 8604 9380 8497 9272 8160 7020 Production 7726 9-5/8" 47# L-80 26 7752 26 7645 6870 4760 Production 333 9-5/8" 43.5# S-95 7752 8085 7645 7978 7510 4130 Production 732 9-5/8" 47# N-80 8085 8817 7978 8710 6870 4760 Surface 2448 13-3/8" 72# L-80 29 2477 29 2477 4930 2670 Production 77 9-5/8" 47# L-80 8817 8894 8710 8787 6870 4760 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See attached - - 5-1/2" 17# L-80 28 - 8481 - - 5-1/2" 17# NT80S 8481 - 8517 - - 4-1/2" 12.6# N-80 8537 - 8636 Packers and SSSV Type: 5-1/2" HBBP-T Packer Packers and SSSV MD (ft): 8487 4-1/2" Baker FHL Packer 8561 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/28/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Katrina Cooper Printed Name Katr in a Cooper Title East Waterflood Team Leader ~ g Signature y~ ~ ,~~ Phone 564-4212 Date 8/14/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~'`'i ~SS~ +~C~ Plug Integrity ^ BOP Test ^ Mechanical Int egrity Test ~ Location Clearance ^ ~~13~~ ~ t Other: ~ ~~~~ ~l~f' ~ ~ 200 Subsequent Form Required: ~~~ A d b APPROVED BY ~ ~~~~ pprove y: COMMISSIONER THE COMMISSION Date: rorm ~ u-4u;~ rtgvisea uerLU~ R 1 G I I~ A L Submit m Uupucate 12-23 184-0580 PFRF ~TT~C`HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-23 11/30/84 PER 9,000. 9,040. 8,892.48 8,932.47 12-23 11/30/84 PER 9,052. 9,092. 8,944.47 __ 8,984.47 12-23 11/30/84 PER 9,106. 9,144. 8,998.47 9,036.47 12-23 8/7/87 APF 9,144. 9,164. 9,036.47 9,056.46 12-23 6/4/89 APF 8,900. 8,923. 8,792.5 8,815.5 12-23 11/10/92 RPF 9,106. 9,164. 8,998.47 9,056.46 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE _ MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • :7 • by To: C. Olsen/J. Bixby, GPB Well Ops TL Date: Aug. 14, 2008 From: Trina Cooper, DS 12 PE Subject: 12-23 Sealtite Cost Code: PBD12WL23-N Est. Cost: $200 M IOR: infector (use 200 for WWBL) (RWO package has been issued for $4.027MM with a benefit of 947 mbo reserves. If this Sealtite program is successful the RWO will be avoided.) Please perform the attached Seal-Tite procedure to repair the casing on well 12-23. Step Type Procedure 1 O Pump Seal-Tite per attached program (separate word document) Current Status: Shut in Injector. Last injection rate: 10,000 bbls seawater per day, early 2007. Max Deviation: 17° @ 6200' MD. Min. ID: 3.813" through 4-1/2" DB-5 nipple @ 8624' MD. Last TD tag: 12/12/07 drift through tubing tail then turned around. 9/27/99 Tag TD at 9114' corr. ELMD. Last Downhole Ops: 6/06/08 Set TTP at 8624' MD. Latest H2S Level: Injector with potential for H2S in the returns. 12-23 is an injector with two PC leaks at 1820' and 5340'. The leak rate is ~0.7 gallons per minute at 2500 psi. Recent Seal-Tite procedures to repair casing on wells that will not see any gas lift on the IA have been successful. If this Seal-Tite procedure is successful then a $4.027 MM rig workover will be avoided. If you have any questions or comments regarding this procedure, please call Trina Cooper at (Work) 564-4212 or (Cell) 230-4212 or (Home) 279-2667. cc: w/a: Well File • Seal-Tite International Advanced Sealant Technology Seal-Tite International Procedure BP Alaska PB 12-23 Casing Leak Repair June 26, 2008 Seal-rite International 500 Deer Cross Drive Madisonville, LA 70447 Telephone: 985-875-1292 Facsimile: 985-875-0687 httn://www. seal-tite. net Objective: Repair Two IA/OA Casing Leaks Identified by LDL @ 1820' and and 5340' md. Obtain a passing MIT on the IA. Mechanical Considerations: The 12-23 failed an IA MIT on 11/22/2007. The leak rate from pump records was approximately 1.5 gpm. Subsequently a TecWel WLD log located two separate leaks at 1820' and and 5340' md. The leak rate at that time was approximately 0.6 gpm. The WLD could not conclusively determine the relative leak rate from each location. The objective will be to spot two separate sealant pills across each leak location. In order to provide the required fluid platform a hole will be punched in the tubing just above the packer and the annulus fluid will be circulated out to brine. Astraddle/sliding sleeve assembly will be used to seal off the hole in the tubing. Volumes: 9 5/8" x 5 1/s" = 0.0438 bbUft x 8487' = 372 bbls to packer To first leak @ 1820' and = 79.7 bbls (Segment A) To second leak @ 5340' and = 1542 bbls (Segment B) From second leak to packer @ 8487' and = 137.8 bbls (Segment C) Assume required MIT pressure is 3000 psi Compression of Segment A = .462 bbls / 1000 psi or 32' @ 3000 psi Compression of Segment B = .540 bbls / 1000 psi or 37' @ 3000 psi Compression of Segment C = .482 bbls / 1000 psi or 33' @ 3000 psi Assume punch hole 20' above packer or 8467' and See mechanical sketch and tubing detail for additional info. Contact: Seal-Tite International Neil Cary 985-875-1292 Intended Procedure: • Meet with field personnel; review well history and verify condition of well as matching information in previous correspondence. Hold pre job safety meeting and review procedure. • • . . 2. R/U slickline. Make a gauge ring run to 51/z" XN nipple @ 8503' . 3. Seta 51/z" XXN or equivalent plug in the S lh"XN nipple @ 8503'. 4. Fill tubing with produced water and test plug to 3000 psi. 5. GIH w/ perforating assembly and punch hole in tubing +- 20' above the packer (Note: Final perf location to be determined based on tubing detail and CCL logs -target is to shoot in the middle of the first full joint above the packer. Per well files there is a 6' long 5 1/z" 17#/ft pup joint just above the packer followed by 155 joints of 5'/z" 17#/ft L-80 tubing. 6. GIH w/ straddle/sliding sleeve assembly and set across perforations. 7. Close sliding sleeve and test straddle assembly to 3000 psi. 8. Open sliding sleeve. 9. R/U triplex on OA. Circulate annulus to 9.4 ppg NaCI brine (circulate until steady 9.4 ppg returns are obtained from tubing, to ensure that fluid is uniform. 10. Transfer triplex to tubing. Inject 12 bbls diesel into tubing, taking returns from IA. This will set up a pressure differential from IA to tubing to enable easy injection of the sealant pill. 11. Blend four bbls of Flo-Seal to 9.4 ppg. Hook up tank discharge to IA casing valve. Open tubing and bleed 2 bbls diesel to suck Flo-Seal into IA. 12. R/LJ triplex to OA. Displace Flo-Seal w 150 bbls of 9.4 ppg NaCI brine. 13. Transfer triplex to tubing. Injectl2 bbls diesel into tubing, taking returns from IA. This will set up a pressure differential from IA to tubing to enable easy injection of the sealant pill. Catch returns from IA back to brine tank. 14. Hook up sealant discharge hose to IA casing valve. Open tubing and bleed 2 bbls diesel to suck remaining Flo-Seal into IA. 15. Displace sealant with 75 bbls of diesel. Take tubing returns back to diesel tank and then brine tank. 16. Once the correct volume of diesel is displaced, R/U slickline and GIH to sliding sleeve assembly at +- 8467'. Close sliding sleeve assembly. 17. Pressure up on IA to 2500 psi. Open OA and monitor leak-off to open tank. 18. Continue pushing sealant down until the leak rate begins to reduce. The lower pill should reach the leak first. Once there are indications that the sealant has reached the leak, bleed the IA back to reduce the injection pressure to 1500 psi. • ~ 19. Maintain a 1500 psi injection pressure to allow the lower sealant to cure and the upper sealant pill to travel to the upper leak. Monitor OA returns for signs that the upper sealant pill has reached the leak location. 20. Once the OA returns diminish to near-zero, shut down the triplex and let the sealant cure for one hour. 21. Increase IA pressure to 2000 psi. Allow to cure for one hour. 22. Increase IA pressure to 2500 psi. Allow to cure for two hours. 23. Increase IA pressure to 3000 psi. 24. Lock in pressure and allow to cure for 5 days. Monitor pressure daily and bump back up if pressure falls below 2000 psi. 25. After 5 day curing period, increase pressure to 3000 psi to establish MITIA. After MITIA bleed IA to zero. 26. R/U slickline. GIH to XXN plug at 8503. Equalize and pull plug. 27. Return well to injection. DNC 7/2/08 • ~~~ ! ProActive Diagnostic Services, Inc.. Leak Detection - WLD 30-May08 12-23 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 Expiration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 ~~~~~ JUN ~~ 2068 and ProActive Diagnostic Services,lnc. CSC l~s ~-(- ~$ Attn: Robert A. Richey !(o3Co 0 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.8952 1) 2) Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-WAIL :.w -_-- _-'~ ~ ~ ~~ WEBSITE _ .___ _- 1 Color Log / EDE 50-029-21105-00 C:\Documents and Settings\Owner\Desktop\Transmit_BP.doc 12-23 (PTD #1840580) Internal ~ver Cancellation -Not Operable Well Page 1 of 1 Re James B DOA • J9, ~ From: NSU, ADW Well Integrity Engineer[NSUADWWeIIlntegrityEngineer@BP.comj ~~~ ~ l~ Z >° I~' 7 Sent: Friday, November 16, 2007 1:00 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS1 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Gerik, Bob G; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Roschinger, Torin T. Subject: 12-23 (PTD #1840580) Internal Waiver Cancellation -Not Operable Well All, An internal waiver was issued for a Production Casing leak on well 12-23 (PTD #1840580) on 01/05/06. Corresponding AOGCC Administrative Approval 4C.003 was approved on 11/18/04. Although this well is allowed to inject under dispensation from the Well Integrity Policy until 12/31/07 if all compliance testing remains current, the PW injection line is down at drill site 12. The decision has been made to cancel the waiver and AA until both the line and the welt are ~. repaired. The well has been reclassified as Not Operable and will be secured."rPlease remove all Waivered well signs and the laminated copy of the waiver and the AA from the wellhouse. The corresponding AA cancellation will be sent to the AOGCC. Please call if you have any questions. ~w~~ t.. ~~~ NQV ~ ~ 2007 11 /26/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K¿11' 7!31!iJ 7 OA TE: Monday, July 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-23 PRUDHOE BAY UNIT 12-23 \tòLt- O~ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: laD P.I. Suprv --.115,"- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 12-23 API Well Number: 50-029-21105-00-00 Inspector Name: John Crisp Insp Num: mitJCr070723085525 Permit Number: 184-058-0 Inspection Date: 7/18/2007 Rei Insp Num: Packer Depth / Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -----, IType Inj. ! ,¡1 ! 140 I Well ¡ 12-23 N TVD 8380 I IA 140 160 160 !/ I ---+-~--+ iTypeTest ! SPT fOA -~ P.T.DI 1840580 Test psi 2095 I 2360 I 2510 I 2570 2460 --- I ~ Interval REQVAR P/F P ",/ Tubing I 20 20 I 20 20 I I -- -- Notes: OA pressure test for variance compliance_ Rigged up with double block to pump truck. #2 retest. SCANNEO AUG 0 6 2007 Monday, July 23, 2007 Page 1 of I MEMORANDUM . TO: ~~~ S~:;~isor Kef?' 7/3/07 FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT 12-23 Insp Num: mitJCr070723084405 Rei Insp Num: Packer Well 1-12"-23 -;Type Inj. ~ N ¡Tvñ-- I P.T.Di 1840580 ITypeTest I SPT I Test psi Interval REQVAR P/F 1 State of Alaska . Alaska Oil and Gas Conservation Commission OA TE: Monday, July 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-23 PRUDHOE BAY UNIT 12-23 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-21105-00-00 Permit Number: 184-058-0 Ko1b \<6 Reviewed By: P.I. Suprv ß¡-'- Comm Inspector Name: John Crisp Inspection Date: 7/18/2007 120 15 Min. 30 Min. 45 Min. 120 Depth f Pretest ----vL--- - 8380 I IA I 120 2095 % OA ~ 2270 I I v' Tubing I 20 Initial I 2500 I ---+- 20 I 60 Min. -- 120 I -+- 120 2450 2420 2370 ! i I 20 -- 20 20 Notes: Test was incomplete. Possible problem with pump truck block valve. I requested that pressure be bled off test equipment & have double block installed on OA to make certain we were not losing pressure to truck. I was willing to witness one more retest. Monday, July 23, 2007 ~.cANNED AUG 06 2007 Page 1 of 1 Jim and Bob, Attached are the missing MIT forms questioned in your email. 1. MITs that appeared past due: 12-33 (PTD 1890100) MITIA performed on 04/17/ 5 PSI-Ol (PTD 2021450) MITIA performed on 11/10/03 Z-33A (PTD 1890050) MITIA 05/09/03 :2-30 (PTD :881420) MITIA 12/04/04 2. lIETs done: 12-23 (PTD 184 580) MITOA 07/29/05 13-22 (PTD 1820770) MITOA 08/26/05 Please let me know 1£ you need further information. Thank you, ¡~ndrea '" Well Integrity Coordinator Office: (907) 559-5102 Pager: (907) 659-5100 xl154 -----Original Message----- From: James Regg [mailt Sent: Thursday, January 11, 2007 1:17 PM To: NSU, ADW Well Integrity Engineer Subject: Missing MITs We have completed a review of the MITs due the past quarter (October - December 2006) and due In January 2007. Several lists below: ~. MITs that appear to be past due *PBU 12-33* (PTD 1890100); MIT due 10/20/2005; status - ecting *PBU PSI-Ol* (PTD 2021450); MIT due 11/2/2005; stacus - ecting *PBU Z-33A* (PTD 189DrJSO); MIT due 10/19/2006; scacus - ect 2. MITs done üased OD Commission record of the test: ector i~tearitv report); hO *PBU 12-23* (PTD 184 580); annual MITOA done 7/29/2 6 *PBU 13-22* PTD 182 77 ; annual MITOA done 8/26/2006 Please complece MITs and provide miss .ceDorts January 31. 2 7 3. lI'IITs *MP:j C-36* PiD 19 198179 Jahuary 2 7_ accordlng to 0ur data: 010); due 1/17/20 7; status - ec-=. 7; status - injecti~g *MPU F-95* status - lDJ2CC12g PTD ::1", ~ ~ I ' '....c'-.- /17/2007; '" . Shut in \NeIls MIT 3Dillversary date; it is acceptab~e _.----~-~----- ¡ of2 *lI'IPU ?-92* 16/2007935 Ai'vl . . to defer testing these until they recommence injection: *PBU WB-06* (PTD 1982210); due 1/13/2007; status - SI since 9/2003 *PBU PWDW2-1* (PTD 1760530); due 1/27/2007; status - SI since 3/2003 Call if you need to discuss. Jim Regg AOGCC Content-Description: MIT PBU 12-30,33 12-04-04.xls MIT PBU 12-30,33 12-04-04.xls Content-Type: application/vnd.ms-exce1 Content-Encoding: base64 Content-Description: MIT PBU PSI-01 11-10-03 (2).x1s MIT PBU PSI-Ol 11-10-03 (2).xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU Z-33A 05-09-03.x1s MIT PBU Z-33A 05-09-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 12-23 07-29-06.xls MIT PBU 12-23 07-29-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 13-22 08-26-06.xls MIT PBU 13-22 08-26-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 \116/20079:35 AM ,. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test /Î . . \~eitt b,..-i;7 ,...1 Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckensteln@admin.state.ak.us;Jim_Regg@admln.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OS 12 07/29/06 Andrea Hughes Packer Depth Pretest Initial 15Mln. 30 Min. Weill 12-23 I Type Inj. 1 W TVO I 8,380' Tubing 2601 260 260 260 Interval I V P.TD. 1840580 Type test P Test psl 2500 Casing P/F P Notes: MIT-OA for Waiver Compliance. ¡/ OA 120 12500 2400 2350 Weill I Type Inj. I TVD I Tubing I Interval P.TD. I Type test I Test psi Casing P/F Notes: OA I 1 I Weill Type Inj.1 TVO I Tubing I I I Interval! prol I Type test I Test psil Casing I I P/F! Notes: OA I I Weill I Type Inj. TVO I Tubing Intervail p.T.o·1 I Type test 1 Test psi! Casing P/FI Notes: OA Weill Type Inj. TVO I Tubing Intervail pro I I Type test I Test psi! Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G ::: Gas J ::: industrial Wastewater N = Not Injecting 'N ::: Water TYPE TEST Codes M ::: Annulus Monitoring p.::: Standard Pressure T:=st R ::: !nternal Radioactive Tracer Survey A ::: Temperature Anomaly Survey D:::: Differential Temperature Test INTERVAL Codes I ::: Initial Test 4::: Four Year Cycle V :: Required by Variance T::: Test during Workover 0= Other (describe In notes) MIT C(eport F:Jrm 8FL 9/1 ¡05 MIT PBU ~ 2-23 07 ·29~C6" 1 xis ~~~ /- RE: PBU 12-23 e e . . ". I? ('/ {¡' '2'./ \ 31D~ Sub.lect. RE. PBL 1_-23 '\<....e1 ( From: "NSU, ADW Wcll Integrity Enginecr" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 12 Feb 200620:42: 18 -0900 To: James Rcgg <jim.Jcgg@admin.statc.ak.us>, Bob Fleckenstein <bob __ fleckcnstein@admin.statc.ak.us> CC: Winton GAubert <winton_aubcrt@admin.state.ak.us>, "NSU, ADW Well Integrity Engincer" <NSUADWWellIntcgrityEngineer(iYBP.com>, "Engel, Harry R" <Harry.Engel@BP.eom>, "NSU, ADW Wcll Operations Supervisor" <NSUADWWcIlOpcrationsSupervisor@BP.com>, "Gerik, Bob U" <Bob.Gerik@BP.com::>, "MCCOllUM, CODY 0 (VECO)" <Cody.McCollum@BP.com> Hi Jim and Bob. Attached is an MIT form for 12-23. Thank you for the reminder. Bob: We did 2 pressure tests, on the tubing and OA. They are currently on the same form. Please let me know if you would prefer they be split between 2 forms and I'll re-send. \164'- 05<6 Thanks! Joe 659-5102 I';';:'ir' ; '\ ¡r'\"f.~¡\:~ r . \ \.:'J"",,t\I)<¡;, ",-- , c-,.> c' -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, February 07, 2006 3:30 PM To: NSU, ADW Well Integrity Engineer; Bob Fleckenstein Cc: Winton GAubert Subject: PBU 12-23 Monthly injector rpt shows MITT and MITOA done 12/31/2005 (as required in AI04C.003 dated 11/18/2004); please send copies of these reports. Thank you. Jim Content-Description: MIT PBU 12-23 12-31-05.xls MIT PBU 12-23 12-31-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 2/13/20069:36 AM e e Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / D8-12 12/31/05 Rob Mielke ~17 2-\f3Io'-' Packer Depth Pretest Initial 15Min. 30 Min. Well 112·23 I Type Inj. I W TVD I 8,380' Tubing 300 3,000 2,880 2,8601 Interval I V P.T.D.11840580 I Type test I P Test psil 2095 Casing I 80 220 250 2501 P/FI P Notes: MIT - T to 3000 psi for WC OAI450 450 450 450 Pumped 8.3 bbls diesel to pressurize TBG. We1l112-23 I Type Inj. I W TVD I 8,380'1 Tubingl 500 500 500 500 Interval I V P.T.D. I 1840580 I Type test I P I Test psil 20951 Casing I 250 250 250 250 P/FI P Notes: MIT -OA to 2500 psi for WC I OAI450 2500 2475 2470 Pumped 2 bbls crude to pressurize OA. Weill I Type Inj. TVD I Tubingl Interval I P.T.D.I I Type test I Test ps¡ Casing I P/FI Notes: OA I Weill Type Inj. TVD I Tubing Interval I P.T.D.I I Type test I Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M;;;: Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlVey A = Temperature Anomaly Survey D:::: Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycie V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT PBU 12-23 12-31-05-1.xls /Q~~ ~0( ~~~7! :fF fÆlfÆ~[~fÆ AT/A~1iA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 18,2004 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.o. Box 196612 Anchorage,AJC 99519-6612 RE: PBU 12-23 (pTD 184-058) Request for Administrative Approval Dear Mr. Rossberg: Per Rule 9 of Area Injection Order ("AIO") 004C.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 12-23. The Commission further finds that, based upon reported results of BPXA's diag- nostic procedures conducted during second quarter, 2004, PBU 12-23 exhibits two com- petent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the envi- ronment or human safety. AOGCC's administrative approval to continue water injection in PBU 12-23 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform a yearly MIT-OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform an MIT - T every two years to 1.2 times the maximum antici- pated well pressure; 5. BPXA shall limit the well's IA pressure to 500 psi; SCANNED NOV 1 9 2004 Mr. Steve Rossberg November 18,2004 Page 2 of2 . 6. BPXAshall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure; and 7. after well shut in, AOGCc approval shall be required to restart injection. 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 consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ø~ DIDIiel T. Seamount Jr. Commissioner SCANNED NO\/l 92004 BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 November 3, 2004 NOV 1 0 2004 Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit 12-23 (PTD 1840580) Request for Administrative Approval to Continue Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval to continue water injection operations into well 12-23. Well 12-23 has a production casing leak. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressure and observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. The attached proposed operating and monitoring plan includes frequent monitoring of the competency of the barriers by recording daily pressure and injection data, increasing the frequency of mechanical integrity tests and increased reporting to the AOGCC. These measures will ensure continued safe water injection operations. Considering the presence of two competent barriers, physical repairs in this well are not necessary for safe operation. If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. This request is consistent with Area Injection Order 4C, Rule 9, in that sound engineering practices have established two competent barriers and an operating and monitoring plan has been developed to ensure continued safe operations. There is no underground source of drinking water and thus no USDW is endangered. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Sincerely, -fS Steve Rossberg Wells Manager SCANNED NO\ll 9 2004 .. Attachments Technical Justification for Administrative Relief Request Wellbore Schematic TIO Plot SCANNE[) NOV 1 9 2004 '. Prudhoe Bay Unit 12-23 Technical Justification for Administrative Relief Request November 3, 2004 Well History and Status Prudhoe Bay Unit well 12-23 (PTD 1840580) has a slow production casing leak. An MIT-IA failed on 05/08/04, leak rate is .42 gpm @ 2000 psi. An MIT-T passed to 3500 psi on 05/10/04 and an MIT-OA passed to 2500 psi on 05/08/04. These passing MITs demonstrate competent tubing and surface casing. Recent Well Events: - 05/08/04: MIT-OA Passed to 2500 psi. MIT-IA failed - LLR-IA 0.42 gpm @ 2000 psi. - 05/10/04: MIT-T Passed to 3500 psi. Barrier and Hazard Evaluation The well has two competent well barrier systems to prevent the atmospheric release of fluids and to safely operate the well. The primary barrier is the tubing/packer. In the event of a leak, the secondary well barrier system composed of the surface casing will contain any pressure. Both of these systems have been pressure tested to at least 1.2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), Pressure / Rate plots and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Tubing competency is demonstrated by the passing MIT-T to 3000 psi on 12/07/03. Primary well barrier system competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting a 2 year MIT-T. Also, maximum allowable IA pressure will be limited to 500 psi. In the event of a tubing or packer leak, IA pressure would increase to the injection pressure, providing notification of a compromised primary well barrier and initiating a well review. Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT -OA to 2500 psi on 10/18/04. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor trends and by conducting an annual MIT -OA. Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. In the event of a shallow production casing leak, an OA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut-in. Any pressure in the OA would relieve into the formation through the production casing and tubing, mitigating the potential of OA overpressure. Injection fluid temperatures are warmer than the wellbore temperatures to the depth of the surface casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressu re. SCANNED NO\! -1 9 2004 . .. Mechanical Condition: The production casing is not considered a component in the well barrier systems. The tubing/packer and surface casing are the 2 competent well barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. Proposed Operating and Monitoring Plan 1. Continue water injection. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform an annual MIT-OA to 1.2 times maximum anticipated well pressure. 5. Perform a MIT-T every 2 years to 1.2 times maximum anticipated well pressure. 6. Notify the AOGCC if there is any indication of a change in well mechanical cond ition. SCANNED NO\ll 9 2004 . ' '^, TREE = FMC GS\J 3 WB...LHEAO = FMC ~AëfÜÃ.Të5Fr;,.""-'-'m"""AXËC§C5'N' 'K8~Ë[Ë\r~'m_'__''''''''''''''mm_m'm_''mmmfF lfF:mË[Ëv":;;;",.,.""""-"-",,,,,,,,,,,,.,,.,_,_,,,,,mmmM "ï(õf5";;,_mm__"____"nm,mmn,,m"'--'44ÕÕ' ,"""'''''HN''''H",,,,,,,m',,,,m',,",,''''''''''NNmNHN''NN,,,,,''''''''NNU''''''NN''''''''''''''''''N''H, -~~_~~"9!:Nn:__'''_m,~".1!_@_~,~QN~ Datum MO = 8979' Datum TVO = 8800' SS 12-23 8 113-3/8" CSG, 72#, L-80, 10 = 12,347" l-i 2477' ~ Minimum ID = 3.813" @ 8624' 4-1/2" Cameo DB-5 LDG Nipple :8: I ~ I TOP OF 5-1/2" TBG-PC H 15-1/2"TBG, 17#, L-80, .0232bpf, 10=4.892" H 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" H 1 TOP OF 4-1/2' TBG-PC 1-1 8517' I r 8510' ~ \ ) 1 8550' 1 8550' 1 :8: ITOPOF 7" LNR l-i 8604' ~ ::8: I I 14-1/2"TBG-FC, 12.6#, N-80, .0152bpf, 10= 3.958" 1-1 8636' 1 I 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 8895' J----AI ~ PERFORATION SUMMARY REF LOG: BHCS ON 05/16/84 ANGLEA TTOP FERF: 1 @ 8900' Note: Refer to A"oductbn œ for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 3-3/8" 4 8900 - 8923 0 06/04/89 3-3/8" 4 9000 - 9040 0 11/30/84 3-3/8" 4 9052 - 9092 0 11/30/84 3-3/8" 4 9106 - 9144 0 11/30/84 3-3/8" 4 9106 - 9164 0 11/10/92 3-3/8" 4 9144 - 9164 0 08/07/87 I I I I ~ 9334' 1 ~. I7"LNR,29#, L-80,.0371 bpf,ID=6.184" H 9380' ~ DA.TE REV BY COMrvENTS DATE REVBY co MrvENTS 05119/84 ORIGINAL COMPLEfION 01/26197 LAST WORKOVER 01/06/02 RNIlP CORREC1l0NS 02/09/03 A TDffP SAFElY NOTE CHANGE TO WI~ 10/31/03 JJ/TLP CORRECT XN NIP 10 TO 4.455" SAFETY NOTES: FHLITIW HBBP PKRS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACT WIE (x51 02) PRIOR TO TESTING. 2229' H5-1/2" HES I-RQ SSSV NIP, 10= 4.562" 1 ~ 8487' 1-i9-5/8" X 5-1/2" TIW HB-BPT A<R I 1-15-1/2" HES XN NIP, 10 =4.455" 1 H5-1/2" XO PffiPD FUP 1 8503' 8504' 8510' 1-15-1/2" OVERSHOT 1 8537' H5-1/2" BAKffi FBRASSY 1 8550' 1-i5-1/2" X4-1/2"XO 1 8561' H 9-5/8" X 4-1/2" BA KER FHL PKR 1 8624' 1-14-1/2" CAM DB-5 LANDNG NP, 10= 3.813" 1 8635' 1-14-1/2" BAKffi SHEAROUTSUB 8636' 1-14-1/2" TUBING TAIL 1 8633' H B...MD TT LOGGED 02/15/89 1 SCANNED NOV 1 9 2004 PRU 01-0 E BAY UNIT WELL: 12-23 PffiMIT No: 1840580 API f\b: 50-029-21105-00 SEC 18, T10N, R15E, 5110.58' FEL & 5028.5' FNL BP Exploration (Alaska) , " . ~ 12-23 TIO Plot 4,000 3,000.. (1) ~ ~ tn tn ~ Cl. 2,000. ~ 1,000 I 'I : I , : i : ~...._~. It JI !liB. .. _II-II}!!!-II-._.II....-fl.-"-..". ..... ---.- .. ;~ ..-11-. ÌlllllIII ~ ~................ AU .. .. . ~. / . ~~r- / 0 ""'.fJI"II_:¡"::'I...-nr... ,. I." _I..'.. ..; I . 11/4/2003 1/4/2004 3/4/2004 5/4/2004 7/4/2004 9/4/2004 11/4/2004 SCANNED NOV 1 9 2004 -. Tbg -R- IA ..... OA OOA -111- OOOA BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 R OCT 2 7 2004 October 20, 2004 ~ cæ Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit 12-23 (PTD 1840580) Request for Administrative Approval to Continue Water Injection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval to continue water injection operations into well 12-23. Well 12-23 has a production casing leak. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressure and observed annulus operating pressures do not exceed 45°1<> of the casing's rated burst pressure. The attached proposed operating and monitoring plan includes frequent monitoring of the competency of the barriers by recording daily pressure and injection data, increasing the frequency of mechanical integrity tests and increased reporting to the AOGCC. These measures will ensure continued safe gas injection operations. Considering the presence of two competent barriers, physical repairs in this well are not necessary for safe operation. If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. This request is consistent with Area Injection Order 4C, Rule 9, in that sound engineering practices have established two competent barriers and an operating and monitoring plan has been developed to ensure continued safe operations. There is no underground source of drinking water and thus no USDW is endangered. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Sincerely, '~J2-- ~ Steve Rossberg Wells Manager SCANNED NO\J 1 9 2004 Attachments Technical Justification for Administrative Relief Request Wellbore Schematic TIO Plot SCANNED NO\! 1. 9 2004 Prudhoe Bay Unit 12-23 Technical Justification for Administrative Relief Request October 20, 2004 Well History and Status Prudhoe Bay Unit well 12-23 (PTD 1840580) has a slow production casing leak. An MIT-IA failed on 05/08/04, leak rate is .42 gpm @ 2000 psi. An MIT-T passed to 3500 psi on 05/10/04 and an MIT-OA passed to 2500 psi on 05/08/04. These passing MITs demonstrate competent tubing and surface casing. Recent Well Events: - 05/08/04: MIT-OA Passed to 2500 psi. MIT-IA failed - LLR-IA 0.42 gpm @ 2000 psi. - 05/10/04: MIT-T Passed to 3500 psi. Barrier and Hazard Evaluation The well has two competent well barrier systems to prevent the atmospheric release of fluids and to safely operate the well. The primary barrier is the tubing/packer. In the event of a leak, the secondary well barrier system composed of the surface casing will contain any pressure. Both of these systems have been pressure tested to at least 1.2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), Pressure / Rate plots and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Tubing competency is demonstrated by the passing MIT-T to 3000 psi on 12/07/03. Primary well barrier system competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting a 2 year MIT-T. Also, maximum allowable IA pressure will be limited to 500 psi. In the event of a tubing or packer leak, IA pressure would increase to the injection pressure, providing notification of a compromised primary well barrier and initiating a well review. Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT-OA to 2500 psi on 10/18/04. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor trends and by conducting an annual MIT-OA. Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. In the event of a shallow production casing leak, an OA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut-in. Any pressure in the OA would relieve into the formation through the production casing and tubing, mitigating the potential of OA overpressure. Injection fluid temperatures are warmer than the wellbore temperatures to the depth of the surface casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressu re. Mechanical Condition: The production casing is not considered a component in the well barrier systems. The tubing/packer and surface casing are the 2 competent well ~ 0 c::::J¡ C'o.J ~ '1-"1 >~ C 2: ¡j::'~ WJ W Z Z <C Ü (f) barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. Proposed Operating and Monitoring Plan 1. Continue water injection. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform an annual MIT-OA to 1.2 times maximum anticipated well pressure. 5. Perform a MIT - T every 2 years to 1.2 times maximum anticipated well pressure. 6. Notify the AOGCC if there is any indication of a change in well mechanical condition. SCANNED NOV 1 9 2004 12-23 TIO Plot 4,000 3,000.. ~ :3 tf tf ( ,) ~ Q. 2,000.. 1,000. ~....-_-_lIlIllt..ø--M.-~-.....II. ~..........~ .... 0 .... III.'.'" 1.11111,...1 rl" 8 " 'I' ....... I' 10/21/2003 12/21/2003 2/21/2004 4/21/2004 6/21/2004 8/21/2004 SCANNED NOV 1 9 '2004 10/21/2004 .- Tbg -111- IA -*- OA OOA -II OOOA TREE = WI3..LHEAD = A CfUii:Y6'Ff = -Kä-ELBT;;-"-~-' wBF. äEV"; "KOP= ... , , ~,^ JY1ax ~n~e = Datum MD = Datum TVD = FMC G8\I 3 FMC . AXELSON Om 71' 12-23 . ._M~-440Õ' _12__~~~~-~ 8979' 8800' SS 8 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2477' ~ Minimum ID = 3.813" @ 8624' 4-1/2" Cameo DB-5 LDG Nipple :8: I ~ I TOP OF 5-1/2" TBG-PC H 8517' I r 15-1/2" TBG, 17#, L-80, .0232 bpf, 10=4.892" 1--1 8510' ~ \ ) 1 15-1/2"TBG-PC, 17#, L-80, .0232 bpf, 10= 4.892" 1-1 8550' TOP OF 4-1/2" TBG-PC H 8550' 1 :8: :8: TOPOF7" LNR 1--1 8604' h I - I 14-1/2" TBG-FC, 12.6#, N-80, .0152 bpf, 10 = 3.958" l-i 8636' 1 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 8895' ~ .. PERFORATION SUMMA. RY REF LOG: BHCS ON 05/16/84 ANGLEA TTOP ÆRF: 1 @ 8900' I'bte: Refer to A-oductbn DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8900 - 8923 0 06/04/89 3-3/8" 4 9000 - 9040 0 11/30/84 3-3/8" 4 9052 - 9092 0 11/30/84 3-3/8" 4 9106 - 9144 0 11/30/84 3-3/8" 4 9106 - 9164 0 11/10/92 3-3/8" 4 9144 - 9164 0 08/07/87 I I SAFETY NOTES: R-ILITIW HBBP PKRS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACT WIE (x 51 02) PRIOR TO TESTING. 2229' H5-1/2" HES I-RQ SSSV NIP, 10 = 4.562" 1 ~ 8487' 1-19-5/8" X 5-1/2" TIW HB-BPT A<R I 8503' 1~5-1/2" HES XN NIP,ID =4.455" 1 8504' 1-15-1/2" XO PERPD ¡:up 1 8510' H5-1/2" OVERSI-DT 1 8537' H5-1/2" BAKER R3RASSY 1 8550' H5-1/2" X 4-1/2" XO 1 8561' H 9-5/8" X 4-1/2" BA KER FI-L PKR 1 8624' H4-1/2" CAM DB-5 LANDING NP, 10 = 3.813" 1 8635' 1-14-1/2" BAKER SHEAROUT SU3 8636' 1-14-1/2" TU3ING TAIL 1 8633' 1-1I3..MD TT LOGGED 02/15/89 1 I SCANNED NOVl 9 20DtJ I ~ 9334' 1 ~. 17" LNR.29#. L-80..0371 bpf.ID =6.164" H 9380' ~ DATE REV BY COMWENTS DATE REV BY COMWENTS 05119/84 ORIGINAL COMPLETION 01/26/97 LAST WORKOVER 01/06102 RN/lP CORRECTIONS 02109/03 ATDITP SAFETY NOTE OiANGETO WI!;. 10/31/03 JJ/TLP CORRECT XN NIP 10 TO 4.455" PRUDI-DE BAY U\l1T WELL: 12-23 PERMT I'b: 1840580 APII'b: 50-029-21105-00 SEe 18, T10N, R15E, 5110.58' FEL & 5028.5' FNL BP Exploration (Alaska) RE: PBU 12-23 Subject: RE: PBU 12-23 Date: Tue, 7 Oct 2003 12:46: 12 -0500 From: "Benson, Gary A" <BensonGA@BP.com> To: Steve McMains <steve_mcmains@admin.state.ak.uS>'" - .¿P--P ~ fe~ -058 '" steve, As I understand it, this was a mistake in the North ~ope automation system related to this one well. No volumes that need to be reallocated to other wells. If it was gas injection, it would be more problematical since we do a gas balancing calculation which would impact all gas injection wells. Gary > > > > > > > > > > > > "Benson, Gary A" wrote: > > > Jim, Winton & steve, > > > > I'll be correcting th~ > system for June, > > July & August and issuing revised 10-406 reports this week. > I've already > > zero'd out the 12-23 volumes for September sent by the > automation system on > > the Slope to our volume accounting system here in Anchorage. > > > > > > > > > > > > > > > > > > > > > > > > ,>., > > > > > > > > > > > > > > > > > > > > > >,> > > > > > > > > > > > > -----Original Message----- From: Steve McMains [ Sent: Tuesday, October 07, To: Benson, Gary A Subject: Re: PBU 12-23 2003 9:31 AM Is the injection volume other wells or was it just a mistake? Steve our volume accounting Gary Benson Volume Accounting Greater Prudhoe Bay BP Exploration (Alaska) (907) 564-4604 (907) 564-4094 fax bensonga@bp.com -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Monday, October 06, 2003 4:26 PM To: Jim Regg; winton GAubert Cc: Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Benson, Gary A Subject: RE: PBU 12-23 Hi Jim & winton. r ~2~23 ~s currently SI. It has been SI sinc~ 8/29/02) The ~n]ect~on volumes reported to the AOGCC appear to be the result of an error in our automation sys~em. 10/1/2003 10:33 AM SCANNED OCT 0 9 2004 Œ: PBU 12-23 > > > > > > > > > > > > > > > Please call if you have any questions. > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > I have been > failures during > > > past year. > in September > > >2002. Per our letter approving the restart of BP's "137 > A/B3" wells > > > (October 29, 2002), a sundry approval was required for Well > > > 12-23 prior > > > to restart. > > > > > > Recent events: > > > - failed MIT (3 tests) on 4/8/03; AOGCC witnessed > > > - well was placed back on water injection in June 2003 > > > according to > > > AOGCC records [June - 4396 bbls (11 days); July - 549 bbls (5 > > > days); Aug > > > - 13,977 bbls (14 days); Sept - ?J. > > > > > > I have not been able to locate the sundry that grants > > > approval for this > > > well to be operating; also, there is nothing in our files > > > that indicates > > > any repair or passing MIT that would be a basis for > restarting this > > > well. > > > > > > Please review and provide an update by 10/3/03. > > > > > > Jim Regg > > > > We are reviewing the process that generates the monthly volumes and evaluating if additional controls are needed to ensure accurate data. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com -----Original Message----- From: Jim Regg [ Sent: Tuesday, September 30, 2003 8:54 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert; Rossberg, R Steven Subject: PBU 12-23 ] reviewing the files of wells with MIT the Well 12-23 was reported as a "137 A/B3" well ~2 10/712003 10:33 AM SCANNED OCT 0 9 2004 ( ( BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 0"',", "'"b"P ,\ '\ May 18, 2004 Mr. Winton Aubert, P. E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 RECEIVED MAY 202004 Alaska Oil & Gas Cons. Commission Anchorage Subject: 12-23 (PTD 1840580) Application for Sundry Approval for PWI with production casing leak. Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well 12-23 requesting approval to continue injection into a water injection well with a production casing leak. If you req~ire any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. -~uÞ- Anna Dube Well Integrity Coordinator Attachments Application for Sundry Approval form 10-403 Description Summary of Proposal Well bore Schematic OR\G\NAL ( STATE OF ALASKA ( RECEIV.ED ALASKA OIL AND GAS CONSERVATION COMMISSIO~ MAY 2 0 '" APPLICATION FOR SUNDRY APPROVAL 2004 20 AAC 25.280 Alaska Oil & Gas Cons. Commission AnchoríUl.Ð Operation Shutdown D perforateD Waiver~ Annular DisposalD Plug Perforations D StimulateD Time ExtensionD OtherD Perforate New Pool D Re-enter sylpended WellD 4. Current Well Class: / 5. Permit to Drill Number: 184-0580 6. API Number 50-029-21105-00-00 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: Suspend D RepairWell D Pull Tubing D BP Exploration (Alaska), Inc. 3. Address: Development D StratigraphicD 9. Well Name and Number: 12-23 10. Field/Pool(s): Prudhoe Bay Fï.éld / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffeclive epth TVD (ft): 9272.4 9334 9155.5 Length Size MD TVD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 71.00 KB 8. Property Designation: ADL-028330 11. Total Depth MD (ft): 9380 Casing Plugs (md): Junk (md): None None Burst Collapse top bo m top bottom 30 - 110 30.0 - 110.0 1490 (604 - 9380 8496.5 - 9272.4 8160 ~6 7752 26.0 - 7644.9 6870 ", 7n2 J 8085 ~644.9 - 7977.6 7510 8' ~I - ~17 / ~977.6 - 8709.5 6870 , ~8 - 13894 8709.5 - 8786.5 6870 29 - 2477 7644.9 - 7977.6 4930 \ì\\ TLbibsize: Tubing Grade: Tubing MD (ft): '\ J- 4.5 " 12.6 # N-80 8537 . 5.5 " 17 # L-80 28 B!, Ck~~5~~y V M",~:ft:: NT80S _1 6 - \ ~~ 8561 t ~ ~ 8487 1 ~ell Class after proposed work: \ ExploratoryD DevelopmentD 15. Well Status after proposed work: Oil D GasD WAG D GINJD Conductor Liner Production Production 80 776 7726 333 732 77 2448 Production Production Surface Perforation Depth MD (ft): 8900 - 8923 9000 - 9040 9052 - 9092 9106 - 9144 9144 - 9164 Packers and SSSV Type: 4-1/2" Baker FHL Packer 5-1/2" HBBP-T Packer Service ŒI 470 7020 4760 4130 4760 4760 2670 8636 8481 8517 16. Verbal Approval: Commission Representative: PluggedD AbandonedD WINJŒ) WDSPLD Prepared by Garry Catron 564-4657. Contact Anna Cube 17. I hereby certify that the foregoing'ts tn/e and correct to the best of my knowledge. Printed Name ~7ra Dube /l Title Signature '- C J,y/LA. of ... r.A - ~/.A...l j¡\.JL Phone Commission Use Only Well Integrity Coordinator 659-5102 5/18/04 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: . ,,./ ..Jo9-/tf';}- -- ÐFL JfJN 2 9 :M) Ii BY ORDER OF I THE COMMISSION Date: SUBMIT IN DUPLICATE Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance D Other: Subsequent Form Required: Approved by: Form 10-403 Revised 12/2003 ORIGIN,AL j' ( 12-23 Description Summary of Proposal 05/18/04 Problem: Produced Water Injector with a production casing leak. Well History and Status Well 12-23 (PTD 1840580) is an injector with a production casing leak. A MIT-IA failed on 05/08/04. A MIT-T passed to 3500 psi on 05/10/04 and a MIT-OA passed to 2500 psi on 05/08/04. These passing MITs demonstrate competent tubing and surface casing. Recent Well Events: > 05/08/04: MIT-OA Passed to 2500 psi. MIT-IA failed - LLR-IA of 0.42 gpm @ 2000 psi > 05/10/04: MIT-T Passed to 3500 psi This Sundry request is to allow for continued water injection in this well. The following supports the request: . A MIT-T passed to 3500 psi on 05/10/04, demonstrating the tubing is capable of withstanding injection pressure. . A MIT-OA passed to 2500 psi on 05/08/04, demonstrating the surface casing is capable of withstanding injection pressure. . Pressures and injection rates will be monitored and recorded daily and checked for indications of a tubing leak. Proposed Action Plan 1. Allow well to continue water injection only. 2. Record wellhead pressures and injection rates daily. 3. Perform annual MIT-OA. 4. Perform 4-year MIT-T. 5. Stop injection and notify the AOGCC if there is any indication the tubing has lost integrity. TREE = Wa.LHEAO = A en.LA. TOR = KB. ELEV = SF. ELEV = KOP= Max Ange = Datum MO = Datu m TVO = FMCGEN 3 FMC AXELSON 71' 4400' 17 ~ 6200' 8979' 8800' SS 11 :>-3/8" CSG, 72#, L-80, 10 = 12.347" H 2477' ~ Minimum ID = 3.813" @ 8624' 4-1/2" Cameo DB-5 LDG Nipple 12-23 8 :8: I ~ I 1 TOP OF 5-1/2" lEG-PC H 8517' I r 15-1/2"TBG, 17#, L-80, .0232 bpf, 10=4.892" H 8510' ~ \ ) 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" H 8550' I 1 TOP OF 4-1/2" lEG-PC H 8550' 1 1 :8: :><: ITOPOF7" LNR 1-1 8604' 1 -. I I- 14-1/2"TBG-FC, 12.6#, N-80, .0152bpf, 10= 3.958" H 8636' 1 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 8895' --4 PERFORATION SUMMA.RY REF LOG: BHCS ON 05/16/84 ANGLEATTOPÆRF: 1 @8900' I'bte: Refer to A'oductbn œ for historical perf data SIZE SA= INTERVAL Opn/Sqz DATE 3-318" 4 8900 - 8923 0 06/04/89 3-318" 4 9000 - 9040 0 11/30/84 3-318" 4 9052.9092 0 11/30/84 3-318" 4 9106 - 9144 0 11/30/84 3-318" 4 9106-9164 0 11/10/92 3-318" 4 9144-9164 0 08/07/87 I R3TO 1-1 9334' I T' LNR, 29#, L-80, .0371 bpf, 10 = 6.184" l-i 9380' I ... ~~ OA.TE REV BY COMrvENTS DATE REV BY COMMENTS 05/19/84 ORIGINAL COMPLETION 01/26/97 LAST WORKOVER 01/06/02 RN/W CORREC1l0NS 02/09/03 A TOffP SAFElY NOTE Q;ANGE TO WI~: 10/31/03 JJ/TLP CORRECT XN NIP 10 TO 4.455" ( SAFETY NOTES: AiLITIW HBBP PKRS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACT WIE (x51 02) PRIOR TO TESTING. 2229' H5-1/Z' HES t-RQ SSSV NIP, 10 = 4.562" I ~ 8487' H9-5/8" X 5-1/2" TIW HB-BPT A<R I 8503' H5-1/Z' HES XN NIP, 10 =4.455" I 8504' H5-1/Z' XO PERPO FUP I 8510' H5-1/Z' OVERSI-K)T 1 8537' H5-1/Z' BAKER R3RASSY I 8550' H5-1/Z' X 4-1/2" XO 1 8561' 1-19-5/8" X 4-1/2" BA KER FH. PKR I 8624' 1-14-1/2" CAM OB-5 LANDING NP, ID = 3.813" I 8635' 1-14-1/Z' BAKER SHEAROUT SLB 8636' H4-1/Z' TLBING TAIL I 8633' Ha.MOTTLOGGE002/15/89 I PRUOI-K)E SA Y LtJIT WELL: 12-23 PERMT I'b: 1840580 APII'b: 50-029-211 OS- 00 SEe 18, T10N, R15E, 5110.58'FEL& 5028.5'FNL BP Exploration (Alaska) . ( ( bp BP Exploration (Alaska) Inc. 0, . Post Office Box 196612 PRB-20 Anchorage Alaska 99519-6612 December 15, 2003 Mr. Winton Aubert, P. E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 12-23i (PTD 1840580) Application to cancel Sundry #300-174 Dear Mr. Aubert: Attached is Application to Cancel Sundry form 10-404 for Sundry #300-174. This request is to cancel the current sundry for IA x OA communication at well 12-23i. The well has recently become a L TSI well and is secured with a tubing tail plug. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Attachment: 1) Application for Sundry Cancellation form 10-404 RECEIVED DEC 1 8 2003 Alaska Oil & Gas Cons. Commission Anchorage sc£.\r'\t,~~t:t) JP~N ~& @ 2001- --'~'\J ~U'~,,~L.. '" n ~ r . f\ , ^,. " ("). "'. 1 ,\ \ "\ , ~ ,~ ." STATE OF ALASKA II" ALAS~ )IL AND GAS CONSERVATION CO~.. .3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Suspend 0 Operation ShutdownD Perforate 0 VarianceD Annular DisposalD Alter CasingO Repair WellO Plug PerforationsO Stimulate 0 Time ExtensionD Other[!] Change Approved ProgramO Pull TubingO Perforate New Pool 0 Re-enter Suspended wellD Cancel 10-403 2. Operator I 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 184-0580 Development 0 Exploratory 0 3. Address: I P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 Service I!) 50-029-21105-00-00 7. KB Elevation (ft): 9. Well Name and Number: 71.00 12-23 8. Property Designation: 10. Field/Pool(s): ADL-D028330 Prudhoe Bay Field / Prudhoe 011 Pool 11. Present Well Condition Summary: Total Depth measured 9380 feet true vertical 9272.4 feet Plugs (measured) None Effective Depth measured 9334 feet Junk (measured) None true vertical 9226.5 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30.0 - 110.0 1490 470 Liner 776 7" 29# L-80 8604 - 9380 8496.5 - 9272.4 8160 7020 Production 7726 9-5/8" 47# L-80 26 - 7762 26.0 - 7644.9 6870 4760 Production 333 9-5/8" 43.5# S-95 7752 - 8085 7644.9 - 7977.6 7510 4130 Production 732 9-5/8" 47# N-80 8085 - 8817 7977.6 - 8709.5 6870 4760 Production 77 9-5/8" 47# L-80 8817 - 8894 8709.5 - 8786.5 6870 4760 Surface 2448 13-3/81172# L-80 29 - 2477 29.0 - 2476.7 4930 2670 Perforation depth: Measured depth: 8900 - 8923,9000 - 9040,9052 - 9092, 9106 - 9144,9144 - 9164 True vertical depth: 8792.5 - 8815.5,8892.48 - 8932.47,8944.47 - 8984.47,8998.47 - 9036.47,9036.47 - 9056'~EC E IVE D Tubing (size, grade, and measured depth): 5-1/2" 17# L-80 @ 28 - 8481 r\ 5-1/21117# NT80S @ 8481 - 8517 DEC 1 8 2003 4-1/2" 12.61 N-80 @ 8537 - 8636 Packers & SSSV (type & measured depth): 5-1/211 HBBP-T Packer @ 8487 Alaska Oil & Gas Cons. Commission 4-1/211 Baker FHL Packer @ 8561 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averace Production or Inlection Data Oil.Bbl Gas.Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentD Service[!) Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilO GasO WAGO GINJO WINJI!J WDSPLD Daily Report of Well Operations - Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact J hn C b 300-174 Printed Name Title Well Integrity Engineer Signature Phone 659.5102 Date 12/15/03 FORn lOR \ G \ 8ft DEe 2;;. .3 PBU 12-23 Subject: PBU 12-23 Date: Tue, 30 Sep 2003 08:53:57 -0800 From: Jim Regg <jim_regg~admin.state.ak.us> Organization: AOGCC To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> CC: Winton G Aubert <winton_aubert~admin.state.ak.us>, Steven Rossberg <RossbeRS~BP.com> I have been reviewing the files of wells with MIT failures during the past year. Well 12-23 was reported as a "137 A/B3" well in September 2002. Per our letter approving the restart of BP's "137 A/B3" wells (October 29, 2002), a sundry approval was required for Well 12-23 prior to restart. Recent events: - failed MIT (3 tests) on 4/8/03; AOGCC witnessed - well was placed back on water injection in June 2003 according to AOGCC records [June - 4396 bbls (11 days); July - 549 bbls (5 days); Aug - 13,977 bbls (14 days); Sept - ?] . I have not been able to locate the sundry that grants approval for this well to be operating; also, there is nothing in our files that indicates any repair or passing MIT that would be a basis for restarting this well. Please review and provide an update by 10/3/03. Jim Regg Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 1 of l SO'"/~I¢~ ~0'~ ~ I 200~ 10/2/2003 6:06 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: April 8, 2003 Commissioner THRU: Maunder/Regg <~e~ ~1';~{0.~UBJECT: MechanicaIBPx Integrity Tests Petroleum Engineer Drillsite 12 FROM: Lou Grimaldi Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 12-23 Type Inj. S T.V.D. 8487 Tubing Vacuum Vacuum Vacuum Vacuum Interval V '" i .,;.i..::'! '.!~;"ii.:'i:.;?:':::?:~il :; ::::.:!..i.... . ..:.;:i !!. :...'.....! .. i:..::.: !. · · · .' I.A 500 2490 2335 2230 P.T.D. 184-0580 Type test P Test psi 2122 O.A 460 700 700 680 P/F F Notes: First test, I.A pressured only Well 12-23 Type Inj. S T.V.D. 8487 Tubing Vacuum Vacuum Vacuum Vacuum Interval V : .:.. : ..... :.:., ......... '..:.' :...~.' ::'.'.' :.:' .2".'i"::i' '"i::'.::':' :'":i" ~. 'i;'.:.:.;: ".::. ;.'~. :.' ~:.:. :' ~: :.. !."." :::."'.."!::;:' :' !.":::..': ...... ~r':~: .~::::':' :..:.~ ::.': :.::.::.:: :....::.'~ I.A 2200 2540 2400 2280 P.T.D. 184-0580 Type test P Test psi. 2122 O.A 680 2520 2460 2400 P/F ~F Notes: Second Test, Combo I/A, O,A. pressure test. Well 12-23 Type Inj. S T.V.D. 8487 Tubing Vacuum Interval V ':i =..;"::.?i;;.'i.:.?:i;' ~;:;~:!?':::~:~::;.:?.~?:! ::i'ii: ?i ?::'~'=!!~::'=:?i;;.?.;: i~";:!~'!':.:':."!'.!'~'~:'::~:':'.i:~;:;.;~:i:~..'=::::~.i.:.;'::~;; :~'~:: :.:'?.. !. ':.. .'~.:~ !: I.A 2280 2160 P.T,D. 184-0580 Type test P Test psi 2122 O.A 2400 2320 P/F ~F Notes: Extension of second test. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING P=Produced Water Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) I witnessed the combination MIT of the IA/OA on this WAG injector. The first test was attempted by just pressuring up the IA, the IA lost 260 psi over thirty minutes (linear). The IA and OA were pressured back up together and fared no better. As the tubing was on vacuum, we could not determine if the leak was into it. This well failed its combo MIT, setting an tubing plug may help determine leak path. M.I.T.'s performed: Two Attachments: None Number of Failures: One Total Time during tests: 3 hours ,CC: MIT report form 5/12/00 L.G. ANNEr Z 7 2003 2003-0408_MIT_PBU_12-23_Ig.xls 5/5/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill "t'''~''' Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: January 14, 2003 .. SUBJECT: Mechanical Integrity Tests -~ ~,~.' BPX - % ' PBU Prudhoe Bay -- Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 179-032 TypetestI P Test psi 2121 Casing 175 - 2 0 2 0 2420 P/F I ~ Notes: ~B3 well. Required 41.6 bbls to fill IA we,,I ~2-23 Imype,nj.I N I~.v.~.l ~o Tubing 0 0 0 0 Inte~al O P.T.D. ~ 1~058 Type testl P Test psi 2095 Casing 50 2480 2360 2240 P/F [ OA 100 2480 2400 2340 Notes: ~B3 well. Required 61 bbls to fill IA ,I i i I'nte a'l O ~.I.D.I ~08-~42 IIgpotostl ~ Iest psi 2~27 Casin~ 20 '2500 -2430 2420 ~/F ~ ~ ~ot~: ~B3 woll. Required 22 bbls to fill I~ . We,I Type Inj. I T.V.D. P/F I ~ot~: ~/~ I- -' ~ot~: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey. D= Differential Temperature Test Interval I-- Initial Test 4= FourYear Cycle V= Required by Variance W= Test during Workover · O= Othe~ (describe in notes) Test's Details I traveled to BPXs Drill Site 12 and witnessed MITs on wells 12-02, 12-23 and 12-30.' Wells 12;02 and 12-30 appeared. to have mechanical integrity during the 30-minute pressure test. Well 12-23 has knox, va IA x OA communication and this test was performed with IA and OA in combination. The test was held for an additional 15-minute period showing the OA pressure loss stabilized at 60 psi and the IA at 100 psi per 15-minute period. M.I.T.'s performed: _.3 Number of Failures: '1 Attachments: Annular Communicstion History Total Time du~rij3g .tests~,~ houm- CC: MIT report form 5/12/00 L.G. 'MIT PBU DS 12 1-14-03 CS.xls 1/17/2003 Annular Communication History Well 12-30 Type WAG Problem: Slow IA x OA Communication on MI *** Class A - Well SI and Secured *** MITIA passes. OA.Not Amtic Packed, LLR 3 bpm at 1750# 3Q99 AD60 444 psi Date Status: MI injector, has POGLM's. If T x IA communication post MI injection, may have to pull POGLM's and run patches. Well is secured. · 02/19/99: MITIA Passed (by LRS), PPPOT-T Pass, PPPOT-IC Fail · 02/20/99: PPPOT-IC to 3000 psi PASSED, req'd WKM sealant in Y-seal · 7/5/99: MI Conversion. · 08/09/99: PPPOT-IC Passed @ 3000 psi. PWI injection started. · 08/17/99: State witnessed MITIA @ 2450 psi Passed. · 05/08/00: SL ran SSSV for MI injection · 09/02/00: DSMVC: Pumped GX sealant into Control/Bal. PASSED · 03/07/02: DSO bled OA 1300 · 550 · 03/18/02: DSO bled OA 1100 · 600 · 05/02/02: OA repressures 130 psi / day · 08/26/02: Load well to secure · 09/16/02: Email to Maunder, IAxOA comm. Will conduct MITIA then review results with AOGCC. · 09/28/02: MIT IA to 3000 psi Passed L&K well · 09/28/02: L&K · 09/29/02: Sent e-mail note to maunder with MIT IA results. · 10/17/02: MITOA Failed, LLR=2 BPM @ 1300# · 11/24/02: LNFT-OA Passed · 12/07/02: PPPOT-T Passed, PPPOT-IC Failed (State Notified) Comment Planned Action: **'137-A Well*** Obj: Eval IAxOA comm 1. FB: MIT-OA to 3000 psi - FAIL 2. DHD: Pressure IA to 2000# with gas, NFT-OA, .monitor OA BU (use chart).- DONE 3. DHD: Bleed IA and OA - DONE 4. DHD: State witnessed MITIA. 1/11/2003 1/10/2003 12/7/2O02 12/3/2002 12/2/2002 11/30/2002 11/30/2002 11/29/2002 11/26/2002 11/25/2002 11/24/2002 11/23/2002 1/14/20o3 TIO= 1760/60/5 Monitor WHP's. Post OA bleed. T/I/O=1700/1040/0 Well SI @ Wing Valve. Bleed IA (Pre State MITIA). Initial'lA FL @ 270' (12 bb'ls). Initial IA pressure @ 1040 psi. Bled IA to 30 psi.Final WHP's 1700/30/0 TIO = 1800/1500/0 PPPOT-T PASSED. (AOGCC was notified of test) Bled off test void pressure to 0 psi. - Rig up and test tubing hander void to 5000 psi for 30 rains. Lost 0 psi in 30 mins. Passed. PPPOT-IC Failed. Test void pressure would not bleed down. Re-torqued LDS, pressure still would not bleeddown: Y-B seal has been packed off with green packing, unable to re-pack seal. Suggest bleedingOA and IA down so that purging old plastic from seal and re-energizing with new plastic may be attempted. - T/I/O= 1720/1560/20 R/D chart recorder. T/I/O=1720/1580/20 Monitor WHP's (OA BUR) '. T/I/O=1750/1480/0 (OA BUR) Monitor WHP's. T/I/O=1760/1450/10 Monitor oA BUR. Changed chart. Re-pressured IA with A/L gas from 1450 psi to 1660 psi and the OAP increased to 30 psi. Final WHP's = 1760/1660/30 TIO= 1700/1510/10 Monitor WHP's. (Monitor OA BUR) T/I/O = Sl/1620/10. Monitor WHP's. (OA BUR). T/I/O = 1700/1675/10..(Monitor OA BUR). T/I/O = 1650/1750/300. LNFT- OA PASSED. (Waiver~Eva~". 'Well i~ FL. @ Surface. Bled OA from 300 psi to 0+ psi in 5 min. Started LNFT. Liquid Flow Rate = 0.4 gal in 10~min. Monitored pressures for 30 .. min. Final WHP's = 1650/1750/26. T/I/O = 1700/1800/310. (Monitor OA BUR). Page 1 of 4 Date Comment 11/22/2002 10/19/2002 10/17/2002 10/14/2002 10/4/2002 9/28/2002 9/28/2002 9/28/2002 9/21/2002 9/17/2002 8/26/2002 8/25/2002 8/25/2002 8/25/2002 8/24/2002 5/16/2002 5/10/2002 5/2/2OO2 4/29/2002 4/28/2002 3/5/2002 5/25/2001 11/22/2000 10/29/2000 10/15/2000 10/14/2000 10/14/2000 10/13/2000 1/14/2OO3 T/I/O = 1650/720/200. RU Chart Recorder, Pressure IA and Monitor OA BUR. Pressured IA to 1900 psi in 1.25 hr. OAP increased from 200 psi to 360 psi. Monitored pressures for 30 min. Final WHP's = 1650/1900/350.. TIO= 1825/500/100 (OA Project) MIT OA TO 3000 PSI, FAILED WITH A LEAK RATE OF 2 BPM AT 1300 PSI TIO= 1840/500/0 (OA Project) T/I/O = 1250/475/0. Monitor WHP's [post Load & Kill] Load and kill well ....Well Shut In upon arrival.* ....... Pump 5 meth/wtr, 180 seawater, 68 flopro, 250 seawater, 60 meth/wtr down the tubing. Final tubing TIO pressures after well kill - 50/140/0. Left well shut in and tagged. MIT-IA to 3000 psi- Passed T/I/O 75/142/0 MITIA passed to 3000 psi. Loast 50 psi in first 15 rain and 0 psi in second for a total of 50 psi in 30 min test. Final WHP 75/0/0 T/I/O = 75/142/0, MITIA PASSED TO 3000 PSI, lost 50 psi in first 15 min. and 0 psi in second for a total of 50 psi in 30 min. test. FINAL WHP's 75/0/0 T/I/O = 1900/660/0 (For big DAVE WENDT). Initial TBG FL @ 1350', Initial IA FL @ 90'. TBG is F/P w/60 bbls of methanol and IA is F/P w/52 bbls. T/I/O = 1900/700/20 (Prep for MITOA) FL @ 630'. Load well to secure. Continued from 8/25/02. Class A trouble well. Bled and monitored OA for repressurization rate and well secure, Bled IA in prep for load. Load well to secure. T/I/O = 2120/840/840 BLEED IA and OA, MONITOR during well kill (Class A trouble well) OA FL @ 700'. Bled OA from 840 psi to 600 psi in 15 min. Monitor for 15 min. OA pressure increased 10 psi to 610 psi. Bled OA from 610 psi to 425 psi in 15 min. Monitor for 15 min. OA pressure increased 5 psi. WHP's = 2120/810/430 IA FL @ 1175' (52 bbls). Bled IA from 840 psi to 380 psi in 45 mins. Pump truck rig up to load IA. Pump truck start IA load (2240 hrs), restart OA bleed. IA loaded with 52 bbls methanol, OA pressure at 100 psi and bleeding. Pump truck rig up to TBG. WHP's = 2120/1750/100 Pump truck start pumping down TBG (2340 hrs). Continue to bleed OA. Bled.OA from 100 psi to 0 psi. IA pressure came down to 750 psi while pumping down'TBG. Pump truck shut down (0105 hrs) and WHP's = 225/750/0 (TBG pressure falling slowly) Turn four hour monitor over to Well Support. FINAL WHP's = 150/750/0 T/I/O = SI/840/840 OA FL (Class A trouble well, prep for TBG and IA load and kill) IA FL @ 1175' (52 bbls) T/I/O = 2580/990/930. Monitor WHPs post-OA bleed (eval for IAxOA waiver). OAP dropped 70 psi in 6 ' days. T/I/O = 2550/1000/1000 Monitor WHP's Post OA bleed (Eval IA x OA comm). OA Psi is up 250 psi in 8 days. T/I/O = 2650/1000/750 Monitor WHP's Post OA bleed (Eval IA x OA comm)- OA psi is up 380 psi in 3 days. T/I/O = 2650/1000/370 Monitor WHPs post OA bleed (eval IA x-OA comm). ' T/I/O = 2700/1000/940 AC EVAL high OA P; IA FL at 920'. OA FL at 340'. Bled OA from 940 psi to 340 psi in 1 hr. OA FL was at 315' after bleed. FINAL WHPs=2700/1000/340 SCHMOO-B-GONE Treatment with MEOH break over and S.W. Flush after 3 hour soak. SBG TREATMENT PUMPED DOWN TBG. 344 BBLS OF SBG. AVE RT = 2 BPM AVE PSI = 1600 PSI T/I/O = 2700/1300/200 Monitor WHP's post IA bleed.. IA pressure increased from 330 psi to 1300 psi since 10/29/00. (quarterly injector eval). T/I/O = 2400/900/200 IA FL near surface. Bled IA from 900 psi to 300 psi in 20 mins. Shut in and monitored for 30 mins. IA rose to 330 psi. Final WHP's= 2400/330/200. SET 5 1/2" CAMCO WRDP-2 3 SETS OF PACKING BAL. OPERATED # HZS-102 sET @ 2174' SLM, NO CLOSURE TEST PERFORMED. HOLDING 4500 LBS ON BALANCE LINE. RDMO TO 12-21 RIH WHILE PUMPING DOWN WELL. TAG FILL AT 11346'. CLEAN OUTTO 1140 FT. CHECK FOR FILL - OK. POOH. BULLHEAD 290 BBLS SBG D.:..O...V=.V~,N_BACKSlDE. FLUSH W/480 BBLS 1% KCL. FREEZE PROTECT TO 2500' WITH METH. "~ ...... [FCO] SET UP EQUIPTMENT, PIN SSSV -READY TO RUN -SECURE EQUIPTMENT FOR NIGHT. 'IFS. MIRU. PRESSURE TEST SURFACE LINES AND EQUIPMENT. A'I-rEMPT TO KILL WELL. PRESSURE Page 2 of 4 ~CANNED ~P-E-~.~ .-- Date Comment 10/13/2000 9/1 O/200O 5/7/2OOO 5/6/2000 11/23/1999 8/17/1999 8/17/1999 8/13/1999 8/9/1999 8/9/1999 8/9/1999 6/30/1999 3/6/1999 3/3/1999 2/26/1999 2/23/1999 2/21/1999 2/20/1999 2/20/1999 2/19/1999 2/19/1999 2/17/1999 2/5/1999 2/2/1999 1/23/1999 11/8/1998 1/14/2003 INCREASED TO 2700 PSI. BLEED WELL TO FLOWLINE THRU 12-7A. CHOKES ON MANIFOLD NOT WORKING. CHANGE OUT CHOKE MANIFOLD. PRESSURE TEST LINES AND CHOKE MANIFOLD. PULLED SSSV.# HBS-691 FROM 2183' SLM. (5 1/2" CAMCO WRDP-1) DRIFT AND TAG W/2.25" CENT, TEL, SB TO 11327' COR ELM, SAMPLE OF SHMOO, 31' OF FILL ABOVE OPEN PERF'S [Tag, Maintenance] SET WRDP-2/BAL OPER/3 SETS PKG/SER# HBS-691. [SSSV Work] TAG SCHMOO AT 1045' SLM W/4.5 CENT. [SSSV Work] T/I/O = 1100/480/480 OA FL @ surface, for WC. STATE WITNESSED MITIA TO 2450 PSI PASSED. . . [MITIA] T/I/O = 880/680/650 State Witnessed MITIA to 2450 psi PASSED; IA FL'near surface. OA FL near surface. Bled IA from 680 psi to 160 psi in 50 mins. Pressured IA to 2450 psi. MITIA lost 30 psi in 15 rains, 20 psi in the second 15 mins, for a total of 50 psi in 30 mins. Pumped a total of 5 bbls of methanol down the IA. Final WHP's = 880/130/700. T/I/O = 840/740/660 IA FL @ surface. OA FL @ surface. Prep for MITIA. PPPOT-IC TO 3000 PSI PASSED. [Ann Comm, WH Maintenance] PWI injection started into well (converted producer). T/I/O = 850/800/800 PPPOT-IC to 3000 psi PASSED; Stung int° IA X OA test port had 120 psi, bled to 0 psi. Flushed through test port with hydraulic fluid and got back good returns. Pressured PKO to 3000 psi. PKO test lost 40 psi in 15 mins, 30 psi in the second 15 rains, for a total of 70 psi in 30 mins. Final WHP's = 850/800/800. T/I/O = SI/200/300 OA FL at surface. T/I/O T/I/O T/I/O T/I/O T/IlO = SI/150/450 OA FL at surface. Monitor OA post load. = SI/100/450. OA FL @ surface, post Load & LLR-OA. = SI/60/450. OA FL @ surface. Post OA LLRT 2/20/99. = SI/50/450 OA FL @ surface. Post LLRT OC. = 900/50/450 IA FL @ Surface, OA FL @ surface. Post OA load. T/IlO = 900/50/400 PPPOT-IC to 3000 psi PASSED: Test port @ 50 psi, would not bleed to 0 psi. Y-seal @ 50 psi, would not bleed to 0 psi. Attempted to pressure up test port. Test port would not pressure up above 50 psi (IA pressure). Had to bleed IA down to 0 psi to get test port and Y-seal to bleed off to 0 psi. Bled OA to 0 psi prior to pumping sealant. Pumped 1/4 of an injection gun of WKM sealant into Y-seal area. Pressured Y-seal up to 3000 psi held for 30 mins PASSED. Pressured test port to 3000 psi: Test #1 lost 120 psi in 15 mins, 80 psi in second 15 mins, 200 psi total. Test #2 lost 40 psi in 15 mins, 60 psi in' second 15 rains, 100 psi total. Final WHP's = 900/20/0 T/I/O = SI/50/0. DS loaded OA with 277 bbl crude and 5 bbl diesel. LLR-OA= 3 bpm @ 1750 psi. Bled OA to 500 psi. Final= SI/100/500. T/I/O = 900/650/1200 PPPOT-T: Initial IA FL @ 20', OA FL @ 3455'. Bled IA fr°m 650 psi to 0+ psi in 10 mins. Bled OA from 1200 psi to 0+. psi in 6 hrs. Re-moved internal checks on test port and packing port from both Tbg and IA hanger. PPPOT-T to 5000 psi PASSED; Flushed through got good returns. Test lost 300 psi in 30'rains. PPPOT-IC to 3000 psi FAILED; Flushed through got good returns. Pressure dropped off from 3000 psi to 0+ psi in 5 mins. Tightened lock down screws to 600 lbs. Retested, pressure dropped off from 3000 psi to 0+ psi in 5 rains. May need to re-energize Y seal. Final WHP's =900/0+/0+ . T/I/O =400/0/1300. LRS pumped MITIA Passed to 3000#. 1st attempt Failed, lost 200# in '15 min. 2nd attempt lost 75 psi in 1st 15 min, 50 psi in 2nd 15 min. Bled IA to 500#. Final=450/500/!300 T/I/O =950/1300/1500 TIFL FAILED (Prep for MITIA): Initial IA FL @ 1820' (88 BBLS). Bled IA from 1300 psi to 0+ psi in 4 hrs. IA FL rose from 1820' to near surface. OA FL @ 3455' (201 BBLS). Bled OA from 1300 to 1200 psi in 30 mins (all gas). Fluid level remained unchanged on the OA. LRS on location to perform MITIA. Final WHP's= 950/0+/1200 T/I/O = 680/400/1700 IA FL at 1460 (64 bbls).~..r~ep...for MITIA. ..~. Dowell crew pumped load & kill. T/I/O = 2000/2000/2000 TBG FL @ 8400' (195 BBLS). IA FL @ 7822~ (343 BBLS). Flowline is freeze protected. Tank can be staged between wells 12-30 and 12-08. Prep for L & K. Checked Rig files; OA not Arctic Packed. Page 3 of 4 Date Comment 11/8/1998 11/6/1998 T/I/O = 400/1550/560 TIFL PASSED (Pre MI conversion); Bled IA from 1550 psi to 230 psi in 2 hrs. IA FL started @ 7550' and rose to 7340'. Monitor IA pressure for I hr with no increase in pressure. MITOA INCONCLUSIVE; OA FL @ 160' (10 bbls). Bled OA from 560 psi to 60 psi in 2 hm. MITOA would not pressure above 950 psi. Pumped 21 bbls of fluid down OA, ran out of diesel will return at a later date. FINAL WHP's 400/230/500. T/I/O = 250/1680/600. IA FL @ 7288' (POGLM), OA FL @ 168' (10 bbls). McEvoy tree with internal checks on hangers. ~/~4/2oo3 SCANNED~PR ~ 5; 20133 ""g" 4 of. R.~: WelF-~ 2-23 (PTD 184-058) Failed MITIA Subject: Re: Well 12-23 (PTD 184-058) Failed MITIA Date: Tue, 13 Jun 2000 07:49:41 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: PRB Problem Wells <P1041@ppco.com> Thanks Joe, we look forward to receiving the action plan and sundry. Tom PRB Problem Wells wrote: Hello Tom. We have completed evaluation of well 12-23's wellhead. The 9-5/8" hanger seals tested good to 3000 psi. The leak point between the 9-5/8" and 13-3/8" casing appears to be downhole. Our proposed plan is to continue injection while pursuing a Sundry for IA x OA communication (similar to well 03-10). We will have a completed 10-403 and proposed action plan in the mail by the end of the week. Please call if you have any questions. Joe Anders, PE Problem Well specialist Phillips Alaska, Inc. (907) 659-5102 p l O41@ppco. com 08:59 PM Forvarded by PRB Problem Wells/AAI/ARCO on 06/12/2000 "PRB Problem Wells" <p 104 l @bvlnotes 10. ppco. com> on 06/1 2/2000 02: 57:48 PM To: Tom Maunder <torn_maunder~admin. state, ak. us> cc: (bce: PRB Problem WelIs/AAI/ARCO) Subject: Re: Well 12-23 (PTD 184-058) Failed MITIA 12-23 injection pressure is 1280 psi @ 16, 000 BWPD. We are troubleshooting the tree and should know if there is something we can fix in the next day or so. Joe Tom Maunder <torn_maunder@admin. state, ak. us> on 06/12/2000 06:56:15 AM To: PRB Problem WelIs/AAI/ARCO@Arco cc: blair_wondzell@admin, state, ak. us, john_spaulding@ admin, state, ak. us Subject: Re: Well 12-23 (PTD 184-058) Failed MITIA What injection pressure are they seeing?? Please keep us informed of the evaluation results. Tom PRB Problem Wells wrote: > Hello Blair and Tom 1 of 2 6/13/00 8:42 AM R~: WeiP12-23 (PTD 184-058) Failed MITIA ,,,. · Well 12-23 (PTD 164-058) failed an MT-IA on 6/9/00 due to lack of pressure · stabilization. During pre-pit de~tetering pressure testing, a steady pressure · loss of 100 psi/15 minutes was observed. The OA pressure increased during the · testing so a combination IA x OA MIT was conducted and passed to 2000 psi. 12-23 · is currently injecting produced water. The production casing to surface casing · leak location is unknown. · Plan is to leave the well online while evaluating the leak source. We will keep · you informed of progress. Please call if you have any questions. Joe Anders, PE Problem Well Specialist Phillips Alaska, Inc. (907) 659-5102 p l O41@ppco. com i" Tom MaUnder <tom maunder~,admin.state.ak, us> ~'~e"~m ~eer Alaska Oil and Gas Conservation Commission 2 of 2 6113/00 8:42 AM Veil 12-23 (PTD 184-058) Failed MITIA Subject: Well t2-23 (PTD 184-058) Failed MITIA Date: Sun, 11 Jun 2000 20:56:22 -0900 From: "PRB Problem Wells" <P1041@ppco.com> To: blair_wondzell@admin.state.ak, us, tom_maunder@admin.state.ak, us CC: john_spaulding@admin.state.ak, us Hello Blair and Tom. Well 12-23 (PTD 184-058) failed an MIT-IA on 6/9/00 due to lack of pressure stabilization. During pre-pit de~atering pre&sure testing, a steady pressure loss of 100 psi/15 minutes was observed. The OA pressure increased during the testing so a combination IA x OA MIT was conducted and passed to 2000 psi. 12-23 is currently injecting produced water. The production casing to surface casing leak location is unknown. Plan is to leave the well online while evaluating the leak source. We will keep you informed of progress. Please call if you have any questions. Joe Anders, PE Problem Well Specialist Phillips Alaska, Inc. (907) 659-5102 p1041@ppco.com lofl 6/12/00 7:56 AM ., state OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4988' FNL, 700' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 5039' FNL, 5117' FEL, SEC. 17, T10N, R15E, UM At effective depth At total depth 5029' FNL, 5111' FEL, Sec. 17, T10N, R15E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service ~X (asp's 696915, 5930601) (asp's 697779, 5930578.5) (asp's 697784,5930584) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-23 9. Permitnumber/approvalnumber 184-058 10. APInumber 50-029-21105 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 20" Surface 2406' 13-3/8" Production 8824' 9-5/8" Uner 776' 7" Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 938O 9272 9161 9053 feet Plugs (measured) Tagged PBTD @ 9161' on 8/19/1998. ;:;; Junk(measured) 0RI$1NAL feet Cemented Measured Depth True vertical Depth 1925# Poi@set 80' 80' 200 Sx PFE & 400 Sx PFC 2477' 2477' 500 Sx Class (3 & 300 Sx PFC 8895' 8787' 280 Sx C~ass e 9380' 9297' RECEIVED 8900'-8923'; 9000'-9040'; 9052'-9092'; 9106'-9144'; 9144'-9164'. JUN ;~0 Z000 Alaska Oil & Gas Cons. Commimio~ 8792' - 8815'; 8892'- 8932'; 8944' - 8984'; 8998'- 9036'; 9036' - 9056'. .~c~10{r~e 5-1/2,, 17#, L-SO Tbg @ 8510' MD; 5-1/2", 17#, L-S0 PCT @ 8550' MD; 4-1/2", 12.6#, N-SO, PCT @ 8636' MD. 9-5/8" X 4-1/2" BAKER FHL PACKER @ 8561' MD; 9-5/8" X 5-1/2" TIW HB-BP T PACKER @ 8487' MD. 5-1/2" HES HRQ SSSV @ 2229' MD. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation July 10, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Service Water Inj Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders/Jerry Dethlefs @ 659-5102 Signed ) (/'~ ~'v~'~''~ Title: P~.~]V/'Vl I~'~Jt." :~[j,~.;,.';,'"l' Date Prepared by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test__ Location clearance '~O{~ -- 117.~--.L.. ' Mechanical Integrity Test~ ~,, "~Ii;~~~~N~,~ ~t,~,~'~ ~'~,~%~'~{~t~, ORIGINAL SIGNED BY'-' D Taylor Seamount Approved Copy Approved by order of the Commission Returned/3/,) Commissioner Date7"'11'~ {P~ ,?,...,/2,-'--_ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE DS 12-23 Sundry Request SUNDRY DISCUSSION AND PROPOSED ACTION PLAN June 26, 2000 DISCUSSION Well 12-23 is a produced water injector exhibiting 9-5/8" x 13-3/8" pressure communication. An MITIA was performed on 6/9/00 pre-pit dewatering. The 2500 psi MITIA failed on pressure stabilization, loosing 200 psi in 30 minutes during which the OA pressure increased. A combination MIT 9-5/8" & 13-3/8" casing was conducted to 2000 psi which lost 20 psi in 30 minutes. The wellhead packoff assemblies were tested and found to be competent. This testing confirmed the integrity of the tubing, casing strings, packer, and OA cement shoe. This sundry request is to continue water injection into the well, based on the following information: · A combination MIT (9-5/8" x 13/3/8") passed 6/9/00 demonstrating mechanical integrity of the casing and injection in the approved zone; ' · Wellhead packoff assemblies have been tested and found to be competent; · Normal wellhead injection pressure is 1200-1500 psi on produced water injection service. PROPOSED ACTION PLAN · Continue water injection into the well; · Perform 2-year combination MIT 9-5/8" x 13-3/8" in lieu of normal 4-year MITIA; · Monitor wellhead pressures daily; · Shut-in and secure the well should MIT's or wellhead pressures indicate problems, and notify the AOGCC. RECEIVED JUN 30 ?.000 Ala~a Oil & Gas Cons. Commission .An~0~age ~.13-3/8" casing 2477' 5-1/2" Tubing 9-5/8"x4-1/2" packer, 8561' 4-1/2" Tubing EOT 8636' 9-5/8" casing, 8895' 7" Liner 8604'- 9380' Well Name: 12-23 (" Well Type: Injector Status: Injecting produced water. IA x OA Communication. 6/00 injection rate: 15,000 bwpd @ 1300 psi. Leak Location: Not known; may be packer or casing. Failed MIT IA on 6/9/00, IA bleed rate 100 psi/15 minutes. Passed CMIT IA xOA to 2000 psi on 6/9/00. 9-5/8" wellhead packoffs passed pressure test 6/12/00. RECEIVED J U N ,~ 0 2000 Alaska 0it & Gas Cons. Commission Anchorage Phillips Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 June 27, 2000 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: DS 12-23 (PTD 184-058) Sundry Notice Variance Request Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 variance request for well 12-23 (PTD 184-058). The request is for approval to continue produced water injection with known production casing by surface casing communication. Also attached is a proposed Action Plan and a wellbore schematic. If you require any additional information or clarification, please feel free to contact either Jerry Dethlefs or me at (907) 659-5102. Sincerely, Joe Anders, PE Problem Well Specialist Attachments RECEIVED JLJN 30 ~000 Alaska 0i~ & Gas Cons. Cornmissio~ Anch~'age "' STATE OF ALASKA " ALASK~{'{' ,JIL AND GAS CONSERVATION C~,v, MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--I Operation Shutdown I--IStimulate I--I Plugging [--I Perforate [--I Pull Tubing [--IAIter Casing [--} Repair Well [--I Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) ARCO Alaska Inc. [--I Development RKBE = 71' 3. Address [--I Exploratory 7. Unit or Property Name F-] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [~Service 4. Location of well at surface 8. Well Number 289' NSL, 700' WEL, SEC. 18, T10N, R15E, UM 12-23i At top of productive interval 9. Permit Number / Approval No. 244' NSL, 165' EWL, SEC. 17, T1 ON, R15E, UM 84-58 397-010 At effective depth 10. APl Number 50-029-21105 244' NSL, 165' EWL, SEC. 17, T10N, R15E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 248' NSL, 169' EWL, SEC. 17, T10N, R15E, UM Pool 12. Present well condition summary Total depth: measured 9380 feet Plugs (measured) true vertical 9272 feet Effective depth: measured 9334 feet Junk (measured) true vertical 9226 feet Casing Length Size Cemented MD 'I'VD Structural Conductor 80' 20" 1925# Poleset 80' 80' Surface 2406' 13-3/8" 200 sx 'E', 400 sx 'C' 2477' 2477' Intermediate Production 8824' 9-5/8" 500 sx 'G', 300 sx PF 'C' 8895' 8787' Liner 776' 7" 280 sx Class 'G' 9380' 9272' Perforation depth: measured 8900' - 8923', 9000' - 9040', 9052' - 9092', 9106' - 9144', 9144' - 9164' true vertical 8792' - 8815', 8892' 8932', 8944' - 8984', 8998' - 9036', 9036' - 9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 8517'; 5-1/2", 17#, L-80 8517' to 8550'; 4-1/2", 12.5#, N-80 8550' to 8636' Packers and SSSV (type and measured depth) 5-1/2" x 9-5/8 TIW packer at 8487'; HES 5-1/2" HRQ SVLN at 2229' 13. Stimulation or cement squeeze summaryNAL ' Intervals treated ,measured) ORIGI JUN 19 1997 Treatment description including volumes used and final pressure ~..~3~.'.0jl & Gas CoDs. ' ~ncl~i0rage 14. Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [--~ Copies of Logs and,,,.%urveys run [--~ Oil [~ Daily Report of Wr~l G~perations /~ '' [--I Gas I~ Suspended Service Water & Gas Injector 117. I hereby certify that t ~e~/ore. g°i~q~s j~r!~ and, correct to the best of my knowledge Signed j FFO, j~ ~. ~ F-.___.~.----,~ PauIPrince Title Senior Drilling Engineer Date " Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate ,, Progress Report Facility PB DS 12 Well 12-23 Page 1 Rig Doyon 14 Date 17 June 97 Date/Time 20 Jan 97 06:00-14:00 14:00-06:00 21 Jan 97 06:00-02:00 22 Jan 97 02:00-06:00 06:00-07:00 07:00-08:00 08:00-12:00 12:00-12:30 12:30-14:00 14:00-16:30 16:30-16:45 16:45-20:00 20:00-22:30 22:30-23:30 23:30-00:30 23 Jan 97 00:30-06:00 06:00-08:30 08:30-09:00 09:00-10:00 10:00-13:00 13:00-15:30 15:30-15:45 15:45-18:00 18:00-18:15 18:15-01:30 24 Jan 97 01:30-02:30 02:30-06:00 06:00-10:00 10:00-12:00 12:00-13:30 13:30-15:00 15:00-19:15 19:15-20:30 20:30-20:45 20:45-21:30 21:30-23:00 23:00-04:00 25 Jan 97 04:00-06:00 06:00-06:00 06:00-07:30 07:30-09:00 09:00-10:30 10:30-15:00 15:00-17:00 17:00-18:00 18:00-19:00 19:00-19:30 Duration 8hr 16hr 20 hr 4hr lhr lhr 4hr 1/2hr 1-1/2 hr 2-1/2 hr 1/4 hr 3-1/4 hr 2-1/2 hr lhr 1 hr 5-1/2 hr 2-1/2 hr 1/2 hr 1 hr 3 hr 2-1/2 hr 1/4 hr 2-1/4 hr 1/4 hr 7-1/4 hr lhr 3-1/2 hr 4hr 2hr 1-1/2 hr 1-1/2 hr 4-1/4 hr 1-1/4 hr 1/4 hr 3/4 hr 1-1/2 hr 5hr 2hr 0hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr 2hr lhr lhr 1/2 hr Activity Rigged up Drillfloor / Derrick Rig waited: Production facilities Rig waited: Production facilities (cont...) Rig moved 100.00 % Rigged up Choke manifold Removed Hanger plug Circulated at 8515.00 ft Installed Hanger plug Removed Xmas tree Rigged up BOP stack Held safety meeting Tested BOP stack Removed Hanger plug Pulled Tubing on retrieval string to 0.00 ft Circulated at 8480.00 ft · Laid down 5850.00 ft of Tubing ' Laid down 2665.00 ft of Tubing Tested Bottom ram Tested Casing Ran Tubing to 0.00 ft (5-l/2in OD) Conducted sliekline operations on Sliekline equipment - Tool run Held safety meeting Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 6315.00 ft (5-1/2in OD) Tested Dual control line Ran Tubing to 8500.00 ft (5-1/2in OD) Circulated at 8517.50 ft Space out tubulars Conducted sliekline operations on Sliekline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Conducted sliekline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Rigged up Accessories Rigged down BOP stack Installed Xmas tree Installed Hanger plug Circulated at 8504.00 ft Circulated at 8504.00 ft Circulated at 8504.00 ft Rigged up Hanger plug Tested All tree valves Freeze protect well - 150.000 bbl of Diesel Tested Tubing Tested Casing Installed Hanger plug Serviced Fluid system Ala$ ,.Oil :& Gas, Cons. , c orage PLANNING PRUDHOE ID: FEB 15'97 15:17 No.O06 P.01 To: Blair Wondzell Subject: 12-23 MITIA and RWO costs Attached to this fax arc two documents which show the 12-23 MIT resulls that we had today. In addiQon I was able to track down an estimate of the final RWO repair co.~t. ($540,000) this number is still an estimate duc to thc' fact not all costs associated with the job have hit. the books yet and thus could be off +/- $10-15 M. I hope this is provides you with ~tll the information you need. Dave Smith · ..~-~,,. ~ z7t,-7gqL RECEIVED F£8 14. 1997 Anchorage PLANNING PRUDHOE ID: ! . F'ebruary 13, 1997 ( ~ DI-ID DAILY SUMMARY [WELL .... l'-~'~c ~A ~o~[ .... .... o~.s¢~!_i~'~zow I 2- I 3 T/I/O=1250/500/500 FEB 15'97 15:17 No.006 P.02 MITIA to 2200 psi PASSED; Bled OA from 500 psi I.o 80 psi in 15 mins IA pressure dropped to 340 psi. IA FL @ surface. Pressured IA to 2100 psi., OA was at 1380 psi. Bled OA to 80 psi. lA had dropped to 1940 psi. Pressured IA to 2200 psi. while bleeding OA to 70 psi. SI OA and begain MITIA. IA lost 50 psi in 15 mins, and a total of 70 psi in 30 min,n, Pumped a total of 5 BBLs of methanol to pressure IA. FINAL WHPs= 13001250ll O0 T/I/O= T/I/O= T/I/O= RECEIVED FEB 14. 1997 Alaska 011 & Gram Oon~. Commission Anohorege PLANNING PRUDHOE · ID: FEB 15'97 ,(" IULAR COMMUNICATION TESTILY. MECHANICAL INTEGRITY TEST 15:18 No.O06 P.0$ DATE: 2/13/97 WELL: 12-23 INITIAL PRESSURE DATA MIT: PAss Well Status: INJ TBG: 1250 CONTROL: NA ...... = .... :.. L ...... - ~-'.h ........... BLED CA FROM 500 TYPE OF FLUID AND VOLUME BLED: ~ : =- :':Z' : = ........ : TYPE: IA: 50O CA: 500 BALANCE: ....... · ....... - ! i i _ ;:'.""'. PRE-TEST PREPARATIONS PS1 TO 80 PS1 Methanol ......... ...... lid, fl TEST PRESSURES HFS 1 5 MIN IA & CA FLs @ SURFACE ......... , .~ .. · :--. TIME 'I'BG IA OA COMMENTS _~:..0..0 1250 340 70 S.T..ART PUMPING TIME ..... 11.~25 ..... 1 ,300 288..0 ................... 7 0 ' STAR ,T, , ,T,, ,E ST ....... 11:40 ..1300 8170 ._90. 50 psi lost 'i i';5S !_300 ............ 21,5,0 100 pass,, 70 psi Io~t..t.0.!.al .......... START TEST ..... . .......... _ ................ ,*.,. ........... _ ........ , ,,,,,, ,, i, ,,iiH · I ill I I )lkd ............. '" ............. B.T.,A_,R, T TEST TOTAL VOLUME PUMPED: 6 BBLs of METHANOL ~ ........ =. -: .... :.,- --:. ., ........... ._, , ~ ~., .................. FINAL pRESSURES TBG: 1300 IA; 250 OBSERVATIONS I COMMENTS CA: 100 ,--,'n,',,,,i i ...... . ...... ~ ._ - r ,, .. FINAL STEPS MUST BE COMPLETED AND CHECKED OFFlll -, FLAG THE WING VALVE IF SI AT TIME OF LOAOING AND TESTING, - NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL· Witness:~RJ/ME ................ ,.;-,.,:,,. ...... R ~ C ~lV ~ D FEB 14 1997 Alaska Oil & Gas Cons. C(~mmission STATE OF ALASKA ALASK/[{ulL AND GAS CONSERVATION cOMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimu!e. te 2. Name of Operator 15. Type of well: 6. ARCO Alaska Inc. I [] Development 3. Address [] Exploratory 7. [] Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. 289' NSL, 700' WEL, SEC. 18, T10N, R15E, UM At top of productive interval 244' NSL, 165' EWL, SEC. 17, T10N, R15E, UM At effective depth 244' NSL, 165' EWL, SEC. 17, T10N, R15E, UM At total depth 248' NSL, 169' EWL, SEC. 17, T10N, R15E, UM 12. Present well condition summary Total depth: measured 9380 feet true vertical 9272 feet Effective depth: measured 9334 feet true vertical 9226 feet [] Other Plugs (measured) Junk (measured) Datum Elevation (DF or KB) RKBE = 71' Unit or Property Name Prudhoe Bay Unit Well Number 12-23i 9. Permit Number 84-58 10. APl Number 50-029-21105 . Eield. and Pool .... I[~~ ~l~iV/Prudhoe Bay Pool ] 6 199 ~a,qka Oil & Gas Cons. Comm ion Anchorage Casing Length Size Structural Conductor 80' 20" Surface 2406' 13-3/8" Intermediate Production 8824' 9-5/8" Liner 776' 7" Perforation depth: measured Cemented MD TVD 1925# Polecat 80' 80' 200 sx 'E', 400 sx 'C' 2477' 2477' 500 sx 'G', 300 sx PF 'C' 8895' 8787' 280 sx Class 'G' 9380' 9272' ORIGINAL 8900'-8923', 9000'-9040', 9052'-9092', 9106'-9144', 9144'-9164' true vertical 8792'-8815', 8892'8932', 8944'-8984', 8998'-9036', 9036'-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT at 8550'; 4-1/2", 12.5#, N-80, PCT at 8636' Packers and SSSV (type and measured depth) Baker FHL packer at 8561'; Camco BaI-O SSSV at 2206' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation January 22, 1997 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Contact Engineer Name/~bec Jim x?~ith, 564-5026 Prepared By Name/Number: 17. I hereby certify that the fjb.~go~g~is/rl~ ~d correct to the best of my knowledge Signed PaulPrince l~~~{~,,,J ~ Title Senior Drilling Engineer Terrie Hubble, 564-4628 Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test 4-'"" Location clearance Mechanical ~:~lglrlar-~gn~u ~,, Integr' Test Subsequent form required 10- /4' ~ David W. Johnst0~ Approved by order of the Commission Approved Copy Commissioner Form 10-403 Rev. 06/15/88 Returned ._ IApproval No. c 1.61 Datq/'/'~,- ?7 Submit In Triplicate DS 12-23 WAG injector Workover The DS 12-23 WAG injector RWO is currently scheduled for Doyon 14 for January 22, 1997. This well is currently shut-in due to tubing leaks and communication between the tubing and the annulus. The workover will restore tubing and annulus integrity so the well can be returned to produced water injection. Proposed Rig Work 1. MIRU Doyon 14. m Pull 5-1/2" tubing from chemical cut at_+8,507' MD (leaving short tubing stub, PBR, production packer and tailpipe in the well). 3. Test the 9-5/8" casing to 3000 psi for 30 minutes. 1 RIH with custom tubing overshot, new 5-1/2" 17# L-80 completion and new 9-5/8" by 5-1/2" packer. Overshot the tubing stub, verify drift through tubing, freeze protect well and set packer. 5. Test the tubing to 4,000 psi (this is an injector). 8. Set BPV and release the rig. Jim Smith 1/16/97 ,. Annular Communication HISTORICAL REPORT 6/2196 FROM: 5/26/96 TO: 06/02/96 WELL: 12-23 WELL TYPE: WAG PROBLEM: Tbg x IA Communication to MI. DATE 5/30/96 5/31/96 DESCRIPTION OF WORK T/I/O--3300/2600/2400 AC Eval; TBG X IA X OA; IA FL @ 180', OA FL @ 50'. Bled IA from 2600 psi to 1100 psi in 2 hrs. IA increased from 1100 psi to 2300 psi in 30 mins. Bled OA from 2400 psi to 250 psi in 1 hr. Gas and then fluid, bled back 5 bbls of fluid. OA increased from 250 psi to 500 psi in 1 hr. TBG X IA PKO's: Test port @ 0 psi. IA X OA PKO's: Test port @ 0 psi. PKO's remained @ 0 psi during bleed. Post IA FL @ Near surface, OA FL @ 55'..DSM scheduled for Load and FP. Final WHP's = 3300/2300/900. T/I/O=600/1800/1500 DSM completed load overnight with 800 Bbls fo SW and 60 BBls of 50/50 pumped down Tbg. AC Eval; IA FL @ 420', OA FL @ 50'. Bled IA from 1800 psi to 1300 psi via well ~35. Bled OA from 1500 psi to 320 psi in 30 mins, got fluid to surface and shut down bleeding. IA increased from 1300 psi to 1520 psi in 20 mins. OA increased from 320 psi to 350 psi. TBG pressure dropped from 600 psi to 320 psi during IA bleed. Notified State Inspector of problem, and recieved verbal approval to place the well on Water injection until the MI is flushed away from the near wellbore region. Well was. placed on Water Injection at ~14:00 hrs. IA and OA had increased to 2500 psi by 19:30 hrs. Setup and began continuous bleeding, OA was bleed to 390 psi, IA was brought down to 680 psi but will track Tbg pressure very quickly when bleeding is shutdown. Will complete bleeding of OA to upright tank in the morning, and will schedule MIT/LLRT on IA with Meth/Water. Final WHP's=1275/680/425. WELL: 12-23 Annular Communication HISTORICAL REPORT 6/2/96 FROM: 5/26/96 TO: 06/02/96 WELL TYPE: WAG PROBLEM: Tbg x IA Communication to MI. DATE 6/1/96 DESCRIPTION OF WORK T/I/O=1300/680/425 DSM RU to IA and pumped 150 BBIs of 60/40 Meth water down IA. Stable LLR was achieved at 1.7 BPM at 1975 psi. -650 psi DP. OA was bled form 425 psi to 75 PSI. After pumping WHP's were monitored for next several hours. All pressure remained fairly stable. RU 3 pen recorder to check for any anomolus changes in pressure. Final WHP's = 1300 / 1280 / 85 psi. Well Work Log Date Description DS-Well 6/01/96 Load and Test IA 12-23 FTP/I'rP PSI IA PSI OA PSI SITP I Min ID SSSV nipple 1,350 psi 680 psi 425 psi I SSSV Informstlon Tubular or Casing Problems PB'rD CIE #1 CIE#2 CIE #3 CIE #4 CIE #5 Diessl (Recov.) Dieeal (non Recov) AFE # CC~ Class Activity P 13246 21 DS121 ER Time Log Entry 07:45 MIRU- DSM Pumpetc. 09:15 Start bleeding OA to Upright tank. OA at 425 psi. / IA bleeding SI to start RU . 09:55 Completed RU & PT/IA pressure is up to 1180 psi. OA is down to 250 10:00 T/I/O=135011450/250 Started pumping; down IA at 1 BPM. 10:15 Increased pump rate to 1.7 BPM T/I/O= 1400/1850/200 10:25 OA down to 150 psi / Bleeding SI / Pump rate still 1.7 BPM IA pressure is up to 1975 10:30 40 Bbls 60140 away - Pump rate at 1.75 BPM T/I/O=1400/1975/150 11:00 Resume bleedincj OA / 90 Bbls' 60/40 away all pressure are fairly stable T/I/O=1375/1975/160 11:35 SD pumping 150 Bbls 60/40 pumped away. / Just prior to SD pressure were T/I/O=1375/1950/75 12:05 RDMO / TII10=1275/1260180 12:30 SI bleeding on OA. T/I/O=1300/1275/70 13:00 Monitor Pressures T/1/O=1300/1275/75 13:30 Monitor Pressures T/I/O=1310/1285/80 14:00 Monitor Pressures T/I/O=1300/1285/80 14:30 Monitor Pressures T/I/O=1300/1280/85 · 17:00 Installed 3-Pen recorder to document pressure changes overnic~ht. Results Summary - Address each objective Iistsd In Job request - e. g. spllts~ GOC plck~ channels, etc. · Established 1.7 BPM leak rate down IA with -600 psi differential with Tbg. · IA was re-Freeze protected with 150 Bbls of 60/40 meth water. · , · Perforatln~l Interval (BHCS depths] & Gun Info. (Insert more lines as n, ecessary) Top (ft) Bottom SPF Grams/EHD/TTP Phasin9 Orient OIBIU Zone Ad/R®perf , P or IPROF: Well rede (attach W$30) SSI-IPS Pump In Logs (LDL, PNL, etc.) BOPD: F/ITP: MD: Tot. Gas: GOFb SS: BWPD: WC (%): Press: GL Gas: Choke o: Temp: , /~1~ /~ PageNo. of Signed ~-~' 1 1 i , i, ~,J.~on cram? .... ~~ ~ ....... .... ~o/~ ~ ........ ' '- I I ii n .._ . I Il l[ ..~ ~ ~'~ .. , ........ ~,~ ,, i i1 mi ii I i ~:.~ .... ~ ~ ,~o~,,, q.J_O~_ _l~ ff ~o ........ ~:~ ,*~ ~ Xtff .......... - ii iii i II _ . lEI ....... iii 7: ~q ~ ~ ~,~ ...... . ~:*~ ~ , C ~ ~-4' ~/~ ~ ~ ,,, II II I I Ill - _. I I I Ill [ [ II [ I] . .. ... I[ ill II I I I I I Ifil I . m I [ [11[ I __ ....... 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Well: 12-23 Spud Date: 5/6/84 Original RKBE: 71' ToD of Formation: 8997' Annular Fluid:Diesel/9.6 NaCl Reference Log: BHCS AR~u Alaska, Inc. - Prudhoe API #: 50-029-21105-00 Completion: 5/19/84 Hanger Type: FMC Gert III Max Hole Angle: 16° @ MD: Date:5/16/84 Tie In: 6200' Type:INJECTOR Status:New Hanger:24' Angle @ TS:l° Angle @ TD:i° Date: 00/00/00 ALL DEPTHS A~E RKB J-1 re, C-1 DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE Jewmlry (J) Depth De~:riDtiOn 1 2206 2 8537 3 8550 4 8561 5 8624 6 8635 7 8636 8633 9 9258' 5-1/2" Ca~oo BAL-O SSSV Nipple ID=4.562" 5-1/2" Baker PEA Assembly Czossover 5-1/2" x 4-1/2" 9-5/8" x 4-1/2" Baker FHL Padu~ 4-1/2" Canuo D3-5 Lar~ Nipple ]]3=3.813" 4-1/2" Baker S~ut Sub 4-1/2" TUbing Tail ELM Tubing Tail ([cg~ 02/15/89) NOTED. ID: 4'-1/2" Camco DB-5 Landing NipDle ID=3.813" FHL/TIW HBBP Dkrs have reduced test Dressure limits in some cases. Contact ACE (x5102) Drior to Dressure testing. and Tubing (C) J-2 J-3 2 J-4 3 J-5 Size Weight Grade 13-3/8" 729 L-80 9-5/8" 479 L-80 7" 299 L-80 5-1/2" 179 L-80 4-1/2" 12.6% N-80 ToD Bottom DescriDtion 0' 2477' Casing 0' 8895' Casi~ 8604' 9380' Liner O' 8550' ~bin~-~C 8550' 8636' Tubir/3-PC J-6,7 Perforati~n Data (ELM DEPTHS) (P) C-2 Interval zone PT SPF 8900- 8923 S~3 23 4 9000- 9040 4 40 4 9052- 9092 4 40 4 9106- 9164 4 58 8 Date Co~ents 06/04/89 APERF 11/30/84 IPESF 11/30/84 IPERF 11/10/92 RPERP FRAC 06/24,/89 8700' SS= 8879' [VD PBrD= 9334' P - 1 8800' SS= 8979' MID 'ID= 9380' Revision Date: 11/09/95 by ENH Peascn: Pulled T~P Previous Reason: 09/29/95 Well 12-23 J-9 C-3 0~-0~-96 ^"~ FOR ,-~r,,., p~,,~.~, , PRESSURES ~ ~ ~,o FLUID ,o ~/8 ~ BEF/AFT TYPE ~,... BEF/AFT. DATE TiME TYPE c 31~0 '~n~ . o~u6 800 ~ ~ ~ 700 2532 775 ~ ~ e~ 700 ~ ~ee ~ 150 3008 740 ~ ~ ~ 680 ~ ~ ~ 145 3008 750 ~ ~ ~ .... 0 ~ ~ ~ 150 3257 ~25 ~ ~ ~ 6sn · ~ ~ . . ~ .. 3251 460 ~ ~ ~ 380 ~ ~ ~ 116 !!73 675 ~ ~ ~ 600 ~ ~ ~ 135 ,,':~_~.o_~.:..,., :... ..,., 0000 wH..'"'r~ '"' · -'.,.~ .'-~ -, u,.,-..'..'-9o 0000 WAG '"~ := '"' 0000 WAG iO 05-I 1-96 !000 14AG 05-01-96 0000 WAG IS ,n..., ~.,, ,4, 1700 WAG 0~. ' '-q"' ..... ' ., ,,'Or WAG 04-15-96 ~50. WAG 04-04-96 0000 WAG IW TYPES P - FREE FLOWING PRODUCER PAL - GAS LIFTED PRODUCER PWI - PRODUCED WA~ER INdECTOR S~I - SEA WATER INJECTOR WAG - WATER A~u GAS INJECTOR (ON WATER OR GqS) RL: .- RESIDLEuAo ~ ~ INJECTOR (NGI/WGI/AGI) OB'.' - OBSERVATION WELL DIS - DISPOSAL WELL P - PRODUCING I - I~4~ I,~O i~ - l~uc~u,~,~ GAS ~W - '~'i~rT ~.~o WATER SI - SHUTI~ ~OUBLED STA~S W - WAIVERED T - TROUBLED P - PROBLEM S - SUSPECT N - NFTS WAIVERED "J A _-,,,..,m'~"r~r,... PAK ;~" """'-'~ D - DIESEL (..'.'iALLONS) .N - NITROGEN (MINUTES) C - CRUDE (GALLOh'S) G - GAS (MINUTES) W - WATER IGALLO~SI 50,000 45,000 40,000 35,000 '~ ao,ooo ~. 25,000 t20,000 15,000 10,000 5'000 ///./~'''' '~ Well 12-23 Injection History. / ..- "- · FWl 0 '$WI X MI - - -_...~.RIR WHIP 3,500 3,000 2,500 2,000 1,500 1,000 500 D5108194 08116~94 11124194 03104195 06112195 0 9/20/95 12/29/9 5 0410 7196 0 07116196 ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 July 31, 1996 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Recent Injection Weil failures. Dear Mr Wondzell: Attached are six documents, the last five are verbal notification reports which are made to document incidents on injection wells where we observed some form of pressure control failure. These reports are ARCO internal reports which identify the AOGCC contact and response. In all eases a failed MIT was the concluding data, and the problems were identified through other monitoring routines. The MITs were run to confirm the extent of the problem, and none of these tests were routine MIT's that identified the problem. All five wells are SI at this time, and a summary of what we have found on each well is listed in the first attachment. If you require additional information or clarification, please feel free to contact either Richard Ortiz or Dave Smith at (907) 659-5102. Very Truly Yours, David D. Smith · Annular Communication Engineer DDS/RAO Attachments CC: Marty Lemon Ron Bowden PRB-20 PRB-24 RECEIVED AUG 0 5 1996 Alaska 011 & ~s Cons. Commission RECEIVED 11-08: 12-23: AUO i 0 5 1996 Injection Well Problem Summary Alaska Oil & Sas Cons. Commission Anchorage Initial indication of a problem was identified on 6/2/96. Since then we have determined that the PBR has unstung from the packer, leaving the Tbg in communication with the IA. It appears that the packer has failed and has slipped down hole and is resting on the liner top. We are unable to secure the well with a TTP or IBP due to the separation in pipe. However the well is SI and freeze protected and WI-IFs remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$23,600.00 Current plans for the well: Keep the well SI until a RWO can be completed to effect the repair. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. Initial indication of a problem was identified on 5/30/96. Since then we have identified the problem as two holes in the tubing at -7,466' and 7,482'. We have been unable to confirm 9 5/8" casing integrity at this time due to a small (- 1.6 GPM) leak at the TrP. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$56,600.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 13-15: Initial indication of a problem was identified on 5/5/96. Since then we have identified the problem as two holes in the tubing at -4,516" and 4,520". We have confirmed 9 5/8" casing integrity with a Combo MIT completed to 3000 psi on 5/26/96. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$45,300.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 17-08: Initial indication of a problem was identified on 6/22/96. Since then we have identified the problem as parted tubing or separation from the Tbg han.ger at or near surface. We are unable to secure the well with a TTP or IBP due to the separation in pipe. However the well is SI and freeze protected and WI-IFs remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$3,300.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. 17-10: Initial indication of a problem was identified on 7/1/96. Since then we have determined that we have competent Tubing with an MITt to 3000 psi completed on 7/5/96. We have identified the problem as a hole in the 9 5/8" casing at -3,150'. The well is SI and freeze protected and WHP's remain low and are monitored daily. Current costs tracked for work completed to control and identify the problem are: -$15,100.00 Current plans for the well: Keep the well SI until a repair can be completed. A Sundry notice will be filed and witnessed testing will be performed prior to re-establishing injection. rv E ORANDUM TO: THRU: Blair Wondzell, P. !. Supervisor State of Alaska Alaska Oil and Gas Conservation Commissien DATE: June 1. 1996 FILE NO: GG9JFADD.DOC FROM: Lou Grimaldi,~;,,.,.. SUBJECT: Petroleum Inspector M.I. injector casing leak Arco well #DS 12-23 Prudhoe Bay Field PTD #84-58 Saturday, June 1,1996' I witnessed the preliminary casing diagnostic work on Arco's well DS12-23 in the Flow Station three area of the Prudhoe Bay Field. I had originally been contacted by Dave Smith (Arco annular engineer) and John Smart (Arco wells group supervisor) on the previous day that a M.I. injector had developed a casing integrity problem. They reported that~ evening of May 30, 1996 the production operator had discovered the pressure on the 9 5/8 inner annulus had risen to 2600 psi and the 13 3/8 outer (surface) had risen to 2400 psi. The well was immediately shut-in and a pump truck was called out to load the tubing with seawater. The following morning I was contacted by Dave and asked approval for putting this well on water injection. I felt this was the safest course of action in that sweeping the M.I. 'q~,"',~. away from the wellbore would reduce the surface pressures and eliminate the possibility of a hydrocarbon leak at surface. I came back to location on Saturday to witness the attempt to pressure test the 9 5/8 annulus. A pump truck with a load of 60/40 Methanol water was used and with 1300 psi equalized across the tubing and inner annulus,the pump truck maintained a sustained pump rate of 1 3/4 barrels per minute-.~During this time the outer annulus was bled from 425 psi to 70 psi and held steady. ~ ?~ -~ c~u,~¢~ ~d~-. v-~J~,~., .~-,-.~ '~.'~--~ .~:r.~,~-~..; .",,'~ :,'7,: .-- ~.~-~."*. T,.his is obviously a major leak in the tubing (possibly packer) and a slight leak in the 9 5/8 casing above the 13 3/8 shoe. Dave Smith has a good plan for identifying the problems and will be in contact with us when he has the results. SUMMARY: I witnessed the preliminary casing diagnostic work on Arco's well DS12-23 in the Flow Station three area of the Prudhoe Bay Field. attachments: Problem history and well schematic cc: Dave Smith (Arco annular engineer) NON-CONFIDENTIAL PLANNING PRUDHOE ID: JUL $1'96 IN~IOIV W~L ANNUIatR COMMUNI~ TIOIV ~ NOTIFICATION OF AOGO0 11:47 No.O0$ P.04 DAT]~: May 31 1996 11~: 12:15 P.M. David D. Smith/John O. Smart AOC~C CONTACT: Lou Grimaldi · ~N: lnJectlonWell 12-25 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 Well 12-23 is a WAG injection well that is exhibiting Tbg x 9-5/8" communication and a smaller level of 9 5/8" x ] 3 3/8" communication. The well has been loaded with Sca Water, the 9 5/8" has been bled to 1300 psi, and file 13 3/8" has been bled to 300 psi. .~-'TION 1%/~: The current plan is to place the well on water injection tttll~, to flush back the MI h'om the near wellbore region, bleed all MI gas from the annuli, and then to pursue MIT, LLRT and Leak DetecUon Logging to evaluate the well for repair options. A State witnessed MIT will be conducted upon completion of ally repair option which is selected, Wellhead pressures will continue to be recorded on a daily basis until the Tbg x 9-5/8" communication problem is resolved, Verbal approval to place the well back on water injection was granted, Concern was expressed to make sure we kept pressure off the OA, until testing could be completed. Sundry Notice Req'd a'{--~is time? YES "__' NO X I ~ ........ I ..... I'''~' I I I I Illl I However, a Sundry Notice will be required to repair the well and return It to injection service, Annular Communication En~hzcer Orlg: Annular Communication Engineer cc: Wells Superintendent, Wells Operations Supervisor Area F/cid Eng. FS 1 DS Supervisor FS Superintendent DS 12 Engineer ......... j~ iiiii i ii i IN--ION WEIL ANNULAR COMMUNICATION V'I~BAL NOTIFICATION OF AOC~C ~.R ~ ~ON ORDER #4 DATE: May 31 1996 TIME: 12:15 P.M. NOTIFIED BY: David D. Smith/John C. Smart AOC, CC CONTACT: Lou Grimaldi ~N: Injection Well 12-2:~ Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 DI~'I~ION: · Well 12-23 is a WAG injection well that is exhibiting Tbg x 9-5/8" communication and a smaller level of 9 5/8" x 13 3/8" communication. The well has been loaded with Sea Water, the 9 5/8" has been bled to 1300 psi, and the 13 3/8" has been bled to 300 psi. ACTION I'IAN: The current plan is to place the well on water injection only, to flush back the MI from the near wellbore region, bleed all MI gas from the annuli, and then to pursue MIT, LLRT and Leak Detection Logging to evaluate the well for repair options. A State witnessed MIT will be conducted upon completion of any repair option which is selected. Wellhead pressures will continue to be recorded on a daily basis until the Tbg x 9-5/8" communication problem is resolved. AOC, C~ ~N~E: Verbal approval to place the well back on water injection was granted. Concern was expressed to make sure we kept pressure off the OA, until testing could be completed. Sundry Notice Req'd at this time? YES __ NO X However, a Sundry Notice will be required to repair the well and return it to injection service. ,, Annular Communication Engineer Orig: Annular Communication Engineer cc: Wells Superintendent, Wells Operations Supervisor Area Field Eng. FSI DS Supervisor FS Superintendent DS 12 Engineer ARCO .Alaska, Inc. Date: Subject: From/Location: Telephone: TolLo cation: July 6, 1994 P.O. Box 100360, Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution oil & oas cons. Number (M-D-Y) S,~ - ~O ~ 1-05STl 6-21-94 Prod Prof ! 1,1"&5" SCH -Lo~ ~ 1-17 j 6-20-94 / ProdProf j 1, 5" SCH "'~ i 2-20 ~ 6-18-94 /~BP Setting] Rec ~ 1, 5" SCH j -- ~.. ~ 2-28 6-28-94 / Leak Detection ! 1, 2" & 5" SCH _2q i 3-2 6-22-94 /'Leak Detection ! 1,1"&5" SCH '~* I 4-2 r 6-17-94 / Patch Set Rec ~ 1, 5" SCH " i~f i 4-308T i 6-25-94 '/ Perf Rec ~ 1, 5" SCH -Lrsq i 4-40 I 6-25-94 J Perf Rec · I 1,5" SCH --~ i 4-43 6-23-94 .~ Comp Rec 1, 5" SOH -~. ~ O i 4-44 6-20-94 ,'="'./ Perf Re(: 1, 5" SOH --~:~ I 4-45 6-25-94 '/" PerfRec ~ 1,5" SCH -'i '/' 5-03A f 6-9-94 " CDN J 1,2"&5" SCH \ ~ 5-03A I 6-9-94 "SlimlGR l 1,2"&5" SCH . 5-03AI 6-9-94 ~ CDR i 1, 2"&5" SCH. - ~ 5-33 l 6-29-94 -' Perf Record I 1, 5" SCH - 6-12A 6-24-94 ,-- PerfRec 1,5" SCH 7-6 6-28-94 ~ Perf Rec 1,5" SCH ~ I 7-26 6-19-94 .,. Perf Rec i 1,5" SCH i ~l~, ./~ 9-05A 6-21-94 ~' Perf Rec I 1, 5" SCH I.~-{' 9-30ST 6-29-94 '". Due! Burst " 1, 5" SCH -i Itel i 11-6 f 6-2~-94 .-"prod pmf 1, 1"&5" SCH - -i 5'Z. ~ 11-29i f 6-27-94 ..-' Perf Rec 1, 5" SCH [~,.~ 12-7A 6-27-94 t~'Leak Detection 1, 5" SCH 12-23 6-28-94 ~ Inj Pmf 1, 5" SCH ~' 1 12'28 i 6'27-94 'ProdProf 1,5" SCH ~ ~1~ 13-08 6-30-94 -~' Perf Prof ~ 1, 5" SCH . 14-24 6-15.94 /- CNL ! 1, 5" SCH [~o~ 14-39 6-19-94 /[.eak Detection 1, 1" &5" SCH 14-39 ~ 6-19-94 / Leak Detection I 2" , ~ SCH ~,2- i 16-28 t 6-20-94 "Perf Rec 1, 5" SCH 7-0-- c~O-~ 9-0-- o DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO Alasl~ Int.. Is a 8lJl)~ldlaW of AtlantlcRIcltflel~ ARCO ,~l~, Inc. P.O.2ox 100360 Anchorage. Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS - 8-93 5-13 ?7-p~ 5-28-93 5-24 ~]/-/~ 5-22-93 5-32 ~ I-~ 5-27-93 6-12A i~'~ 5-29-93 6-14A i ~?.5-19-93 7-147~-.-81 5-25-93 9-3 ?~.. :~..- 5-18-93 9-3 5-24-93 9-4A 9~-~.¥ 5-26-93 9-5A ?~'~ ~ 5-30-93 9-28A ~$-~') 5-28-93 9-31A ~-~$5-19-93 9-32 ~--/~5-30-93 12-15 ~ o~ ~- 5-27-93 12-23 z ~t- ~'~ 5-27-93 14-22A~.~5-23-93 14-22A 5-23-93 ~ ~ 18-29A ~5-18-93 AGI- 1~..~ ~ 5-20-93 AGI-1 5-20-93 Completion Record R,m 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Collar R,m 1, 5" Atlas TDTP (Borax) Rn_n 1, 5"Sch TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Prod Profile Rnn 1, 5" Sch Peri Record Rnn 1, 5" Sch Prod Profile R,,n 1, 5"Sch Production Log Run 1, 5" Sch Completion Record Run 1, 5" Sch Production Log R,m 1, 5" Sch CBT R~m 1, 5" Sch Completion Record R,m 1, 5" Sch Completion Record Run 1, 5" Sch Leak Detection Run .1, 2"Sch Peri Record Run 1, 5" Sch PITS' R~_m 1, 5"Sch Peri Record R,m 1, 5" Sch Jewelry R~m 1, 5" Sch Peri Record Run 1, 5" . Sch AGI-2 q~.~¢vS-23-93 Jewelry Rn_n 1, 5" Sch AGI-2 ~-23-93 Peri Record Run 1, 5" Sch AGI-3a~,~ 5-20-93. GR/C~ Run 1, 5" Sch AGI-3 ~ , ~5-21-93 Primary Peri Record l~nn. 1, 5" Sch AGI-4 ~'Xa 5-22-93 Initial Peri Record Run 1, 5" Sch $onya Wallace APPROVED ~_?J~ ATO.].52e Trims# 9307~.-~"~~~/~/0~ The correct well name for this log is 9-4A. The correct APl# for 9-28A is 50-029-21292-01. ARCO Ahska, Inc. P.O.Box 100360 Ancho~e, Alaska 99510 DATE: 12-18-92 REFF3LF~CE: ARCO CASED HOLE FINALS * ( 11-13& 11-1~93 ~//o * ~ IIoI3A 11-18-99 - ~11-13A 11-33-92 ~14-43 11-11~ ~-/oo C17-~ 11-1~ ~-/// 17-~ 11~ Dun] Burst TDT-P (Bor~ Dutl Burst TDT-P (Bcru) UBIT (Corrodon) ~ UBZF (~ment)~ UBIT (Cement & CotrcdonF Color Bun 1, fl' CBT/ Color Run 1, ~' (:ET / Color P-~ 1, fi' USIT (Cement & CorrmioM ~Color mm 1~ ~' Please sign and return 'the o;ttached copy u"receipt of data. RECEIVED BY~_~_~ Sonym Walhce DEC. ~) 0 1992 APPROVED~ &T0-1529 Alaska Oil & Gms Cons. Commission Tr~# 92265 AnchoraOe # CENTRAL FILES # ~ul;~ON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL #PHILLIPS PB WEIJ, Fll2m R&D #BIX # STATE OF ALASKA TEXACO * The correct API# for II-13A is 50-029-2122901. ,. STATE OF ALASKA ;- ~-~A~L-A~ ~.A,~N? ?A~S CONSERVATION ~: ~ISSION ~ ~'~ u uRY WELL OP RATIONS 1. Operations pedorm~: O~rati~ shutd~n Stimulate Plugging P~orate ~ ~'~ ~'~'~. ' "' 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 289' FSL, 700' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At effective depth 244' FSL, 165' FWL, Sec. 17, T10, R15E, UM At total depth 248' FSL, 169' FWL, Sec. 17, TON, R15E, UM 5. Type of Well Development Exploratory -- StralJgraphic Service X 6. Datum of elevation(DF or KB) 71' RKBE feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-23i 9. Permit number/approval number 84-58 10. APl number 50 - 029-21105 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9380 feet Plugs(measured) true vertical 9272 feet Effective depth: measured 9334 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 80' 20" 1925# Poleset 80' Surface 2406' 13-3/8" 2000 sx 'E'& 400 sx 'C' 2477' Production 8824' 9-5/8" 500 sx 'G' & 300 sx PF 'C' 8895' Liner 776' 7" 280 sx Cl 'G' 9380' True vertical depth 80' 2477' 878? 9272' Perforation depth: measured 8900-8923'; 9000-9040'; 9052-9092'; 9106-9144'; 9144-9164' true vertical 8792-8815'; 8892-8932'; 8944-8984'; 8998-9036'; 9036-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8550' MD; 4-1/2", 12.5#, N-80, PCT @ 8636' MD Packers and SSSV (type and measured depth)Baker FHL packer @ 8561' MD; ~r~~l-~~.,,,~i~ 2206' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attachment DEC 0 2 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons, Cola~lSS|0tl Anchoraoa Reoresentative Daily Averaoe Production or Injection Data - Oil-Bbl Gas-Mcr Water-Bbl Oasing Pressure Tubing Pressure Prior to well operation 0 0 12600 -- 590 Subsequent to operation 0 0 14700 -- 830 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing/i~rue and correct to the best of my knowledge. Signed ~ ~'~//='~'t~itle Senior Engineer cc: S. Wallace/DS Engr/J. W':'Peirce Date //~0/~"z...-- SUBMIT IN DUPLICATE Daffy Report of Operations DS12-23i 11/10/92 MIRU SWS. PT. RIH w/GUN # 1. Shoot 9144-9164' MD. POOH. LD GUN #1. All shots fired. PT. RIH w/GUN #2. Shoot 9124-9144' MD. POOH. LD GUN #2. All shots fired. PT. RIH w/GUN #3. Shoot 9106-9124' MD. POOH. LD GUN #3. All shots fired. Release well. Resume SWI injection. STATE OF ALASKA "ALASK, '_ AND GAS CONSERVATION C( VIISSION ,,3 APPLICA ION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Slimulate Change approv~ program Pull tubing "'-' Variance Pe"~'~te X 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 289' FSL, 700' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At effective depth 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At total depth 248' FSL, 169' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service X RECEIVED OCT 1 5 1992 Alaska 0il & 6as Cons, Commiss~Ot~ ^nchomgs Other 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12 - 23 9. Permit number 84 - 58 10. APl number 50 - 029 - 21105 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9380 feet Plugs(measured) 9272 feet Effective depth: measured 9334 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor " 80' 20" 1925# Poleset 80' Intermediate 2406' 13-3/8" 2000 sx °E' & 400 sx 'C' 2477' Production 8824' 9-5/8" 500 sx 'G' & 300 sx PF 'C' 8895' Liner 776' 7" 280 sx Cl 'G' 9380' True vertical depth 80' 2477' 8787' 9272' Perforation depth: measured 8900-8923'; 9000-9040'; 9052-9092'; 9106-9144'; 9144-9164' true vertical 8792-8815'; 8892-8932'; 8944-8984'; 8998-9036'; 9036-9056' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 8550' Packers and SSSV (type and measured depth) Baker FHL 8561' Camco BaI-O SSSV @ 2206' 13. Attachments Description summary of proposal .. x. 14. Estimated date for commencing operation November 1992 16. If proposal was verbally approved Detailed operations program __ BOP sketch 15. Status of well classification as: Oil ..._ Gas _._ Suspended .__ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WAG Injector I Signed .,,,~'"~,,~~~,'"'~~'~,.. Title Senior Operations Engineer I 4 - [ c FOR I~OMMIfifilON URI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY RUSSELL A. DOUGLASS Date Commissioner Date /O -~lr/'" ~,., Form 10-403 Rev 06/15/88 SW/JWP/DS Engr. SUBMIT IN TRIPLICATE ~;:::~ Arco Alaska, Inc. proposes to add perforations in DS12-23 for a selected interval within the Sadlerochit Sand from Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operations. Proposed Perforation Interval: 9106-9164' MD (58') @ 4SPF Ref: BHCS 3/16/84 RECEIVED OCT 1 5 1992 Alaska 0ii & Gas Cons. commissio~ Anchorage 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4. 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF II '1 H ! REL ! NE BOP EQU ! PHENT 510080,006 REV·] ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-3 1-92 REFERENCE: ARCO CASED HOLE FINALS ~2~2~ 13-23A 2-11 7~-d3 7-14-92 Prod Profile Run 1, 5" 2-23ST~2~/~o 7-14-92 Prod Profile (Flexstak) Run 1, 5" 2-35 7-13-92 Leak Detect Run 1, ~' 3-7 ~-~'3 7-6-92 Inj Profile Run 1, 5" 3-10 ~--~/ 7-7-92 It~j Profile Run 1, 5" 3-14 ?f--~.~- 7-10-92 Prod Profile Run 1, 5" 4-25 ~d-~ 7-5-92 Static Temp Run 1, 5" 4-42 7-5-92 Inj Proflle/Temp Run 1, 5" 5-3 g~/-.~'0~. 7-6-92 Prod Profile Run 1, 5" 9-2 ~'~/.~o 7-4-92 Prod Profile (Flexstak) Run 1, 5" 9-27 ~'o'.~# 7-10-92 Leak Detect Run 1, 5" 9-29~5'--/F~' 7-7-92 Prod Profile Run 1, 5" 9-36oo5'-,~o? 7-5-92 Prod Profile Run 1, 5" 12-2 F~-2~._ 7-14-92 Inj Profile Run 1, 5" 12-23 ~ ~'-~ 7-14-92 Inj Profile Run 1, 5" 7-4-92 Inj Profile Run 1, 5" 7-7-92 Inj Profile Run 1, 5" 7-11-92 Gas Entry Run 1, 5" 7-11-92 Prod Profile (Flexstak) Run 1, 5" Please sign and return the attached copy as receipt' of data. RECEIVED BY.___~__~ Have A Nice Day! Sonya wallace ATO-1529 APPROVED Trans# 92167 CKIlICO Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES' R&D 9. BPX # STATE OF ALASKA TEXACO RECEIVED The correct well name is 2-23ST. AUG 1 0 1992 Alaska 0il & (~as Cons. Commission Anchorage ALA~'KA, INC. ~ ARCO F':'~ O, BOX t(~(.)S66~ ' ANbl..IO,.,'AL,[.~., ALASKA 995t ("~ D A T E .' 5 - 6 - 9 t I',, I:: F i::. I ', E: N C, IE' ARCO CAS'E"D HOLli.". I-.[NAI...$; t -" .3 (~ ~"~..-" 4'"'9t 'rEMF" E:.RA"" "1" LI F,,E"" 2 -. t 6 4 - i 3 ..-. 9 t L.. E {-':, K D Ii.:. 'f' E C T I C) N ;3 .... t 7 4- t 3-. 9 i I... E: A I< D E'i" E C: T I C) N 1, 4 .... 'i~) 4'-"6-' 9t ! N,J Ii.". C T I 0 N · ' ~,-,~ "'D"" 2 ¢ 4 "; ''~ "" C -',..'. ~... -' 7 'l B i" 6 '" t.., '''~' 4 -' 8 "" 9 t P R 0 f) U C T '1:0 6'"'2¢ 4""6'-9I F:" I:;,' C) I) LJ C; ]" .'!: 0 N 9 '--' 4 4 - t :.'¢ '"' 9 'i !... Iii; A I< D E T Ii" C T ]; 0 N '."..~ .... o4 "" '5 - 9 'i I... E A K D Iii: 'f' I.'!: C T' I 0 N I0 - ~0'"1 ~'..-.'i1.;'¢4""2t .... 9t COLL. AI'?/F:'FI-~F" 0~ ~., O ~ 9 "'- 4 8 4 "" 4 '"' 9 'l C; A t't f'! A / C C i.../J Iii; W Iii: !... R Y t f .... f 4 "-' 2- ? 'l l...,r.'.:. A K D E T Ii" C T I 0 N t t .... 3 4'"' 2-- 9 i L. !ii: A K D Iii; T E C '1 I 0 N f t .... 4 4 .... 3-9f t"']:T,":;/:I:NJECTION t 2'-23 4""6-9t 'i 2'"'215 4--'i 4-9'i INJECT IC)N e¢.. t 4 --- 2 3 S - 3 -' 9 t P R 0 D U C l' _1:0 N f 4 .... 35 4-'3-9t COLI_AF;: t '? .... t 4 "-' 3 - 9 'l F:' R 0 D U C 'f' ]: 0 N ,, ..... ,,... PWDt, It .-~...A4/c~-7/9t TEHF'/,., I'-I NNEF,,' RUN '{ ,., RtJN t , t ' RUN 'i ,..; RUN 'i, 5:" " ~ 5 ' I..,UN'i , F;,'t..IN t , .5' RI..JN't, 5' F;,'L~N t, F;,'LINt, 5:" F(U N 't, 5" RLIN t , 5" R t..I N 'i , Rt..INf ~ .~¢" RUN 'i ~5" F;~t..IN t , .., RUN 'i, 5' RUN t, 5" F:'L. EA,S'E: /.';'IC;-N AND I:;,'E:'T'LIF;,'N THE kECk..[¥[="D BY .. . HAVE A NICE DAY! /.'.':HAF:.:ON W I I...,~:C)N ATO .... 1 529 ATTACHED COPY AS' RECEIF:'T' OF:' DATA, A I::' P R 0 V E 'FI'?ANS':~: D 15; T' R ]: B U T ]: 0 N ,Il. · ,. C !....-. N T R A t.. F.' I L. E S' .". · ,,-F' !..! I L L I P S' · ,-CHEVRON F:'B WELL FILES' D & M R & D .n. "" ' "'% ' ' F:' · ,,. E:.XIE:.~.~3 }.ON EXF'I...OF;~AT]:CIN '"' · .. B X .fl. · .. EEXXON ~ ,~"'T'A'fE OF AL.A.?I<A HARATHON TE:XACO .11. -,. MOBIl_ CAMCO CAMCO CAMCO C A M (3 (3 ,¢~' C:l..i CAMCO CAMCO C A M C C) C A N C 0 ATL. A;E' C A M C 0 CAMCO C A M C C.,' CAME;(:} C A f'l C 0 CAMCO C A ~'i C 0 CAMI. L.) CAMCO CAMCO · )~ 'f' I"1 ]: ~' I ~' A D U P [. I C; A l' E O F" T H E I.. O G Y O U Al.. R lii:A D Y RE C E I V EL D, E. X [,' E F'T T I-'1[-" A F:' I -'I: COI',,I-,I-C'IE.'O I-L[':.A,~JE THROW TI-4E: F'F;tEVIOU$ COPY W.'I'TI-~ 'f'HE WI:~:ONG ~P:I:"'- ~I4~Y ARCO ALASKA, INC, F',O, BOX ~80368 ANCFIORAGE, ALASKA 995~8 DATE' 3-9-9e REFERENCE' ARCO F'RE£$'URE DATA 3-4 4-6-90 BHP--$TATIC GRADIENT CAMCO 3-t8 4-6-90 BHP--£TATIC GRADIENT CAMCO 9-.45 4-45-98 BHP--$TATIC GRADIENT CAMCO 9-J9 4-45-9~ BHP--$TATIC GRADIENT CAMCO 44-1 4-5-9~ BHP--$TATIC HAS 44 '-.t 6 4 -5-90 BHP--$TAI'IC HR$ 4 2.-23 4 -?-9~ BHF'--$TATIC HAS ~2-29 t-43-90 BHP--$TATIC GRADIENT CAMCO i3-32 i-?-go BHP--£TATIC i4-2t i-3-90 BHP--FL[)WING GRADIENT CAMCO 44-36 4-3-90 BHP--FLOWING GRADIENT CAMCO 46-~4 4-43-90 BHP--$TATIC GRADIENT CAMCO 48-3 44-29-89 BHP--$TATIC GRADIENT CAMCO i8-9 ti.-29-89 BHF'--£TATIC GRADIENT CAMCO t8-i6 ii-27-89 BHP--£TATIC GRADIENT CAMCO 48-20 44.-'2?-8? BHF'-~$TATIC GRADIENT CAMCO PLEASE SIGN RECEIVED BY AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ R£-Cd¥ O MAR 141990 AF, F, ROVED/~ __,.~_ Alaska 0il & Gas Cons. Go, mmiS~gll TRANg~ 'Anchorage HAVE A NICE DAY! £ALLY HOFFECKER AT0-4529 DISTRIBUTION CENTRAL FILES .,..'. ~:'WIt. LIPS CHEVRON PB WELL FILES ~ D & M ~ · ,,..,,- R& D " EXTENEION EXPLORATION .,,,"' BF'X ~' EXXON ~ ~ ~. STATE OF ALASKA MARATHON '" · ,. TEXACO · ,.'"' MOBIL ,, ARCO ALASKA, INC P.O. BOX i ANCHORAGE, Al_ASEA 995i DATE' 8-29-89 REFERENCE' ARCO CASED HOLE FINALS t-J t 8-i 2-89 3-t0 8-7-89 4--3 8-J 9-89 5-J 8-t 2-89 7-8 8-t 0-89 7-33 '7-2r~-89 9-4 7-t9-89 9-t2 8-3-89 9-28 7-t9-89 t i-5 7-2J-89 J J-J 7 8-J J-89 J2-2J 8-7-89 J4-~2 8-J 6-89 J6-J8 8-2~-89 J -/-9 8-9-89 J 8-28 8-J J-89 PRODUCTION F'ROFILE INJECTION PROFILE TUBING [;UTTER PITS F'RODUCTION PROFILE PERF RECORD PERF RECORD INJECTION PROFILE PERF RECORD F'ERF RECORD LEAK DETECTION INJECTION F'ROFILE COLLAR/PERF TEHP/C AF'/QR/I'P INNER F'RODUCTION PROFILE FLUID ID/PITS/LEAK DETECTION RUN RUN 1, 5" RUN J, 5" RUN 1, 5" RUN t, 5" RUN t, 5" RUN t, 5' RUN 4, 5" RUN t, 5" RUN 1, 5" RUN RUN RUN i, 5" RUN£ i&2, 5' RUN i, 5" RUN 1, 5" PLEA£E SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. CAMCO CAMCO A'['LA~' CAMCO CAMCO I-~L~' HL$ CAMCO HL~' HL$ CAMCO CAMCO ATLAS CAHCO CAMCO HAVE A NICE DAY! $ALLY HOFFECI<ER , ,:~... APPROVED ATO-i 529 { ~E~.~:~,~.~!~&~asCOllS. CO~ll~12~;~:~,~ TRAN$~ 89364 Anchorage DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON F'~-~ WELL FILES D & M R & D EXTENSION EXPLORATION ~ BF'X EXXON -' .. STATE OF ALASKA MARATHON J TEXACO MOBIL THE CORRECT AF'I~-' FOR 9-4 I$ '50-029-282t2, THE CORRECT AF'I-t- FOR t t.-.5 I$ 50-029-20670. ARCO ALASKA, INC. f'".O· BOX i 0¢,36G ANCHORAGE, ALASKA DATE: 8-2-89 REFERENCE' ARCO CASED HOLE FINALS i-4 5-26-89 F'ERF RECORD RUN i i-i? 7-3-89 PERF RECORD RUN i 2-4 6-24-89 PERF' RECORD RUN i 2-i& 7-3-89 F'ERF- RECORD RUN i 3-9 5-i G-89 COLLAR/F'ERF RUN i 4-5 6-ti-89 PERF RECORD RUN t 4-t9 5-3i-89 F'ERF' RECORD RUN i 7-i6 5-i-89 COLLAR/PERF RUN t ii-t;~ 5-24-89 F'ERF RECORD RUN i fi-t6 5-;24-89 PERF RECORD RUN ~ t i.-28 7-24-89 CBT RUN t t i-28 7-24-89 CET RUN t i t-28 '/-24-89 GR RUN t t2-23 6-4-89 PERF RECORD RUN t i2-25 6-i5-89 F'ERF RECORD RUN t i 2-30 6-i-87 F'ERF' RECORD RUNS t 2-~t .... 6,-2=89 - - PERF RECORD - .. RUNS.. t 2-3J 6-3-89 PERF RECORD RUNS t4-2 7-~-89 PERF RECORD RUN t t 4-27 6-29-89 PERF RECORD RUNS i 7-9 6-i 6-89 F'ERF RECORD :RUN I.-IL.S I.-ILS HLS I..IL.S FILS I..ILS FILS HLS FILS I-tLS SCH SCH SCH HLS HLS 5" HLS 5". HLS 5~'' HLS HLS 5" HLS ~ ;-'~5~- ....... ":':'" ..... '~'H£S PLEASE SIGN AND..RETUR~ THE ATTACHED COPY.AS RECEIPT OF' DATA. HAVE A NICE DAY! SALLY HOFFECI<ER' ....... ~.,,,,:..,,.,..,,~ ,-, .... ,,.,,,,,, r'-,,......,.-=l,,.--..!arJ R'OVE . _ ATO- t. 529 · :. ~,,.:.-,~:.;~.,~ ..,:....~. ..... .~..:;..~.~. ,-,-' ..... . , · .. ....... ~--..4..," ~ , DI$~RIBU'FION .~,.. ,m ,.. , /,4 - .' '"~ .' ..~ ~,:~"'.~,,::",~:.":, .,.., ','. · ... -'-;' CEi~TR' '" · .-. AL: · O' ''" '"'...CHEVR N'''';:;'';'.:~'''''' ..... · .-"" EXTENSION EXF'LORATION · · .. EXXON MARATHON · .. MOBIL PHILLIPS F'B WELL FILES BPX STATE OF ALA&'KA TEXACO ARCO Alaska, Inc.~' Prudhoe Ba~ _~,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-23, Approval No.9-351 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RAC/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 12-23) W1-3 RECE ¥ED & C~as Cons. Comm~ss~o~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C; STATE OF ALASKA ALASKa"" .AND GAS CONSERVATION C{ fiSSION REPORT SUNDRY WELL OP' RATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing ~ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 289' FSL, 700' FEL, Sec. 18, T1 ON, R15E, UM At top of productive interval 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At effective depth 244' FSL, 165' FWL, Sec. 17, T10, R15E, Um At total depth 248' FSL, 169' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development Exploratory StralJgraphic Service 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-23 9. Permit number/approval number 84-58/9-351 10. APl number 50 - 029-21105 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9380 feet Plugs(measured) true vertical 9272 feet Effective depth: measured 9334 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 1925~ Poleset Sudace 2406' 13-3/8" 2000 sx 'E'& 400 sx 'C' Production 8824' 9-5/8" 500 sx 'G' & 300 sx PF 'C' Liner 776' 7" 280 sx CI 'G' Measured depth True ve~icaldepth 80' 80' 2477' 2477' 8895' 8787' 9380' 9272' Perforation depth: measured 8900-8923'; 9000-9040'; 9052-9092'; 9106-9144'; 9144-9164' true vertical 8792-8815'; 8892-8932'; 8944-8984'; 8998-9036'; 9036-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8550' MD; 4-1/2", 12.5#, N-80, PCT @ 8636' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment 14. Packers and SSSV (type and measured depth) Baker FHL packer @ 8561' MD; Camco Bal-0 SSSV @ 2206' MD ~ ~"~ ~' ~," t '~ ~:,' i"", r~ 3UL 2 8 ' Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons. C0mmissio~ Reoresentative Daily Averse Produ~ion ~r Injection Date A~ul~u~agu OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 18077 -- 1329 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations --' 20225 -- 1165 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 ~~-~v~ ,~_ "~J"c,,,.~...v-~ Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 108 R. A. Clausen, 263-4538 SUBMIT IN DUPLICATE DS 12-23 Sag River Fracture Treatment Post Job Summary Sequence of Events: 8. 9. 10. 1. Perforate Sag River formation 8900'-8923' MD'(referenced to BHCS log dated 5/16/84) on 6/4/89.. 2. Pumped sand slurry on 6/21/89 fullbore down tubing to isolate Zone 4 perfs 9000'-9040', 9052'-9092', 9106'-9164' MD (referenced to BHCS log dated 5/16/84). 3. Rig up DowelI-Schlumberger for frac on 6/24/89. 4. Pressure tubing by casing annulus to 2000 psig. 5. Pump 100 bbl formation breakdown stage to the Sag River formation perfs 8900'- 8923' MD'(referenced to BHCS log dated 5/16/84) at 20 bpm and 2000 psig. 6. Pump 40 bbl pump-in/shut-in stage at 20 bpm and 1990 psig. 7. Pump propped fracture treatment at 20 bpm and pressures ranging from 1420 to 4100 psig. Pumped 242 bbl of pad, 188 bbl of slurry with proppant concentrations of I to 14 ppg, and 195 bbl of flush. RDMO Dowell. MIRU coil tubing unit and cleanout proppant and sand fill on 6/27/89. Place well on seawater injection into both the Sag River and Ivishak formations. ARCO Alaska, Inc.i' Prudhoe Ba~ _,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager 0 {IGINAL July 10, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-23 Approval No. 9-325 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(D$ 12-23) Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-G STATE OF ALASKA ,,. ALASK,{". AND GAS CONSERVATION C~' JlISSION REPORT oF SUNDRY WELL OP,- ATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging ~ Perforate Pull tubing ~ Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 289' FSL, 700' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At effective depth 244' FSL, 165' FNL, Sec. 17, T10N, R15E, UM At total depth 248' FSL, 169' FWL, Sec. 17, T10N, R15E, UM Repair well Other 5. Type of Well ~ D~velopment~ Explora~ry Stratigraphic ~._.~' 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-23 9. Permit number/approval number 84-58/9-325 10. APl number 50 - 029-21105 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9380 feet Plugs(measured) true vertical 9272 feet Effective depth: measured 9334 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 1925# Poleset Intermediate 2406' 13-3/8" 2000 sx 'E'& 400 sx 'C' Production 8824' 9-5/8" 500 sx 'G' & 300 sx PF 'C' Liner 776' 7" 280 sx CI 'G' Measured depth Trueverticaldepth 80' 80' 2477' 2477' 8895' 8787' 9380' 9272' Perforation depth: measured 9000-9040'; 9052-9092'; 9106-9144'; 9144-9164' true vertical 8892-8932'; 8944-8984'; 8998-9036'; 9036-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8550' MD; 4-1/2", 12.6#, N-80, PCT @ 8636' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached 14. Treatment description including volumes used and final pressure Packers and SSSV (type and measured depth) Baker FHL packer @ 8561' MD; Camco Bal-0 ,.S~,,S. SV~,(~..,2, 206' MD '?',.., .' ........ !i"': '!~ ':~ ~.'., ~' ~ ~ ...... i...i' i'~.., i',J."' ., ..-.,. ,. , .? {','~ , ~'.,..... ,,.". ;...,,.:.; ,..~ .~,! .',' ~.. :, :.', .. ·... ,',:, ~ ',., , .' i,, ..'~-~!'~ Reoresentative Daily Averaoe P--,mdael~or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 9000 -- 1000 psi Subsequent to operation 0 0 16000 -- 1000 15. Attachments Copies of Logs and Surveys run . 16.,.S, tatu~ef well classification as: Daily Report of Well Operations ~t, ~'" Gas Suspended 17. I hereby certify that the foregoing is true and correct to/t'he-"best of my knowledge. Form 10-404 Rev 06/15/88 Service Title Oper~ions EngineeHng Manager 069 J.C. Bmden, 263-4536 Date ~/~ SUBMIT IN DUPLICATE Drill Site 12-23i Half Strength Mud Acid Matrix Stimulation 5/23/89 ARCO Alaska, Inc., performed the following stimulation treatment: 1. Loaded the following fluids: a. 2000 gal of 12% HCl with 10% mutual solvent b. 10000 gal of 12% HCL/3% HF c. 8000 gal of 12% HCL d. 8000 gal of 2% NH4CI water e. 500 gal of xylene e. Batch mix 1500 gal 2% NH4Cl water, 60 lbs HEC polymer and 1500 lbs BAF f. 150 bbl of methanol for displacement and clean-up. 2. MIRU CTU with the 130 rib Baker inflatable packer. 3. RIH with CT and packer. Set the packer at 9045'MD. 4. MIRU transports and tanks. 5. Stimulated the lowest two perforated intervals (9052' - 9092'MD & 9106' - 9164'MD) by pumping the following fluids down the CT: a. 500 gal b. 5O bbl c. 2000 gal d. 1000 gal e. 3000 gal f. 5000 gal g. 1000 gal h. 4000 gal i. 500 gal j. 3000 gal k. 5000 gal I. 1000 gal m. 4000 gal n. 75 bbl xylene Methanol 12% HCI with 10% Mutual solvent and additives gelled 2% NH4CI with BAF 12% HCl with additives 12% HCl/3% HF with additives 12% HCI with additives 2% NH4Cl Water gelled 2% NH4Cl with BAF 12% HCl with additives 12% HCl/3% HF with additives 12% HCI with additives 2% NH4CI water Methanol for cleanup 6. Released the packer and POOH with the packer. Displaced the CT with methanol/water. 7. Rigged down and moved out. Reference Log: BHCS 5/16/84 ARCO Alaska, Inc. Prudhoe Bay l( ':.eering Post Office Bo=.. u0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 3, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-23 Permit N~).84-58 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp Attachment BP Exploration, Inc. J. Gruber, ATO-1478 PI(DS 12-23Wl-3 E£EtV. ED ARCO Alaska, In¢, Is a Subsidiary o! AtlanticRichfleldCompany AR3B--6132-C ~ ~AI I~ ~1- AL~bI~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLIC(," 'iON FOR SUNDRY APF(.']' )VALS 1. Type of Request: Abandon~ Suspend Operation shutdown Alter casing Repair well Plugging Change approved program __Pull tubing Re-enter suspended well Time extension Stimulate Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. , . Address P.O. Box 100360 Anchorage, AK 99510 Location of well at surface 289' FSL, 700' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At effective depth 244' FSL, 165' FNL, Sec. 17, T10N, R15E, UM At total depth 248' FSL, 169' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well: Development x Exploratory . Stratigraphic Service 6. Datum elevation (DF or KB) 71' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 12-23 9. Permit number 84 -58 10. APl number 50-029-21 1 05 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Intermediate 2406' Production 8824' Liner 776' Perforation depth: measured 9380 feet Plugs (measured) 9272 feet 9334 feet Junk (measured) 9226 feet Size Cemented Measured depth True vertical depth 2 0" 1925# Poleset 8 0' 80' 1 3-318" 2000 sx 'E' & 2477' 2477' 400 sx 'C' 9-5/8" 500 sx 'G' & 8895' 8787' 300 sx PF 'C' # 9000-9040'; true vertical 8892-8932'; Tubing (size, grade, and measured depth): Packers and SSSV (type and measured depth): 280 sx Cl 'G' 9380' 9272' 9052-9092'; 9106-9144'; 9144-9164' '""' ,~,", !~.~ ! ~ ;,.~ 8944-8984'; 8998-9036'; 9036-9056' ~{ t t.~ ~; ~.!,f'].~! .. 5-112", 17#,L-80, PCT @ 8550' MD; ....... 4-1/2", 12.6#, N-80, PCT @ 8636' MD .,'-"~.'~ ...... ............ '"..:~.~ :~,~ .& Baker FHL Packer @ 8561' MD; Camco Bal-0 SSSV @ 2206' MD 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch x 14. 16. Estimated date for comme~ing operation May 1989 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas~ Suspended~ Service 17. I hereby,.~ertify that t_he foregoing is true and correct to the best of my knowledge. · Signed ~/p/,ljY~_,,~t.~./- Title OperationsEncjr. Mcjr. FOR COMMISSION USE ONLY "~ONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form B{equired 10- /7/c-~' ORIGINAL. SIGNED Approved by order of the Commissioner 1,0NNI~ O, SM!TH Commissioner Form 10-403 Rev 06/15/88 003 J. C. Braden, 263-4536 Apb.roved Copy Returned · , IApproval ,O.~:~ _ ~-/ Date SUBMIT IN TRIPLICATE Drill Site 12-23 Proposed Hydraulic Fracture Treatment ARCO Alaska Inc. proposes the following 1. . . . . 6, . . 9, hydraulic fracture procedure. Perforate Sag River interval 8900'-8923' MD referenced to BHCS log dated 5/16/84. Isolate Ivishak perfs 9000'-9040', 9052'-9092', 9106'-9164' MD with a sand slurry pumped fullbore. Tag fill with wireline to insure top of sand depth. MIRU fracturing service company Pressure annulus to 2500 psig. Pump propped fracture treatment for Sag River zone from 8900' to 8923' using gelled water and 16/20 mesh Carbolite proppant. a. 100 bbl formation breakdown b. 40 bbl pump-in/ shut-in c. 250 bbl Pad d. 180 bbl Slurry at 2-14 PPG e. 238 bbl Flush RDMO fracturing service company. MIRU slickline unit and tag fill. Cleanout proppant and sand with CTU to 9300' MD. Return well to injection and run spinner log to determine Sag River injection. 6 4 2 COILED 1UBINO UNIT BOP EOU ] PHENT .5000 PSI 7" WELLHEAD CONNECTOR IrLANGE !.5000 PSI 4 1/16" PIPE RAMS L 5000 PSI 4 1/6" HYD~UL~ SLIPS t.5000 PSI 4 1/6" SHEAR RAMS L 5000 PSI 4 1/6" BLIND RAMS L 5000 PSI 4 1/16" STUFIrlNO BOX · II HIREL INE _ I I BOP EOU l PHE N'I* 1. 5000 PSI ?" WELLHEAD OONN£CIOR FLANO[ :2. 5000 PSI WIRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc.;'I,,''' Prudhoe Bay Er, gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 26, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-23 Permit No.84-58 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DF$/JCB/jp. Attachment cc: BP Exploration, Inc. J. Gruber, ATO-1478 , PI(DS 12-23Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA AL/( \ OILAND GAS CONSERVATION COMMI/"' ')N APPLICATION FOR SUNDRY APPFIOVALS 1. Type of Request: Abandon~ Suspend Alter casing Change approved program 2. Name of Operator 5. ARCO Alaska, Inc. 3. Address P,O. Box 100360 Anchorage, AK 4. Location of well at surface 99510 Operation shutdown Repair well Plugging Pull tubing Type of Well: Development x Exploratory Stratigraphic Service .. 289' FSL, 700' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 244' FSL, 165' FWL, Sec. 17, T10N, R15E, UM At effective depth 244' FSL, 165' FNL, Sec. 17, T10N, R15E, UM At total depth 248' FSL, 169' FWL, Sec. 17, T10N, R15E, UM Re-enter suspended well __Time extension Stimulate x Variance Perforate Other 6. Datum elevation (DF or KB) 71' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 12-23 9. Permit number 84-58 10. APl number 50-029-21 1 05 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Intermediate 2406' 9380 feet Plugs (measured) 9272 feet 9334 feet Junk (measured) 9226 feet Size 20" 13-3/8" Production 8824' 9 - 5 / 8" Liner 776' 7" Perforation depth: measured 900'0-9040'; Cemented Measured depth True vertical depth 1925# Poleset 8 0' 80' 2000 sx 'E' & 2477' 2477' 400 sx 'C' 500 sx 'G' & 8895' 8787' 300 sx PF 'C' 280 sx Cl 'G' 9380' 9272' 9052-9092'; 9106-9144'; 9144-9164' true vertical 8892-8932'; 8944-8984'; 8998-9036'; 9036-9056' Tubing (size, grade, and measured depth): Packers and SSSV (type and measured depth): Attachments: Description summary of proposal 5-1/2", 17#,L-80, PCT @ 8550' MD; .:.--.:~ C"'~i:),,, ,,:"~ ~3 '.~":::;i'!... 4-1/2", 12.6#, N-80, PCT @ 8636' MD Baker FHL Packer @ 8561' MD; ..,':~t~.";t,;~,,~.o:,,.~, ~,,,,n~ .~ Gas C011s, Camco Bal-0 SSSV @ 2206' MD ". ~ ~ch0rage x Detailed operations program BOP sketch x 14. 16. 17. Estimated date for commencing operation 15. Status of well classification as: May 1989 If proposal was verbally approved Oil x Gas~ Suspended~ Name of approver Date approved ~ Service I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Operations Engr. Mgr. Date FOR COMMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location Mechanical Integrity Test Subsequent. form Approved by order of the Commissioner ORIGINAL SIGNED BY . -,,,~,~ ~. .~MITH LUi~i i,i t I.,. v ..... Form 10-403 Rev 06/15/88 003 J. C. Braden, 263-4536 clearance required 10- /~/-/-.. IApproval No. D ate,,~--~/.--~' SUBMIT IN TRIPLICATE Drill Site 12-23i Half Strength Mud Acid Matrix Stimulation ARCO Alaska, Inc., proposes to perform the following stimulation treatment: 1. Clean the fill out of the well to a depth of 9275'MD. 2. Make a wireline tag with a 3.5" gauge ring, CCL and Gamma ray to ensure there are no obstructions, tag bottom and Icg the tubing tail. 3. Load the following fluids: a. 2000 gal of 12% HCl with 10% mutual solvent and additives b. 10000 gal of 12% HCL/3% HF with additives c. 8000 gal of 12% HCL with additives d. 8000 gal of 2% NH4CI water e. 500 gal of xylene e. Batch mix 1500 gal 2% NH4Cl water, 60 lbs HEC polymer and 1500 lbs BAF f. 150 bbl of methanol for displacement and clean-up. 4. MIRU CTU with the 130 rib Baker inflatable packer. ! RIH with CT and packer. Tie into the tubing tail using the tie-in Icg from Step 1. Set the packer at 9045'MD. The blank interval to set the packer is 9040' - 9052'MD, based on the BHCS (5/16/84). 6. MIRU transports and tanks. 7. Stimulate the lowest two perforated intervals (9052' - 9092'MD & 9106' - 9164'MD) by pumping the following fluids down the CT: a. 500 b. 50 c. 2000 d. 1000 e. 3000 f. 5000 g. 1000 h. 4000 i. 500 j. 3000 k. 5000 I. 1000 m. 4000 n. 75 gal xylene bbl Methanol gal 12% HCl with 10% Mutual solvent and additives gal gelled 2% NH4Cl with BAF gal 12% HCl with additives gal 12% HCl/3% HF with additives gal 12% HCl with additives gal 2% NH4Cl water gal gelled 2% NH4Cl with BAF gal 12% HCl with additives gal 12% HCl/3% HF with additives gal 12% HCl with additives gal 2% NH4Cl water bbl Methanol for cleanup 8. Release the packer and POOH with the packer. Displace the CT with methanol/water. 9. Rig down and move out. Reference Log: BHCS 5/16/84 H2S Concentration - not available Minimum ID is 3.813 inch Camco DB-5 Nipple @ 8624' MD 6 5 4 3 2 COILED TUB].NG UNIT BOP EGU ! PHENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSi 4 1/16" PIPE RA.US 3. 5000 PSI 4 1/6" HYORAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 2 HIREL]NE BOP EOUIPHENT I i i 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE :2.5000 PSI WIRELIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC, ANCHORAGE~ ALA£KA 995~-~ DATE: 3-29-89 REFERENCE: ARCO PRE£$URE DATA 4-2 2-t0-89 BHP--FLOWING GRADIENT CAMCO 4-i9 t-3t-89 BHP--£TATIC GRADIENT CAMCO 5-i7 2-i6-89 BHF'--$TATIC GRADIENT CAMCO &-8 2-5-89 BHP--STATIC GRADIENT CAMCO 9-3 t-t5-89 BHP--$TATIC GRADIENT 0'[I£ 9-t~ t-3t-89 BHP--$TATIC GRADIENT CAMCO 9-ii 3-5-89 BHP--FLOWING GRADIENT CAMCO tt-t t2-2!-88 BHP--$TATIC GRADIENT OTI£ ii-ii 3-t?-89 BHP--$TATIC GRADIENT OTIS ti-t6 3-t4-89 BHP--£TATIC GRADIENT OTIS i2-i5 2-it-89 BHP--$TATIC GRADIENT CAMCO t2-23 2-t5-89 BHP--$TATIC GRADIENT CAMCO t4-28 2-5-89 BHP--£TATIC GRADIENT CAMCO i6-6 3-it-89 BHP--PRE$$URE BUILD-UP OTIS t'8-t7 2-t3-89 BHP--FLOWING GRADIENT CAMCO PWDWt-t 3-3-89 BHP--£TATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COF'Y A~' RECEIF'T OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 TRAN$ ~89i ~j~ AF'F',ROVED _~___ Anchorage DI£TRIBUTION CENTRAL FILES CHEVRON D'&M EXTENSION EXPLORATION EXXON MARATHON MOBIL T PHILLIPS F'B WELL FILES · ,' R & D ' SAF'C ~ STATE OF ALASKA ~~ TEXACO ARCO ALASKA, T. NC,. P.,[1. BOX ~88368 ANCHORAGE ~ ALASKA 99..~t G DATE: REFERENCE' ARCO CA~ED HOLE FTNAI... -29 2-27 -88 3-4 2-2e-88 5-t 3-4-88 ~ t 8 2-6-88 t - t 3-2-88 ~ 2-t 9-88 2-27 D-~-8~ 4-26 2-28-88 PRD,PRFI..E/HPFM/WHIIT MT$C~GA~-IN,JECTION PRFI E HPFH/TEHP ~AL[.AR~PERFDRATION P:rT~/GR/TEMF' CO[..L. AR LOG INJ~PRFI...E/TEHP/FI...OWHETER IN,.I~pRFLF/HPFH/TEHP PRD~PRFI_E/FI...OWHETER/WHUT CO[..t..AR/PERFORATYON Pl..EASE RECEIVED HAVE A N PEGGY ~ENNETT ATO i'~ - ~,~.9 APPROVED D T. ,~TR.T. B! ITl rlN RUN RI IN RI JN RUN RI.IN RI IN RtJN RUN R!IN RUN OF I)ATA~ ~AM~A CmM£n ~FAR CAM£1A CAMCO .,,,~ CENTRAl... FII...E,.g' '"' CHEVRON ~ EXTEN,.~ T ON EXPLORATION -"-, EXXON HARATHON '" MOI~II · ~- ,. STATE OF ALASKA .,. ALASI A OIL AND GAS CONSERVATION MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-'1 SUSPENDED [] ABANDONED [] SERVICE [] Water/Gas Ia.~ect:f. on -~ 2. Name of Operator 7. Permit Number - ,¢ ARCO A[aska~ ];ac. 8z~-58 3. Address 8. APl Number P.0. ;Box 100360, Anchorase, Alaska 99510 50-029-21105 ,, 4. Location of well at surface 9. Unit or Lease Name 289'FSL, 700'FEL, Sec. 18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2~4'FSL~ 165'FWL~ Sec. 17, TiON~ R15E, UM 1,2-23 At Total Depth 11. Field and Pool 248'FSL~ 168.8'FWL~ Sec. 17, T10N~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' ]~[(S AD[, 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/06/8~ 05/17/8~ 05/28/8~I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)1'9. Directional Survey I 20. Depth where SSSV set 121.Thickness of Permafrost 9380'ND, 9272'TVD 933Z,'ND~ 9226'TVD YE~ NO [] . 2207 feet MD .. 1900' (Approx.) 22'. Type Electric or Other Logs Run DIL/BHCS/G~/SP, LDT/CNL/GR/Cal~ CBL~ Gyroscopic Survey 23. . ....... CA.S!NG,. LI.N.E.R.. AN.D CEMENT! .N..G RECORD'" .... , ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~. . H-z~O Surf, 80' . 30". 199_~ Pnl.~_~ 13-3/8" 72.0# L'80 Surf. 2~77' .... 17%" 2000 sx Perm "[" & AOO s~ P~_~m "C," 9-5/8" 47.0~ L-80 Surf. 8895' 12~" 500 sx Cl~s.~ "~" & 300 .~ PF ,'C,' 7" 29.0# L-80 860~' 9,380' . 8~" 280 Sx Class !'G'.' '24. Pe'rforations olden to Production (MD+TVO of T'op and Bottom and 25. " TUBING RECORD interval, size and number) sizE DEPTH SET {MD) PAC'K.ER SET {MD) 9000-90~0', 9052-9092' 9106-916~'MD 5~ R~, R~I ' 26. ' .... kClD, FRACTURE, ~;EMENT SQUEEZE, E~FC. '" , , , , 8892-8932', 89z~z,-898z~' ~ 8998-9057'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,N/A .. Ref: BHCS 5/16/8~ ...... 27. PRODUCTION TEST .. .... D~,te First p;oduction' " t' Me;hod of Oper;tion (Flowing, gas lift, etc.) 12/17/8~I Water/Gas. In~ectioii. .. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKE sIzE I GAS-OIL RAT'IO . 8/..~7/87 24 TEST PERIOD I~ . -- -.- 7R=;? . . ~Ct I ---- , Flow Tubing ' Casing Press'ure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)' Press. 137Z~ -- 24.HOUR RATE I1~ .... 7857 -- . , ,, , ,, , , ,, 28. CORE DATA ,~, ~'_ ~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit.. in duplicate ., 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadleroch:Lt 8997 t 8889~ NONE ' ' ' 0/I4 Contact 9212' 910/+' ' ' Top Zone 3' = 9220, 9112, .' Top Zone 2 9289, 9181, · .. , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . , ~ , Signed __ Title Oper. Engr, H~_r. Date 7 INSTRUCTIONS . General' This form is designed for ~ubmitting 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 produ'bed, 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, Hydtaulic Pump, Submersible, Water In- jectiOn, Ga~ Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407' ,. A~ STATE OF ALASKA AL . . OIL AND GAS CONSERVATION COl{' .,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other [] Water/Gas Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, Al( 99510 4. Location of well at surface 289'FSL, 700'FEL, Sec. 18, T10N, R15E, UN interval FWL, Sec. 17, TION, R15E, UM At top of productive 244' FSL, 165' At effective depth 244' FSL, 165' At total depth FNL, Sec. 17, TION, R15E, UM 248'FSL, 169'FWL, Sec. 17, TION, R15E. UM 11. Present well condition summary Total depth: measured 9380 feet true vertical 9272 feet Plugs (measured) 5. Datum elevation (DF or KB) 71' RKB 8. Unit or Property name Prudhoe Bay Unit 7. Well number DS 12-23 8. Approval number 7-411 9. APl number 5O-- 029-21105 10. Pool Prudhne Bay Oil Pnnl None Effective depth: measured 9334 feet true vertical 9226 feet Junk (measured) Fill - 9312 Casing Length Size Cemented Measured depth True Vertical depth Conductor I ntermed i ate Production Liner Perforation depth: 80' 20", 91.5# 1925# Poleset 2592' 13-3/8",72# 2000 sx "E", 400 sx "C" 8895' 9-5/8",47# 500 sx "G", 300 sx PF "C" 776' 7" , 29# 280 sx Class "G" measured Surf - 80' Surf - 2477' Surf - 8895' 8604'-9380' 9000'-9040' 9052'-9092' 9106'-9164' Surf - 80' Surf - 2477' Surf - 8787' 8496'-9272' 12. true vertical 8892' -8932 ', 8944 '-8984' , 8998 ' -9057' Tubing (size, grade and measured depth) 5~", 17#, L-80, Surface to 8636'MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 8561'MD. Camco Bal-O SSSV Fa ??(17'Mn Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVE1) SEP o 9 Alasla Oil & Gas Cons. Commission Anchorage 13. Prior to well operation Representative Daily Average Production or Injection Data 8/4/87 OiI-Bbl Gas-Mcf Water-Bbl .... 7756 Casing Pressure Subsequent to operation 8/17/87 -- 7857 Tubing Pressure 1399 1374 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~/~I Title Operations Engineerinq Manager Form 10-404 Rev. 12-1-85 STAT16/SN 12'23 M, R. 01son (265-6810) Date Submit in Duplicate DS 12-23 Daily Report of Well Operation Add Perfs 8/7/87 SI well. Pump A/L gas down well. PT equipment to 3000 psi§. OK. RIH w/20' Hyper Jet II perf gun, 4 SPF, 60°/120° phasing. Tag PBTD @ 9318'MD. Shoot 9144v to 9164'MD. SI well. POH - all shots fired. SEP o 9 i.~61 011 & 6ss Oot~s. CommissloT~ Anchorsge ARCO Alaska, Inc. F',C), Box t09S60 ' . Anchorage, A La.s'ka 9~:( ( DATE' August t8, ~987 REFERENCE' ARCO Cam'ed Hole Final ~ 2-..2S 8-..7-87 CCL/F'er f. Record Rur~ t2-.25 8-8-87 CCL/Perf, Record Run 2, t 2--27 8-'7-87 C;CL/F'er f. Record Run S--~0 8-~0-87 CCL/F'erf. Record Run 2, 5 3-22 8--t2-87 Spinner F'rofi Le Ru~') t, 5' ~ch .~c h $ch ~'ch Please sign and return the aftached copy as receip't of data, HAVE A NICF.' DAY! ~ ~ Rosanne Peek · .-o ,,.~',.~,~ r~'~ 8~ Cons. ATO-.-~ ~.9 " TRAN$ ~'87426 Ap p r ovecl .... ~ ....... DISTRIBUTION ~' F'hi LLips Central Fi Les Chevron PB WeLL Fi I. es D& M R&D Exfensio)') ExpLora'tion -~- .~. Exxon .,- ~'tate of ALaska Marathon ,.'~ Texaco Mob i L ARCO Alaska, In~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 23, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Re: DS 12-23 Permit Number: 84-58 DS 12-25 Permit Number: 83-166 DS 12-27 Permit Number: 84-23 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEH'sd Enclosures CC' Standard Alaska Production Co. File P1(DS12-23)W1-3 P1(DS12-25)W1-3 P1(DS12-27)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' STATE OF ALASKA ~ ALA{ .. ,.)IL AND GAS CONSERVATION CO ..... &ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~, Plugging Fl Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 71' RKB feet 3. Address 6. Unit or Property name Post 0ffice Box 100360, Anchorage, AK 99510 Prudhoe Bay Unil: 4. Locatortofw~.~mat~,urfa e_Z89_il:SE;..700~_FEL_j~CSec. 18, TION, R15E, UM At top of productive interval 244'FSL, 165'FWL, Sec. 17, TION, R15E, UM At effective depth 244'FSL, 165'FNL, Sec. 17, TION, R15E, UR At total depth 248'FSL, 169'FWL, Sec. 17, TION, R15E, UM 7. Well number DS 12-23 8. Permit ~m_~r 9. APl number 5o-- 029-21105 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9380 feet Plugs (measured) 9272 feet 9334 feet Junk (measured) 9226 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' Intermedi ate 2592' Producti on 8895' Liner 776' Perforation depth: measured 20", 91.5# 1925# Poleset 13-3/8",72# 2000 sx "E", 400 sx "C" 9-5/8",47# 500 sx "G", 300 sx PF "C" 7" , 29# 280 sx Class "G" 9000'-9040', 9052'-9092', 9106'-9144' Surf - 80' Surf - 80' Surf- 2477' Surf- 2477' Surf - 8895' Surf - 8787' 8604'-9380' 8496'-9272' true vertical 8892' -8932' 8944' -8984' 8998' 9036' T~j~i,gg, (~.i~ gr~d,.,ind..rneasured td~)P~tl~36 MD , L-~U, burtace ' Packers and SSSV' (type and measured ,,depth) Baker FHL Packer @ 8561 'MD, camco Bal-O SSSV @ 2207'MD' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July 20, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,-,pertify that_the foregoing is true and correct to'the best of my knowledge Signed /~(:~'~ /~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Rev 12-1YSt'-)'o ~" ....... (JEH) 265-6859 lappr°va' N°. . the commission Dat Submit in triplicate ARCO ALaska, Inc. P.O. Box i00:36G Anchorage, Alaska 995tG DATE: June 2:3 ,~986 REFERENCE: ARCO Cased Hole Final 6-9-86 Inject ion Profi [e 5-28.-86 Spinner Inj. profi[e 6-2-86 Spinner Inj. profi[e Run I 5' Run i 5" Run t 5" Camco Camco Ca fflc o Please si ~~ached copy as receipt -/ - · ~. .,,'. "i' '~C:.~,~,~,,~ HAVE A NICE DAY! Linda Hulce ATO-t 529 TRANE of data. DISTRIBUTION Central Files Chevron D&M Extension Exploration Exxon Marathon Hob i [ Phi llip$ F'B Well F'i Les R&D $ohio Slate of Alaska Texaco ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 DATE: MAY 20. 1985 REFERENCE: ARCO PRESSURE DATA i2-23 PFO 4-7-85 CAMCO ~iN AS RECEIPT OF DATA. RECEIVED BY PAM LAMBERT AT0 i429C .. TRANS 116 Alaska Oil & Gas Cons. Commission Anchorage Chevron D&M Expl. Services Ext. Exploration Exxon Mara Chon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: April 23, 1985 Reference: ARCO CH Finals 3-8/ Perf Log 1-9-85 Run 1 5" Sch 6-5 v~ Collar Log 1-12-85 1 5" Sch 6-11W' Collar/Perf 12-25-84 1 5" Sch 11-12/TDT 3-20-85 1 5" Sch :i~"~'~:~'2,3.1:'~' S~inner/Temp 4-8-85 1 5" Camco ':.', '~,'. -'~ ,,.~L, ," 12-25"Collar/Perf 12-7-84 1 5" 'Sch 12-26/Collar/Perf 12-2-84 1 5" Sch 12-29~/collar/Perf 12-10-84 1 5" Sch ; 14-35~Collar/Perf 3-33'85 1 5" GO /.~inner 4-4-85 1 5" GO gn as receipt of data. Received by Pam Lamber t ATO 1429C Trans 081 Chevron Mobil E & P D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon ffohio Marathon l~obil Texaco ARCO Alaska, Inc.,~' Prudhoe Ba~ .-,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 31, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-23 Permit No. 84-58 DS 12-27 Permit No. 84-23 Dear Mr. Chatterton: Attached are Well Completion reports for the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments cc: Sohio Alaska Petroleum Company File Pi(DS 12-23)W4-3 File PI(DS 12-27)W4-3 RECEIVED JAN 0 2 1 B5 Alaska 011 & I~as Cons. Commission Anchorage ARCO Alaska, Inc, Is a Subsidiary of AllanllcRIchfleldCompany STATE OF ALASKA , ALASKA~' _ AND GAS CONSERVATION C~,, ,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well WATER INJECTION OIL I--I GAS [] SUSPENDED [] ABANDONED [] SERVICEd 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-58 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21105 4. Location of well at surface 9. Unit or Lease Name 289' FSL, 700' FEL, Sec.18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 244' FSL, 165' FWL, Sec.17, TiON, R15E, UM 12-23 At Total Depth 11. Field and Pool 248' FSL, 168.8' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 05/06/84 05/17/84 05/28/84I N/A feet MSL 1 17. TotaIDepth(MD+TVD) 18. Plug Sack Depth (MD+'rVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness °f Permafrost 9380'MD,9272'TVD 9334'MD, 9226'TVD YES J~ NO [] 2207 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP~ LDT/CNL/GR./Cal~ CBL, Gyroscopic Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · 20" 91.5# Hi40 Surf 80' 30" 1925V* Po~.set . 13-3/8" 72.0# L-80 Surf 2477' 17-1/2" 2000 ~x perm "E" + 400 ~ Per~ "C" 9-5/8" 47.04~ L-80 Surf 889~' 12-1/4" 500 sx Class "G" + 300 ~x PF "C,' 7" 29.0# L-80 8604' 9380' 8-1/2" 280 sx Class "G" , , . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD, " '" interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) 5-1/~" RR3R' R~R1 ' 9000- 9040' MD 9052 - 9092' MD Perforated on 11-30-84 w/4 SPF 26. ACID, FRACTURE/CEMENT SQUEEZE' ETC. 9106 ~ '914~' .MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED TVD of Perfs: 8892 - 9036' N/A · 27. N/A' PRODUCTION TEST Date First Production '1 Method of Operation (Flowing, gas lift', etc.) [ I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF " WATER-BBL CHOKE SIZE GAs-OI L RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=k, OIL-BBL GAS-MCF WATER-BBL OIL.GRAVITY-APl {Corr) Press. 24-HOUR RATE ~ ., 28. CORE DATA 'Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED · JAN 0 2 19B5 Alaska 0il & 6as Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS' ' ' F~)RM~,TION T'ES~S NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time o! each phase. _ Top Sadlerochit 8997 ' 8889 NONE OWC 9212 ' 9104 ' Top Zone 3 9220' 9112' To]) Zone 2 9289' 9181' 31. LIST OF ATTACHMENTS "32.' I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~,~~~Y ~,~'~S~-. Title ReR:ional Ooer. RlrlR:. Date /~''-~/'~y 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 prodaction from. more than one interval (multiple completion), so state in item 16, and .in item 24 show the producing intervals for 0nly the interval reported in item 27. Submit a separate form for each additional interval to be separately prod'uced, showing the data pertinent to such interval. Item 21'.Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23'. A'tta'ched SUlSpiemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. ,, Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jeCtion, Gas I njection,.Shut, in,.Other-explain. . . Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. ~ Prudhoe Bay r..,,~lineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 31, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-23 Permit No. 84-58 DS 12-26 Permit No, 84-14 Dear Mr. Chatterton: Attached are Sundry Notices for above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb Attachments CC: Sohio Alaska Petroleum Company File PI(DS 12-23)W1-3 File PI(DS 12-27)W1-3 work completed on the ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany RECEIVED STATE OF ALASKA ALASK,~" . AND GAS CONSERVATION (~' /IlSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-58 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell (Surface) 289' FSL & 700' FEL, Sec 18, T10N, R15E, OM (Producing Interval) 244' FSL & 165' FWL, Sec 17, T10N, R15E, UM (Total Depth) 248' FNL & 168.8' FWL, Sec 17, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADL 28330 8. APl Number 50- 029-21105 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-23 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimula.te [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing Abandonment [] Other []. 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, in. cluding estimated date of starting any proposed Work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 11/30/84. RU perforating unit and pressure tested equipment. RIH w/gun 91, shot interval 9126 - 9144' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot interval 9106 - 9126' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun 93, shot interval 9072 - 9092' MD (4 SPF). Shut-in . well,' POOH, all shots fired. RIH w/gUn 94, shot interval 9052 - 9072' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun 95, shot interval 9020 - 9040' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun ~6, shot interval 9000 ~ 9020' MD (4 SPF), Shut-in well, .POOH, all shots fired. Secured well, RD. Ref: BHCS: 5' 16-84 RECEIVED J AN 0 2 1985 AlasKa Oil & Gas ConS. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _-? . ,- --,..--~,~d¢ Title Reqtona] np~w~n9s Engineer The space below for Commission use Conditions of Approval, if any; By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate DATE· December 2t t°84 REFERENCE- ARCO F're.~.¢,ure Dm*,a 9-6 i ¢,- I i -84 F:'BU 1-.'~-a, 1t-.~-o/~~, ~,, ~.~Tmt'ic Grad'Jeni' Camco i2-8B i'i-26-84 5Jt'at'l'c 6radient' Camco ~2-28 ti-26-84 , ,~a~'ic G. raclien-t Camco i~."~-.~i~ 1t--3~)-84 ~'~'~t'ic Gradient Cmmco i_c~-o~ 12-I-84 ~t'mt'ic ~.l-adien~ Ce. moo l -.c)-- ~ 3~. t~')-.t --84 ~.")-26. ~2-3-84 ~'at'ic Gradient' Cmmco t ~-.~7 ~--=-84 -. ~- ~- ,, , · ,~'t'a~'ic Gradient' Cmmco ~ ~.~,_-)o~., ~ 2-~ -84 ~"t'.a t' i ~ Grmd i en't Ca:m~o. ~3-3 . ~-~?-84 ~;;~at'ic Graclient' Ca, taco ~3-4 ~-~7-84 ,?~'mt'ic Grmdient' Camco ~3-6 ~-'~9-84 ~mi'ic Grmclien~ Cmmco ~,3-? ~-~7-84 .~'tal'ic Gradient' Cmmc:o ~ Z--~ 3 ~ ~-'~ 9-84 ~at' i c Grind ient' [:a~ mc o ~-.~4 ~-~9-84 ,~'4'~. '~ic~rmdieni' Cmmco ~ - ~, ~,-,. ~' t' a t' i c G'r a ci i e n t' C a ,m c o ~6-~ 9-~-84 F'DD ~urvey Cmmco t 6-6 o-~'~-84 '"" I '" , ~ I"BL ,~urvey GO J6-9 '3-J9-84 ~t'a'tic: Grmdien¢ O~ i:.' J 6-. J J 3--. J c:,_ o,~ ,' ~,-, S't'at'ic Graclien¢ E:.mmc:o J7-5 9-26-84 F'BU Z'urvey Ce~mco J 7-.~'., 'z-.'i o-84, ~ t' a t'~' i c G~,m cl ient' Cmmco F'[ea~'e ~ign and ret'urn ±he at'~ached copy Alaska Oil & Gas C~ns. Commiss!er, Anchorage I) I ~,.7 'f' R I B L.! T I C.t N Mob i L Hobi ! ~" & F:' Phi !. 1. i p~: F'ru. clhoe I-)ay WeLL R & D J.,' o h io ,S'1'a'~e of A l.m.s-I<m ARCO Alaska, Inc. P.O, Box i¢~¢:36¢~ Anchorage, A La~'i<m DATE' December 2t i°o'~ REFERENCE' ARCO Ca~'ed HoLe F inaL~ D S I -. f A "~ o....-~ ,,... c.,/, · , · ,..: ,....,..,- ,..:-, C C L/,.F:'e r 1"' F-:.: e c c. r d D.,.S, 3-4 fi-7-84 Diff 'f'emp Log D S .'"~-t t i t ';: ~.,*-. C ....~-' · . .,,.. -,.,-.. E,, F:'.:, / ..., p i n'~"~ e r D, $, 3.',-28p''' f t -f 8-84 C. NIMSICR D, S, 4.-S '-.'/'/.I i ---t .7-.84 CN/M$'/[;F;.: D, E.',,"5-4. ''-'~' t I --i 4-.84 CN/M,:':,'/GR ~'! · "",, · '1 I),. £,' , ¢--4 -"'"' 8-7,6,-84., ,.. ., CCL,, F. er f Record D,, 2' , 7-4" . ...,,'-'. _ ", o,.... , '-°4,., CET Log I).S. '?-TA~. t i-t6-.84 CN/MS/GR D S r-.'t~,~'" ii 15 84 CN, P~,~/Gt-,, D. S, 7"t 4~,'/ i f '"t 6-'84 CNIMS.'IGF< ~., -, ii '~6~ 84 F'erfor@t'ing F;,'ecord ,,, ~l, D.S. i'$--'~A-. ~"i(')-8-84, . CCL/Perf Rec:ord D.$. i4-i3-.-" ii--'"'~-84...~,.. ., Co/I. ar/Ferf Log I).$. t4-S67' 8-25-.84 CCL/F:'erf Record D. S' i .,'~'"'7 ' 9-t ~-84 CET .,. .,'=; -' 9-' i D S' 1_- r · ¢-.84 CBL/VD D,, $,~ t '7-6 ~ i t --.2--84 CF,?/,S'p i ri'net D ,, S ,, I 7-8 .,-'"" t f -4-84 CF:'£'/:.:,'p inner [e~a~e :¢ign and 're'l:urr~ 't'he at"tached copy a:.¢ rec:eip'(' Received By .................... - "~.-'-/~/ HAVE A HAF'F'Y I-.I[)I. IDAY SEASON! ~"-'"'; ;~; / ]!¢j~.4~ . Ke [ l.y McFal- Land Alaska Oil & O~ss 6m"m. -O0¢'lrnissi':an A ]" 0-- t 429 F:' Ancl~0rage. 0 f d a 't' a., I) I S'T' R I B LJ T I 0 N Chevron Moh i k I) & M ld,'.:.',l-.~i I. E & F:' E x p 1. o)" a 't' i o n $ e r v i c: e ~ F:' h i I. I. i p .s' Ex+en~?t:io"n ExF, I. orat'ion F:'ruclhoe Bay Wel. I. Exx(-',n R & ):) M a ,.." ;-'., 't h ,'.::, n .':'.:.' 'f a 't' e (::: ',~' A [ a z,- k 8 F:'i I.e.? ARCO Alaskai ~. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 28, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 12-21 Permit No. 84-48 DS 12-22 Permit No. 84-60 . DS 12-23 Permit No. 84-58 DS 12-25 Permit No. 83-166 DS 12-26 Permit No. 84-14 DS 12-27 Permit No. 84-23 DS 12-28 Permit No. 84-31 DS 12-29 Permit No. 84-32 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/imh Attachments cc: Sohio Petroleum File PI(DS 12-21)W1-3 File PI(DS 12-22)W1-3 File PI (DS 12-25)Wl-3 File Pl (DS 12-26)W1-3 ~OV File PI(DS 12-27)W1-3 File P1 (DS 12-28)W1-3 Anchora~8 File PI(DS 12-29)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany {r , STATE OF ALASKA ( ALASKA 0IL AND GAS CONSERVATION UOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLi~ID OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (surface) 289' FSL, 700' FEL, Sec 18, T10N, R15E, UM.. (Producing Interval) 244' FSL, 165' FWL, Sec 17, T10N, R15E, UM (Total Depth) 248' FSL, 168.8' FWL, Sec 17, T10N R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 71' RKB I ADL 28330 12. 7. Permit No. 84-58 8. APl Number 50- 029-21105 9. Unit or Lease Name Prudhoe Bav Unit 10. Well Number DS 12-23 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [--] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A/~CO Alaska Inc. proposes to perforate well 12-23 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximtm~ e~q~e...cted surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals 9000 - 9040' MD (40') 9052 - 9092' MD (40') 9106 - 9144' MD (38') Ref: BHCS~'16-84 Subseqa]ent Work Reported o. RECEIVED 2 $ Aiasl~a 0i~ & Gas Cons. Commission ^nct;orsge 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ .~__~g,-~'/,.:~ ~.,~'~". ~'~'~.e.,,,.~. Title REKjional l~girt~r The space below for Commission use Date Conditions of Approval, if any: Approved by. COMMISSIONER Approved Cop~' By Order of the Commission Date Form 10403 Rev. 7-1-80 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate DS 12-23 DRILLING HTSTORY NU 20" dtverter. Spudded well ~ 1800 hfs, 05/06/84. Drld 17-1/2" hole to 2500' Ran 63 its 13-3/8" 72#/ft, w/FS ~ 2477'. Cmtd 13-3/8" csg w/2000 sxs P~m "E" + 400 sxs Perm "C". NO 20" dtverter. Instld 13-3/8" packof¢ & tstd to 2000 psi - ok. gU BOPE & tstd to 5000 pst - ok. Tstd csg to 1500 pst - ok. Drld FC & cmt. Tstd csg to 1500 pst - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EI~I - ok. Drld 12-1/4" hole to 8906'. Ran 221 its 9-5/8" 47#, w/FS ~ 8895' Cmtd 9-5/8" csg w/500 sxs Class "G" cmt. Tstd csg to 3000 pst - ok. Drid FC & cmt. Tstd csg to 3000 pst - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg HEW - ok. Drld 8-1/2" hole to 9380'TD. Ran DIL/BHCS/GR/SP f/9380' - 8895'; LDT/CNL/GR/Cal f/9380' - 8895' (GR f/8895' - 2476')..Ran 17 ~ts 7" 29#/ft. Cmtd 7" 1hr w/280 sxs Class "G" cmt. Drld cmt to 9334'PBTD. Tstd 1hr lap to 3000 pst - ok. Displaced well to brine & freshwater. Ran CBL f/9318' - 8500' Ran 5-1/2" completion assy w/tail ~ 8636' & pkr ~ 8561' & SSSV ~ 220¥'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Secured well & ~eleased rig ~ 2000 hfs, 05/19/84. Injected reserve pit fluids into 9-5/8" x 13-3/8". Leave diesel cap for freeze protection. Displace to diesel & set packer, 05/21/84. Arcttc Packed 05/24/84 w/300 sx PF '"C". · o JMM/DHIO: tw RECEIVED 007 0 ]984 Alaska Oil & Gas Cons. Commission Anchoraoe ARCO Alaska, In~ Post Office ~°x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 26, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-23 Well Completion Report Dear Mr. Chatterton: Enclosed are the revised Well Completion Report and Well History for the subject well. The well status was formerly listed as "Oil". This error has been corrected to show a well status of "Service" and well classification of "Water Injection". If you have any questions, please call me at 263-4610. Sincerel. y~ T. L. Fithian Area Drilling Engineer TLF/tw JMM/L04 Enclosures RECEIVED OCT o 11984 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ..' ~ STATE OF ALASKA GAS CONSERVATION ~,.,. ,VIISSION ~ ~,... ALASKa,.,. AND WELL COMPLETION OR RECOMPLETION' REPORT AND LOG 1. Status of Well ]~V~ S~[ON Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE]{~ WATER INJECTION 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8a,-58 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 5O- 029-21105 4. Location of well at surface 9. Unit or Lease Name 289' FSL, 700' FEL, Sec.18, T10N, R15E, UN Prudhoe Bay At Top Producing Interval 10. Well Number 2~+Z~' FSL, 165' FWL, Sec.17, T10N, R15E, UN 12-23 At Total Depth 11. Field and Pool 2a,8' FSL, 168.8' FWL, Sec.17~ T10N~ R15E~ UN Prudhoe Bay Field .5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 71' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/06/8~, 05/17/8z~ 05/28/8a'I N/A feet MS LI 1 17. Total Depth {MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 9380'HD,9272'TVD 933~'MD~ 9226'TVD YES [] NO [] 2207 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP, LDT/CNL/GR/Ca], CBL, Gyroscopic Survey 23. CASING, 'LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULL.ED · ZU" 91.5# H-Z~0 Surf 80' 30" 1925# Poleset 13-3/8" 72.0# L-80 Surf 2~77' 17-1/2'.' ,2000 sx Perm 'E' + z~00 .x .Perm "C' 9-5/8" z~7.0# L-80 Surf 8895' 12-1/z~' 500 sx Class "G" + 300 ~x PF 'C' 7" 29.0# L-80 860~' 9380' 8-1/2" 280 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD int. erval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) · NONE 5-1/2" 8636' 8561 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .DEPTH INTERVAL (MD.) A'MOUNT.& KIND O'F MATERIAL USED · N/A · , 27. N/A PRODUCTION TEST 'Date First PrOduction I Method of Operation (.Flowi.ng, gas lift, etc.) . I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE '1 GAS'oIL RATIO ' I TEST {=ER IOD '.1~ Fiow ,T.'ubing !Casing Pressure 'CAiLCULAT'ED=1~ OIL-BBL GAS-MCF WAT:E'R.:BB,L. OIL GRAVITY-APl .(corr) Press. 24-.HOUR .RATE '~ 28. C.OR E DATA BriefNonedescription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core .cI~sEcEJYED OCT 0 1 ]984 Alaska 0il & Gas Cons. Commission Anchorage. c Form 10-407 Submit in duplicate Rev. 7-1-80 JMN/WClZ~ CONTINUED ON REVERSE SIDE 29. ' 30. ' ' " " GEOLOGIC MAI~i~ERs !" "' " FORM~TION TESTS" · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR0 and time of each phase. Top Sadlerochi t 8997' 8889 NONE OWC 9212' 9104 ' Top Zone 3 9220' 9112' Top Zone 2 9289' 9181' . , , ,, , , . , 31. LIST OF ATTACHMENTS , Dr~lllnn~ H~st~nry: Cyrosnon{e Survev (:? 32. I hereby certify that the foregoing is true and correct tO the best of my knowledge Area Drilling Engr. '/Z Signed T, L _ . .Title Date_ ? INSTRUCTIONS General' This. form is designed, for submitting a complete and correct well completion report and log on all types o'f 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-. lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in; Other-explain. Item 28' If no cores, taken, indicate "none". Form 10-407 , ,r STATE OF ALASKA ALASK~ ~ AND GAS CONSERVATION (~ .VlISSION ~~2 WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well ? OIL I'~x ° GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84- 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21105 4. Location of well et surface 9. Unit or Lease Name 289' FSL, 700' FEL, Sec.18, T10N, R15E, UM 'r'. .... :7 ......... ~- Prudhoe Bay Unit At Top Producing Interval I V'"'~;'~['"-r'" I 10. Well Number 24/+' FSL, 165' FWL, Sec.17, T10N, R15E, UN ~S~JrL ~_.:i 12-23 At Total DepthI ~ ;-' -~---I 11. Field and Pool 248' FSL, 168.8' FWL, Sec.17, T10N, R15E~ UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 71' RKB ADL 28330 12. Date Spudded05/07/84 13. Date T.D. Reached05/17/84 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns05'28'84 N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+'FVD) 19. Directional Survey I 20. Depth where SSSV'set 21. Thickness of Permafrost 9380'ND,9272~TVD 9334'ND, 9226'TVD YES rx1 NO []I 2206 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Ca], CBL, Gyroscopic Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" 1925# Po1 eset ' 13-3/8" 72.0# L-80 Surf 2475~ 17-1/2" 2000 sx Perm "E" + 400 ,,x Perm 'C' 9-5/8" 47.0# L-80 Surf 8895' 12-1/4' 500 sx Class 'G' + 300 ~x pF IIC~I 7" 29.0# L-80 8604' 9335' 8-1/2' 280 sx Class 'G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD) NONE 5-1/2" 8635' 8561 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A . , 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours TeSted PRODUCTION FOR gl L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEsT PERIOD I~ . I Flow Tubing Casing Pressure CALCULATED=1~ glL-BBL GAS-MCF . WATER-BBL OIL GRAVITY-APl. (corr) ' Press. 24-HOUR RATE =~ 28. CORE DATA Brief desCription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Cons. Form 10-407 '. Submit in duplicate Rev. 7-1-80 JNN/NC14 CONTINUED ON REVERSE SIDE 29, 30. GEOL, OGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad] erochi t. 8997 ' 8889 NONE 0WC 9212 ~ 910~ t Top Zone 3 9220' 9112t Top Zone 2 9289' 9181' ,, : · . , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~'L j Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and' leases in Alaska. Item 1' Classification of SerVice Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Meth'od of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate' "none". Form 10-407 ( ARCO Oil and Gas Company WMI History- Initial Report - Dally I~mlnmg~na: Pmp~m sd .ubmit the "le#lM R~t" on tile fl~t Wednead~y after a well le spudded or wor~over operations are .tatted. DaiLy wo~ p~or ta ,Pudding should be ~ummaHzed a~ the form giving Inclualve date, only. DJ~tdCt ~Counly, ~tl~ or borough lState Alaska i , . Noct~ Slope ~o~ough ~L~ or Unit T,,. ~L ~28330 . . ~ Dgt11. Complete & Pe~o~aCe Field Prudhoe Bay Auth. or W.O. hO. AFE 801828 Alaska elJ no. DS 12-23 Operator [ARCO w I. ARCO Alaska, Inc. Spudded 5/06/84 1800 Hr-~. Dete and depth es ct 8:00 a,m. 5/07/84 5/08/84 5/o9/84 5/lO/84 5/11/84 Complete record for each day reported 21.66Z it a W.O. 20" @ 110' 1050', (940'), Drlg Wt. 9.2, PV 13, YP 66, PH 8.5, WL NC, Sol 6 Accept rig @ 1000 hfs, 5/6/84. NU 20" Hydrl & diverter sys. 1800 hfs, 5/6/84. Drl 17~~ hole Co 1050'. ~pud well @ 13-3/8" @ 2476' 2500', (1450'), Dtspl cml Wt. 9.4, PV 16, YP 32, PH 8.5, WL NC, Sol 7.5 Drl 17½" hole to 2500', C&C f/csg. RU & rn 65 jCs, 13-3/8", 72#, L-80 BT&C ceo w/FC @ 2396', FS @ 2477'. M&P 2000 sx Cl "E" cmo + 400 sx Cl "C" cml @ 450 psi. Displ cmo w/mud. Bump plug. CIP @ 0630 hfs, 5/8/84. 13-3/8" @ 2477' 2500', (0'), Drlg FC Wt.' 8.5, PV 3, YP 2, PH 9.5, WL NC, Sol 2 Fin displ cmt. CIP @ 0630 hfs, 5/8/84. ND 20" Hydrl, NU & ts~ BOPE. wsh ratty cml to top of FC @ 2396', drl FC. ' TIH, 13-3/8" @ 2477' 4133', (1633'), Surv @ 4133' Wt. 8.8+, PV 5, YP 7, PH 8.5, V~L, Sol 4 Drld FC @ 2396' & cml to 2356', Cst csg co 1500 psi. Drl cmo t/shoe @ 2477' + 10' hole. Perform leakoff tat to ll.2'ppg EMW. Drld & surv' ~o 4133". Sur: 3951' MD 1/4° S38E 3951' TVD -1VS SI3 W2 13-3/8" @'2477' 5462', (1329'), Drlg Wt. 8.9+, PV 5, YP 6, PH 8.5, WL--, Sol 4+ Drl & surv 12~' hole to 5462'. Surv: 5156', 3°, N80E, 5156 TVD, 4.31VS,, i5.22S, 2.77E. 443?', 9-1/2°, S84E, 4435 TVD, 36.16 VS, 14.38S, 34.74E 4706', 15°, S82E, 4697 TVD, 96.62 VS, 19.88S, 95.07E RECEIVED SEP 1 1 1984 Alaska 08 & Gas Cons. Commission Anchorage The above Is correct For form preparation and distribution, - / - see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 5/22/84 Title Drtllin§ Superintendent AR3B-459-1-D Number all dally well historY forms consecutively aa they are prepared for each well. no. ARCO Oil a~ . Company -, ~ v Daily Well History--lnterii;i I,,&;;-=?_-_::_-: This form 18 ueed during dr ng or workover operations. H testing, coring, or perforating, show formation name in describing work performed. Number all dr &;~ testa sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets until final completion. Report o!flcial or representative test On "Finlr' !orm. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wedneadey of the week in which oil string ia set. Submit weekly for workovere and following setting of oil slrin§ until completion. Olatrlct ICoumy or Parish Alaska North Slope Borough Alaska Field ILease or Unil IWell no, Prudhoe Bay ADL #28330 Date I 12-23 aa of g:00 a.m. record !or each day while drilling or workovar in 5/12/84 thru 5/14/84 5/15/84 5/16/84 5/17/84 5/18/84 13-3/8" @ 2477' 8323', (2861'), Drlg Wt. 9.9, PV 10, YP 6, PH 10, WI, 6.0, Sol 10 Drl & surv 12¼" hole to 8323'. Surv: 5195', 16°, S80g, 5168 TVD, 227 va, 40.28S, 224.14N 6681', 16°, S89E, 6595 TVD, 640 rS, 65.88S, 637.18W 7105's 14½°, S83E, 7004.45 TVD, 751.96 VS, 73.06S, 748.33W 7965', 2°, N37E, 7857 TVD, 843 va, 47.00N, 842.66E 13-3/8" @ 2477' 8906', (583'), Rn'g 9-5/8" csg Wt. 10, PV 10, YP 4, PR 11, WL 5.6, Sol 11 Drl 12¼" hole to 8906', 15 std short trip, CBU, TOH. RU & begin rn'g 9-5/8" csg. 9-5/8" @ 8895' 9205', (299'), Drlg Wt. 9.4, PV 8, YP 3, PH 11.5, WL 6.0, Sol 8 Rn 221 its, 9-5/8" csg w/FC @ 8817', FS @ 8895'. Tst pack-off to 5000 psil M&P 500 sx C1 "G" w/.15% HR-7 & 1% CFR-2. Displ w/rig pmps. CIP @ 1545 h~rs, 5/15/84. Chg & tst rams. TIH, DO cml & FC @ 8817', tst csg to 3000 psi, drl 10' new hole. Conduct leak-off tst to 12.3 ppg EMW Drl 8%" hole to 9205'. · 9-5/8" @ 8895' 9380', (175'), Rn'g 7" lnr Wt. 9.4, PV 7, YP 3s PR 10.5, WL 6.2, Sol 8.5 Drl to 9380', C&C. RU & rn DIL/BHCS/GR/SP f/9380'-8895'. Rn LDT/CNL/GR/CAL f/9380'-8895' & DR f/8895'-2476'. Cond hole, CBU, TOH. Chg rams & tst doors. Begin rn'g 221 jtss 9-5/8", 47#, L-80 BT&C Csg. 7" @ 9380' 9380', (0'), TOH Wt. 9.4, PV 8, YP 3, PH 10.5, WL 6.8, Sol 9 TIH to 9380' w/17 ]ts, 29#, L-80 BT&C tbg w/FC @ 9335', TOL @ 8604'. M&P 280 bbls Cl "G" w/5% KCl, I~ CFR-2 & .3% Haled-24. Displ cml w/dr!g mud using ri~ pmps. Bump plug. CIP @ 1530 hfs, 5/17/84. Chg rams, tat doors. TIH, tag firm cml @ 8385', drl cml to TOL @ 8604', CBU, TOH. The above is correct Signature For form preparation and j~lstrlbution see Procedures Manual Sbetlon 10, Drilling. Pages 86 and 87 ~" 5/22/84-rfi~. Drilling Superintendent AR3B-459-2-B RECEIVED SEP 1 ! 1984 Alaska Oil & .~[~s in~r~i~.l~ra~rl~i~;l: ....... Lively afli~hnmoe ' JPag~ no. ARCO Oi ...,,. Gas Company uaily Well History-Final Report Instructions: Prepare and suOmH the "Final RePort" on the first Wednesday after allowable has been assignecl or wel! is Ptuqged, Abandoned. or Sold. "Final Report" should be submitled also when ooera:ions are sus0ended !or an ~ndefin,te o' appreciable :ength of time, On wor~iovers wheo an official test ~s not required uoon completion, reDort completion and represental~ve test data in blocks Prowded. The "Final Report" term may be usecl for reporting the enhre Operation if space ~s avadable. District Fiel~ ICounty or Parish Lease or UP, i: Tille IAccounting cost center code s'.:,',e Alaska Auth. or W.O. no. Alaska Prudhoe Bay North Slope Borough ADL #28330 Welt no DS 12-23 AFE 801828 Drill, Complete & Perforate Operator A R.Co. W I ARCO Alaska, Inc. 21.66% Spudded or W.O, begun Date Spudded 5/06/84 Date and depth Complete record for each day reported as of 8:00 a.m 5/18/84 7" @ 9380' 9334' PBTD, (0'), RR 9.6 Brine Wtr TIH w/6" bit/7" csg scrprs, DO cmt to FC @ 9334' 5/29/84 Iotal numOer of wells (achve or mactwel on tms est center prior to pluggmg and bandonment of th~s well our Prior .'.[a:;JS if a W.C. 1800 Hrs. , tst lnr lap to 3000 psi. Pmp 596 bbls 9.6 br. Rn CBL f/9324'-8500'; good bond. Rn 210 jts, 5½", 17#, L-80 AB Mod tbg. NU & tst tree to 5000 psi. RR @ 2000 hrs, 5/19/84. (Will displ w/diesel & set pkr after rig move). SSSV @ 2207', PBR @ 8537', FH-L pkr @ 8561', Shear out Sub @ 8635' Tbg Tail @ 8636' Rn gyro surv to 9300' MD. Old TD I New TD PB Depth I 9380' 9334' Released rig [ Date Kind of rig 2000 Hrs. I 5/19/84 Rotary Type completion (single, dual, etc,) Single Official reservoir name(s) Flowing Sadlerochit Potential test data Classifications (oil, gas, etc.) Oil Producing method Well no, Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump. size, SPM X length Choke size T,P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ~2~ ~,~_~.~ , [Date 5/22/84 Drilling Superintendent For ,orm prep~ra;'o; AR3B-459-3-C SEP 1 11984 Naska 0il ~'~mNr~l N~I~II~I I.~t~4~o~f~'~'~%~ecutlvely aa Ael~(~ffO~l?~:)~d f ..... h well, ' iPage no. 3 Division of AffanflcRIchfleldCompany sper,r -sun gUNE 28,1984 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box :360 &nchorage, &K ~5i0 Re: Our Boss Gyroscopic Survey gob No. AK-BO-40045 blel 1: 12-2:3 (SEC18 TION R15E) PRUDHOE BAY North Slope, Alaska Survey Date: May 28~ 1984 Operator: Sel I ers Mr. Ruedrich: Please ~ind enclosed the "Original" and one (1) copy o~ our Boss Gyroscopic Multishot Directional Survey on the above wel I. Thank you ~or giving us this opportunity to be o~ service. Si ncerel y ~ NL SPERRY-SUN, INC. jm/AK Enclosures Ken Broussard Dist~ct Manager RECEIVED S£P ! ! 1~!~ Alaska Oil & Gas Cons. Commission Anch0mge ARCO ALASKA,.. INC ...................................... DS 12-2F.': (SEC 1.':_:: T10N R15E) PRLIDHOE BAY ALASKA ....................... VERTICAL SECTION CALCLILATED AI_ONG RL.(')::::L~RE:. TRUE SUB-:SE;A COURSE MEASLIRED VERT I CAL VERT I CAI_ I NC L. I NAT I ON PEPTH ......... DEPTH ........ .DEF2'I'H ............ DEG. . M I N :-'-~:F-'t.:"I~tF~;Y--'.'-:;L.II~I WE'I.. I._ ::::LIRVEY I NG COMF'ANY ""-' '~i~l~".',i~'j: : ..... · ' .-' ~f~" :'-. ....... :! k, '..:- ..v ................ ..: ...~. :. .,~! :.ff .... !;..:. :... .. : . ........... DATE..OF.. :::IJF~VE.~.. ~11~_¥.- ~27_~ :Jl.g88.?'~ '.~-[.'; C..'.'.;'~:':~... CC)MPLI'FAI'ION DAl'~: BO:SS AYROSC:OPIC F;I. JRVEY I. MAY 2'P, 1'P:34 ,_lOB NUMDER AK-BO-4(])045 .......... KELLY BL!::3LI-'[ N:3..ELE',6.._.---_ ~ _7 I_./__')L'I ._ F..T_;_.... ~ ...... ° ..... " "l ''~ '"' " 'e ~'' ': .J F' I:::. F,, A T L F',, - .::, E L 1_ l.'.. F,, .:. · " .,. ' .. ..... :~....,:' . . i '..; '.. ?... i':~' "P. i' '. *:':. · ': '.." : ,i '~ · ," ::' ,.' -v..: .: i':. ' .- 4. -. · · ........................................................................................................................... :: ._,~.t.~_~.L'~;'_..::):'[~ '.~-[..s-.'..:~:. COURSE ].]Ot]i-LEC.~ TFiTAI_ 1'.'.; I RIE'(': T I ,'IN SEVER l 'T'Y RE(":'T'ANFiiLIL. fiI':~ f..':('IOF~F~ Z NATE~ · VI:'RT Z CAL ( DE:'Cq'qi:i:F:--:..DEO/1Qr'! ....NC)R:'FH/SC:,J'I"H .......... E(.t~:,'I'J.Z.~.E.~LT .... , ....... 0 0. O0 -- 71.00 1 O0 100, O0 ":"-' OQ .............. ....... ~ .................. 2 C) 0 200.00 129, 00 300 :300. O0 229. O0 .............. 4.o~:~ ................. ~,O(L..[U:~ ................ ;D;!'}~.. 0(~ ................... 51"tO ~ ' . ,.:.OU. O0 429. O0 600 599 99 ~"',", ................ 7.QQ. ~" '" ' '~":' ................ .............. 6.~.y...X~ ..................... 800 '7'79.99 ' "'"'" ... 7 ~:,::., ':) ':~ '~00 8'P 9.99 "~'"'"' ':;',:~ . . ,~ ~ 0. .. 1 (') (") (') 999 '~'~ ............... ~ .~ ~ ................. . ~, · .. q .. ............. ~.~.~ .~- '.~.., . , ...................... 0 0 N .0 ......... ':.'/ ('~ 3 :ii.:; 0 6 S (! ...... L'P. ...... 1'4 0 27 N I.') """'" -",:::, N 0 ....... 1 = I',1 ....I , ,.,, 0 15 N () 16 I',1 11 O0 1099 o,- .., ~' 1028 99 ~") 1 ":' i m . , ... 1200 1199 ':T, 9 ! 128 ':.)9 ¢') '":'":' I · , ~ · .. a:...i.% 1.3~]0 12.9'.:.~ 98 ~"~'"'q !;>.8 ............. 0 :20 ........... .. ............... 140(") 1:399. 'P 8 1:32:3. 'P::ii: () ::;il F) 1500 14.'?'P. 'PS 14';::8, ?8 () :'"":4 £;.~ ,,'", ,..., 1600 1 '-"i ':)"-), ? 7 ~.... ~.'..:::,. '."? '7 0 4. 5 ........... · .,- .. ,- · . . .... ., , 170 ~"~ .! 69 ?. 96 :L 628.96 0 5:2 18(')A 1799.95 1 .... 7 -,' "'",::,, "'"::, .:.,"" 0 :::; ::::... i ."! i'"l 1900 ..... 189'9, ¢~.~ ..... :LSd;,"-,. !?:3 I '.:;' o.... .............. '..-.:0()0 1 'P'P':~ · '..'~ 0 I. 9:::::8. '-'~('-~ I ::ii: 1. 21 O0 20'..'.:,'P. 85 ':.::0"2::'..: · :i'J:5 '2 15 2200 '--: .................. · .-. 1 '..:, '? ...Z Z.. "" .... '""' .. ......... ~:, 1..¢.,":,, '7 'Z 2 1 '-'"9 "! ,.'._ ¢.. 0 2299, 70 :'":"'"":' 70 '"::' '" 24(])0 2:39':..'~, 65 2.328.65 1 :")2 ................ 25.00 .......... 2~t9. S?..6:3 ........~..4.28, 6:3 ..... 0 51 2/-,F,q] 2.'=';':;,'~ 61 "-"':~'--"::' /-, .1 C) 47 ..... · ... . · -'-.-- -" A,..~ .. 270 () 26. 9 '.:.;' .61 .~-""/-., ~.":' ,---,':'. 61 O. 4. 4 2800 2799, 60 .-, '7 o,::, 60 .... : ,.. ................ ~L,.~,..,,:.,,.,, · .... 2'PA('t .... ,,':,,-,o ,~;,:~ '""'""°" · .,:'- C, ::'., ~ -.., 4:. (:'.~:; ,:.') · .... N S N ... Iq N S S :""i; .,..:..; :::; 1:::; ,::'. :'3 ri::; 0 4. 2 ':::' · , ........ O. 0 O, 69 :3:3. !15 () :3'7. 10 .57,.:3i~ 60,6? 56, '""(" ,:,':...) I:::' i' 'I .... ,,:::,..:!:, 0 77,8?.:' ' ~::i"':' :'"";("1 71.50 7 ...... :':1 '::) 6,1 ,. 89, '7.'2. 10 :'_::7. '"'""' ~:.,, .:, 50 · 60 41 . 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E O, """" 1 ":":) N'"', 6' :: W I m I ' ~: '...f;~:~.;~2~'~74 ~!. .~..~: · .,'.... . ..:, ,.,.~ ' ~' ;.'..,~.'::..;~.~c:..? ""..~. i .... , . ,,,.,, (, .... ~., ,, . E: o, .1 ! .................... :[, .4.':~ N ........................... 2 ,..1.LW ..... E .0'7 .~. /:.::: N 1.56 W -!·6 E (). ::5,'.':, 1. ,.12 N 0. ?8 W --1,04 E ........ !) ·.,2,1 ......... 0 ,, 61 . I',1 ........................... ,O.,,..J/-:,...H.... ,,::J'l,..~,'i~L ........ Ii.:' (:), 1 '7 (). ::.,':Fi: .S'; L). .... L~7"'" F' . 0~ 88 E 0.,:.'"'"':'..., 1,44 ...,'::' :-2.0'7 E .... ..' 2'~;~ '! 4'" ...................... · '"'~ .'~'1 I'( ~""° '° E ~"~, 26, ,~, ._., r._., c: ........................ ,:.:(.,6bL E ........... ~.~~9 ....... I]:.' (). 4.5 ::ii:. 1 I S 5, :..]:'i;~ [ii: 6, 0:.", E: ('). 72 :3, :iii:8 '.i":; '.:.';'..1 () [!:' 9.27 E ! · O1 '.:'"; '""i'::' S... :L":' ':::'":' ........... ~...~.~...,.... :E__ ............... ~ II ,....~ ........ E.". 0 ·,.":~ ~"~..,..,'::', O'P '..'.:; 1 .~~.i, :30 E E 0,54 1() 41 .'.'3 17,41 E "': E ..0..?s .. 1-';::,,s · ..... Iii-" 0.0f::. 1""..::,. 4:":: :ii!; .L":~... 19. E 19.7':-) E O. 21 ! 4. '70.. ....,c:. .1 o... ~."]/-.., E 20 .2:3 ..... ' 19, A:'.'¢ [':' "¥1 ':,~.'~ W O, 1.., 1.5 ":;'/". '.:::; ..... · .............................................................. ~~.,Z.~ ..~.t :,,." ........ 14 0,. I 1 1 '7 , ':lit.'.'..' S..; 1 '...'~., 47 E ~.'0, 2 ARCO ALASKA, DS 12-23 (SEC PRUDHOE 8AY ALASKA SF"EI'~:r~Y-...'.3LIIH NELL S;!JI~VIZY ING COMPANY A I',1 C: H O F;: A 13 E A I_ A,':.3 K A INC: ........................................................ 1::': T'ION F(15E) F:C'IHF'I..II"ATIOiXl DAT~ 1'4A¥ 29, 19:-34. · ...... .....~,~..~..~.. _ ~ ....................... VERTIC:AL ::.';ECTION CALCULATED ALONO C:LOG;LIRE~ MEASURED DEF'TH TRUE ............ ~L;~'"' SEA "' ,::C, LIRF::E VERTICAL VERTIC:AL I NC:L_ INAT I'ON DEPTH ............... D..E.F_'i l:H ........... r:lEf3... 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OSLIRE TRUE SUB-SEA COURSE:' MEASLIRED VER'I' I C:AL VERT I CAL I NC:L I NAT I ON .... DEE'TH ............... DEF'..TH ............ _OEPT. H .............. DEG ..... H I N ..... &O00 5941,29 5870.29 16 0 610.0. 6037 :'~'-' ' - '-" ~; ....... D~66 3Z . 16 1 . m ~, m ...... ~ ~, ,~, 6200 61 '"""~ ~o. 21 ~062 . ~"':' 1 16 .... ":"' 6300 622'2.07 ~ 158.07 16 25 64. C,] ........ '-"-'~; 09 6'2~;4. o9' ............ 6.. . () ....... .................. 6-:..<. ................................ 1 6500 6421.21 o.: .... , z.l 16 0 ' ' ~ ~'~' , ":"=' 5 48 66o0 6., 17. ,.:,o a 446 1 ~ .~. . ~ o 6~ ..... 5. .... ...................... .~700 ................ ~&i~.,..6,~ ............. ~.~.-.4~ ........... 1 . ~ ~ ............. /-,800 6709. ?7 66:38.97 ,/:,'F'O0 6806.45 67:35.4.5 /_",,_-_,.-,~., ~. ~.-, 7¢"~AA /-,'.T~A3.0~, "'""'"; ''~' - -,. -. ........ ~ e. ~ ............... 0.~..,~.~.," . ' '"' " ' ....... ~ 7100 A99'~_. . . .,_':::.~._ 6;928. ,--,'="='..:, 7200 70?'6, 95 ." 70:;:.:.'5, '~"'...'", ....... 7300 7.1°':'; OZ ............. !i.Z.12.4., 07 . .. e~.~ ............ . . , '7400 7294.07 7223.07 .... 7~,...~.. 44 '7.=; 00 73'2:3 44 ' ':'":' '-' .............. 1.7.6!:)0 ....... 74'2.;3..93 ............ .7...42:2.0:':':. 7700 7592, 7:3 , 7521.78 7800 '7692.61 7621.61 .... 7:,~00 ............ 777,2..50 ...... : 7.Z2!. 50 '" ,",'::,1'"': :::::000 7,:, .. ~.. 42 '7:-"::21 4 :,7.: · _,':'100 7'F/'.:.;'2 .37 7921 . :3'7 ...... E:2C)C! ...... :.3.0 ';> :2 . :~:,.,1 ...... 8.C!21. :34 15 .1..'.:9 14 14 ;i '"" ,? '7 5 4 ....! 2 .1. 1 CC) I..IRS E DOG-. LEG [) I REC"[' I ON SEVER I 'tv DI::GREES . .. BEG/1 S :"-':6.3'2 E ':::' ::'::.":; /',':) E. :i::; :.':J:4. () E 8300 A 19': ....... .,- . ¢'," .... -,-. c::z 81 '.-" 1 '~''''' 8 4 C) O ""o .." ..'-' "-'~ ..-.° :3 0 "8 2:21 .3. (]. · -- ~ ' e'-'l '"~ '"~". "'" ,'", . . ,..-' 8~0 f'~ ........... 8;~ c,:,'2..Z.~ ............. ~..:.,,. 1 ....~. E:6C)0 8492. ~.7 843:1.27 ::370 () ,-, ~; 9 <' '2,4-,'"' ":'' "'" ,-.,., z 1 26 · i~._ . ,~. ~ ....... ~ .. ,::, . ,--..-:, .-, ..-.. ,...,/..'", t .'? :":::'-"~1")() v/-', ..~, .~'.~:..' '=' Z'.~; J., ~"'- . ~ ...... , ., . · ..... ...... ";>'7 ";' ~ , 8900 '::'7'::>";' ?4. ,: .......... 24 'i ' .. ! ~ ..-.<.ur.. DA'TE. OF:.. E;URVEY.....P. IAY-27....~~i, .... :~-':-:-:': ...... BC~S:'--; C~YRI".]:=;COF'I C: SIJRVEY ,_II:,B NUMBER AK-BO-40C)45 E; ,:. 4..,::, ..) .,, N 87.39 N 78.10 N 66,, I',1 55.69 N 4.'.':.';. :30 N :3'7.10 N :35. :=;C) N ::ii:4.6() N :3"1. :.:i: ...~ N ..:.4. :.'..::'i~ N :.:'::1. 0 N 25. :::;0 N 1'2. 10 N 1'::"',.,. 60, N .1. 1. '7 4./..:. :...::,...j :37 30 :34 1 '? 6' 3 :3 '? 45 4 ! ~'7 ..................... KELLY.. BIJ.'.-~tJiIYG....ELE~/.... = 7 !. oo FT'. _._ ,..' ,,~ .' ,..:,: ............................................................. _ -:- :;,t._ 4 -~-JJ:?-:'--. " I"OTAL ' F.;jEr. C'I"ANC;UL AR I::OORl) 1 NATES VERT I CALf _. NOR'I]:I / SOL~.]]i_,_.__E.~'.~-[z]4ES.T _.::_ ._._. ~..t.._ ~....q_ ~_,~.. :..,.' ::,:::,... .::,., O. 0:::: 52.50 q ~/-'~ '"~ ": · :. :470.~.:~ ... -,,...-,,:....,._ r.:. ' ":' "'"' ;:' ¢''~' 0 .... ,=,..., .......... 54., 27..S ............ . ..... ..4.. ~.&. .U Z._E ...... 0.:34 56.. ..._,'":":' ::.'-.'; .::,....4.4C) E 526.46 C). 5:3 58.7::'; ::":; .......:.. 7,. E 554:39 ':';'::' /1(' ) 'N l'l l"l 7:2. :3:5 F.; /_-,=,,=:,. ,~$,'=: E 6~1.53 '75;. 46, '.::; 715.0/_-, E' 717.81 '7'7 91. '.::; .......... 7 z~ ~'"~ v 4 ~::' _743. ~;.Z--. # . ..... .... a. ,,..~.#...' ..... ~ .................... :30. '1 1 :::~; 76.'.5 ''~'-' . . .=.,= E .768, 74 ":"""' 86 '-' '~'"-':'~ 50 E 7~2,51 ,::, .,:....=. /""' ." e ,, .. ::3:!:, 64 '":' "."'"'h~ E' ... ~ ..................... ~:.,.,..,... ""'"'" ().l :5; ,2.-,.":, ~;~ ,=,.,::., , .... -... I E;' 825.4,'.1,. '7:i.i: '76 S ,:::,'-,'::, ,::, R'~-~ ...... ",._, 1 E ,:-..... . . · ,..' . .. ,'". ,2, ~ '? ..... 74. :::::/", .=,. .............. ,..:...1. i .... :.;.... E , ", .. ...., ... '71.14 S ,:::,'1,7...'7 E 849.67 67 ~.I" .... '"':' 73 :' 2o ....,:::, ,=,.:, ! . ...............S "::'""-'--,,~ 4.~,':":::/..., .E: ............ .El~i6..,.,~.~.~' . c =' . '.iii; :i.:.':!"'.~'7.1'7 E ~q~'-~.. 07 '.i""; ,:::.'""':::/:'.. ,.:.,. '::?0 E:' 860.6'.-? ·., 54.5'2 .'.'":; ::-~/.... 1.51 F' ~ 86;3.12 .53. ~")(:) 'S :36:;:'.. 5:3 E . .864.06 · .'"91.35'; S , .. 86.3 ...43 .E ......... ,'1.9. 'i:>:i:: ::3 ::::,:=,4.01 E 865.41 4,:3.85 S :::::/:,4.51 t:-: 865.85 .42', ,},?. 5; .... :36.5, ~"! 1...E ........ 4<!:,,. :'3.1 :ii:; ::'i:/::,5. :'3./:, F 86~. 58 ARCO. ALASKA, INC: .................. 2 '"'" '":' 0 I.)S 1 :.-~:.-, ( "SEC J.,.. l" 1 ()N R 15E) F'f-iUDHOE BAY AL IIS;.':.'A ' ........... SF'ERRY--.F:i;L.IN WELL '.3L.IRVIL:.YINO COMI='ANY K~NC:I4OR(~GE AI_ASI<A ......... E:C'mHF:'I..i'I' A l' I I)N [)A"I'E Hl:~ Y 2'?, t '.':'> ~i.:.'. ,.I VERTICAL SECTION [;:(~LC:ULATED ALON6 CL. OSUH;E IZ: 0 U F'( ?.-; ED 1'3 f3 - I._ E: Df:'k"f'E OF '"'1' " '"" ~ '"'" :~'~':- ' oL I~VE.Y'..,..[1AY-.,~Z~.__iStEi,4:.,:..' :."- ':'.' '. ' . BCmS:"", f'gY'RCfSC:OF:' l 6: SURME¥ .... h.'.)[.~ NUMBER AK-BO-40045 t'::EL. LY .BUSH.[N6...ELE~.,.,~:! 71.00 OF:'IiEf:~A'T'OI.:~-Fi;EI...LERS --!':;-- '~ .; "'¥~'7 .' · · .. .- . . : . · ......... . .,.0 ......... ±: 'f' O 'F A L HEASLIRED VERT I C:AL DE:F'TH ........... DEP .T. H ............ .DE.P_ l':.H ............. D E."C~ r'l I N VERT I CAL I NCL I NAT I f')N l) I F';tE:C:"I' I m.:)lq SEVEF~ I TY F;:IE F::"I"('~NOI..II_Pd:? C:OORD I NATES VERT ! CAL ,. .. DE,'£~F:~I~.'-':Iii.":.':.; .... .[:,F.!i:O.,.' 1 (.1!!:!. NOi~."i']:.J../iii;L:,L.l:[i:.l ...... .[...::.f:~.~;.]'i/_W.~:~;."~L!: ..... , ..... ':.~'100 '-~'~'-~"'-' 21 (3~21 · 21 0 48 '.;'2()0 909':.". 20 9021,20 (-~ 4.'5 ':..'c::Fl¢"~'=;' 19': ..... ' "l · '? '.'2 0 4. 6 .......... ~-t. 1 '-.--' 1. 0 I',l 2. 1 () EL (:). :Z 1 N 22.1 '? Ii:.: 0.56. N 4:::i:.:39 E F).15 Iq 6 :.":../:.'.:::' ii?.O. 2:3 9380 ':x::'7';'. 1":~ '::~201 1 ':~ 0 46 N 6.3, 4:.':> E:' ('~ 0:3 4(). ,.':.,I '.'Z; ::=:6:=',. 80 E _8~'~. 75 . _ :;?-'.. ~ ...... :% ............. ¢~.....~ .... ~...% ............................... : ......... ~ ........................................................ ........................... 7 r ,.~ ~ HOI'~IZONI'AL DISF'LACEMEIq'T =.' (!i:6S,',75 F:'E:ET' (:.YI' i:i;f."ll..r'f'H :i..':'7 DF:B. :l.'i? I','llIq. IF':A'.3'T (.Il' MD =: '!i~:3:30 .'; ' ............................T'HE CALC:i_ILAT 1' ON F':'";"::"-:'"'":'"'J":""""RUL. EI"'L RE..:: .... ...... '~'tF;:i"i"'Eif4:'SE[) oN"fHE LIF.';I:= F:q=' I'll' I" ~ i:;: I~: I:~: E'IHi"":N:i:;IF)N¢"fl.--'RADI"iii?::; "CmF'" F!iLiRVAI'I_II:d!""' HEI'HOD. ANK:HARACq?-' ALASKA ...... ARCO ALASKA,..INC ............................... DS 12-23 (SEC 18 TION R15E) PRUDHOE BAY ....... AL~SK~ ................................................... CIDMI':'UTAT I ON DA-~'F MAY :::.:'~', 1 'P84 " · I-I I ' ~I -. ~ .- ....ELATE OK. ;~,L RVEY HAY_ 2'7..,.._j,~Z~.._' ,_;CID NUMBER AK-BO-40045 ............................... ]':::ELLY_.BU:SiktI NP.~_EI~V. _ = .-~,: 71 _. oo_ _ET_- .... OPERATOR-SE:I_LERS .............................................. INTERP..OLAT'ED VALLEoI'"'-' FOR EVEN 1000 FEEl". OI:.'..MEASURED..DEFFrH ................................................. ': ' · TRUE SUB-SEA ]' OTAL. ..... IYIE~tS. URED .......... .VERT ! !-:AL ..... ~.ERT. I CAL .....REC:._TANGL~LAR . r-:or'-q:U'-i ! NA'I'ES ........... MD.-.-. T.VD .............. V£[;L]:.I.C:AL DEPTH DEF'TH DEPTH NORI'H/SOLrT'H IF"AS'I'/WEST [i I F:F:ERENCE COF;:RECI' I ON ,.0 .................... 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THE USE..OF"...THREE..BI MENS; I ONAL. RAI:,.I.U~;....O.F.': .. L:L"" ID.VA' 'I..URE.' '" ' ..~IE,.'t..PI.O.D.,,,, ...... . ( ~ · . ~ , A.I',ICHORAL]E ALAL-':I'.'::A .'-~ .. . '. ~.:.:, ARCO ALASKA,... ! NC .............................................................................. DATE OF....:E;LlI~V. EY,...,.J~i~..Y_,2,7_~,_~..I_~84_:,_ ~. · .- ........ D'.E; 12-'23 ( SEC F'RUDHOE BAY HAY '2'.:.), 1'F,~-34 " ._lOB NI..IHBER AK-BO-40045 · ALA. SKA ............................................................................................. F'..';.E.'.LL.Y_..[~!2..[~!:E].~j_E.~.EV. ~ 71.00 FT, " OPERATOR-.3EI_LERS ...... ..% .....;: ~: .?~. ............................................. I N..T. EE~E',~..Li~.T. ED .V. ALLIE~'~ FOR EVEN ..lC,') FEET. CIE..f.~UB:-.:E;EA_D. EF::.T.H... ..' ' .~ ....... ..................................... ~.:__:.,,. ~.: ..;: ..~ ~. __.i( ...... ' .... TRUE SUB-:=;EA TOTAL ., MEA:E;URED VERT I CAI_ V~ E~R .T.j)..I.:.: .A.L. ..... _R..'EC TANOUL. A..R ..... f':OI:IRD I NATES MD- TVD VERT ! CAL . ...... ( . :. '.. . '.: .... '.~::..,;~ii!:'..~ ~:i.:.~.':.~. ., ~ ................ _Q. .......... : .... .Q:.....~).O._: .... ~],.,1., O0 O. O0 O, O0 O. OO ' , .' "~;' .' ' '....:.':'...'~'~."~. '..~.'.'..'~?~'~.,.'~"~."':~'.'..~.'..'": ' ' ................ '~ ............... ~ ........ .o~ .......................... o.~.......~.~.,o..~.-.~..~.~w.~i-~ .... '~'_'.,_~_'~..':~_'_'~ ~ !:~.'.!;..i~.~?,'.,~, :.,; ',', ~ .. 71 71.00 O.00 0.06. S O. 171 171.00 100. C) 0 0.30 '.3 0. 2_.7_!_ 2.71. OC) 20Q :. O0 .,.!:). -. 40 ...S ................. O. · _'371 371 C)O "'--'(' '. . ' . ..', .)O C) 0 C) 4-6, ~:.~ O. 471 471.00 400.00 0.14 S O. .......... _ .......... ~Z.,J, ................... b:..Z ~,..,.,0..0. ........ ~9...O,...,.O.Q ............................ 0...27.. N ..................... 671 671.0 C) 600.00 0.6'~ N 2. 771 771. O0 700 · 00 0. '!.://.:., N 2. :371 :371 O0 :300 ("~0 1 17 N ":' 971 '.~71 O0 .900 O0 1 :'..:'.'7 N '"' 1071 1071, O0 1000, O0 1 · ~.~:":'"'" N ............... 1.1..7.1 ...... l I.Z l., Oo ........ .L~.O...o.,. oo 1 "'.'-' ·, ............................................ ~;,,'F,, N 1271 1271,00 :J. 200,00 1,41 N 1:371 1:371. O0 1:300. C)C) 1../:,7, N .. . . ......... 14'.7..! ........... J. 471....00 ....... ,..,.~,4..C!0, C)O .............. 1../_.',.5. Iq. 15'71 1571· C)(') ..... i :-fAA .0A. 0 . ,::,"" '"=...., N 1671 1671. C)O 16CJO. O0 (:). 0.% ................. i. 7.71 ......... !.7...7!.,.00 ................ J.:Z...OQ,.O0 ............... 1.16. '.:J. lli'I a" B 1. C), 1. 00 E:' ('-). O0 O1 W 0.00 OF-: W ("), (")C) 27 N 79W .4':?,,.,W ................... 11 W 4~ 14 :?:~6,,~4 .... ..... ARCO. ALASKA, .... INC ........ DS 12-23 (SEC 18 TION R15E) PRUDHOE BAY ....... ALASKA ......................................... :--.;f:,~:~.i~',;,:S'l'_lN WEL. L SURuEY'IN,3 C,:};~:i~-'A'Ny ....... · ANC:HCIF:;:AGE ALA'.SI.:::A COMPi_I'T'ATION DA~'E MAY '.:.'.".-?, 1':?:::4 ' .RAGE,.'. 7 -. DATE OF..$URUE,.Y,,.. I '"- "" ' I:'. A.Y--~.Z..--..t:~A.-_.~ ..... ,_lOB NUMBER AF:.:'-BO-40045 .... KELLY.. BUSHI r.~PERA']'OR- SELL ER.S I NTERE'.OLATED VALUES F'OI:~ EVEN 100 FEE'F OF. SUB--F;EA ' . ................................... .......................................... DEP:T,H TRUE ........ MEI~SUBED. ......... .VE~TZ.CAL.. DEPTH DEPTH SUB--SEA .. VEE.'I:. I C:AL ....... REC'FANOUL. AI:~ DEPTH NORTH/SOUTH .................... 187.1..,~ ...... 18~1.,00 .... ~BO~.O0 ................. 2. ].~71 1~71.00 1~00.00 2. 2071 2071.00 2000.00 3 ............. ....... ..... .................. 2271 2271.00 'm "2200.00 7 2371 2371.00 :2300.00 ~ ...................... ~iZ! ................. 2~71.,.0D ............. 2.~QO...O0 ................................. 11. 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()0 E ......... 0..47 .......................... 0,..00 ........................................ ~__ .... · .'.:.i;F'ERRY--.,'.~;IJN WELL .'F.;URVEYING C"-IHF'ANY ' "' ' · :: .' : '., . . '":i'~..;.":. '";i;:~:;~.~':: '*.!'. '-.:.~ ': ANC:HOF~AC.~E ALA~K'A i ." . ' :...'!:~~.~:~ i:i .: ... ARCO ~tLASKA, .... INC: ............................................................................................................................. DATE.. OF__,$UE,~~Y--2-7 ...... :=.'~'~lll~t~}Ai~.'.i~i:i'::~lt", DS 12-22: (SEC: 18 T10N R15E) CCIHF'UTATION DA[.E pRIIDHOE_ B~Y HAY ,:.":'°..., 1,..:>84 '. ,_lOB NLIHBER AK-BO-4AA45 .... ...... ALASt:;'~ ~ ...................................................................................................... b':ELL, Y... BU'.'2;I=(I}(~,.~L~_.=.=_ ...... 7 I, 00 FT. OF'ERAI'C~R-$ELLEF~:3 ).:' ;i. -'-: ~ ..... =-~--=- ' · .!.;: ~,,.. ~.~.. ::.~: .. )?! ~........, :: :. :. i~: ~':~.'.. . :.. ............. :;i'' .. !. t' ;'. :.':.; ~..: ...................................................... I.I~.TE, I~.:.OL~..T. ED V~LUE.'3. I:!'OF~ EVEN ! 00 .. EEE]:... OE.....SUB::F;Ei~. DEE'..TH __ TRUE SUB-SEA TOT'AL ........ .H...E...A.:'~!LJ.6.'.'E.._D .......... .v_..E.'.R.T....I b-:AL VE R_'. T...I.~.':.:.A.L-._ ......... RE C 'J'.A h!!:-:'~LIL A F~' C:C~O R l')I NA'i'E S MD-'FVD VER TI CAL ("' ...... , ....' ......... . ......... _ .................... .~.....~ ~ ...... ., _., .........~.~ ............. ~ _ ._ ;:- .... ,,~,~.,~...~ DEPTH DEPTH DEF'TH NuRT H/'.:;uLITH EA~;I'/WE';T Em I FFE'RENCE CORREC'¥ I ON · ' ' ' 'm m =m ::~':: ~ m, m': m: m~m::~ m'm'' mm ' ~[:~m' ' ~ m - : mm . ' . . = . ' =. ~: :~;.~..':.i;.iif:i:<:.:i.',~'~''= :.'" ;' .... ~ZZ..i ...... ' " .... ~ ' ...... '='- '- ...... ' .... 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INC .................. D:E; 12--23 (SEC: 18 T1C)N RI5E) F'RUDHOE BAY ........ AL/~$.KA ............ L--_;PERRY-:3UN WELL .'-_-;URVEYINfZ~ COMF'ANY :. -.. " :': ,:: . ...:. · ............................................... INIF,~.P, DLATED .VALUES .FOR EVEN . 100 F'EE:'T Cfi: .. SUB=SEA DEPTH ................................. ANCHORAOE ALASKA ................................... DATE OFT. SURVEY....MAY..,. '22'~_.1~.84_:~ ' ....... r::oMl'.':'l_r'rA'[ I i')N /IA~'E MAY "::~'~), 1'~):34 ~ ,JOB I~II_IMDER AtC-.BC~-..40045 ................................ i::iE LLY ..~.U~; L~.I I~.iG_ELE~, = OPERATOR-SELLERS .: .: · .. ,, _ ~ .~ ' TRUE .'.--;LIB- SEA TO TAL ...... ~E/~$,U. RED .......... .V.E~T I.C:iAL__~EF£1' I C:BL ......... RECYA~C';ULAI':;: . .C:OORD I NA'f'ES ........ I'.ID..:.: T.VD .................. V. 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Z~O.O, 00 . 74.5:3 S 705. ,'5:3 O0 ............... 77.13 S ........... 732.32 O0 79.63 S ' 75:.::':. 44 Of") 82.2/'.:, S 7':!33.4:3 OC) ........................... 8:'::....Z 1..'.i"-'; .............. ::"::0.4.58 00 82.6(") :""i; 819.70 () 0 7 '.-.?. 6 ..5 .:::,"" F".., ...,":' 1 . 1 C) 00 ............... 75..71. $ ............. 83'?...72 ANCHORAGE ALASKA ' ' e-. '~ "' .':.~ ...... : ~?,~: .. "L'Y:' '" ': · ARCO.. AL~SkLA, . ..I NC ................................................................ ................................... DA]:E . OE ..... ~.UR~E.Y_..EI/~Y.~ ....... £~1~4.,.~,. ........... ___. DS 12-23 (SEC 18 TION RISE) C:OHF'I_ITATION DA'~E F'RUDHOE BAY MAY 29, ~t784 " JO13 NUHBER ~K-DO-40045 F~ .............................................................................................. - . .. · '~" UFERATUR-~ELLER~ · ' .:.. . ~ ::.,. ~' · '~..' .] :.' L:~J.~:i~.;:::.:.~:~'~:~ ~.:'~ ' .... " .".. 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Z~.?.~ ..... ~. ....... 7..s..ZL, g.g,,.'"'.'.:'.i.."..:.,iz~.o_c,, oc:_~ .' .... . ....... · ',~'( ,'Fi'"', 7778 7671.00 7600.00 68' . ....':'"-"._. 7878 7771. ~'~0 7700, (]~('D 64, 72 S .... _,,,, ~;~ E 1 AT., 49 0.1 ._,':' 7978' 787 ! 00 78A0. AC 6 !. 45 ':' :'"::~/-,. 7/-, E. ! ('FF, 57 0, 08 . ~7:~.' ~."f'~. oo '?.~-a-~: i:,6 .... :,.,._....-.... s ~.7 F ~,:,7, 62 ' ,-,, o,-, ' . .... , .¢.. i..?.,.,.:"~':....~.'.; ................... . ~,:~, ,..'~,~~ ,-,f.-.,,'-, · ~78 e;)7~. 00" ". 8000.,:,0 .s~.. 7~ .._.:.'. e~o. c,/-. E~.,',7.~s '. 0.04... '"'' : .'"~::'.:"..;,:',li~l.?!,'". . . . .,.,,...'.,. :..~,....,.~i~i.!":'i · '" . '" . 0.7~.,~ ......... ' ............. ~;2.7,..8. ....... , ...... .G.'.LT.,!.~,.,Q.O, ..... :..~i,g.~,,,¢!,o, .... '"~'-":J 8271 00 8200 00 53 ,L."i~.~ / ,.; , · . · 8478 8:=:'71 · 00 83C)0.00 5 !. 8578 8471 · 00 8678 8571 · O0 8778 8671.00 8600.00 47. ............................ ~..8. 7 ..8. ................ ~.7. .. .7.. L,... .0 ~.;! ......... 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NO C:OMF'ANY · ~i~iOi~:::l. i AIqCI.'IOf=CAGE ALASKA " ".' ..:i~i':.~.'.' ..................................... DATE OF .. SURVEY. HAY..27., ..... !-P9.13~. ':.~ ..... CC~HF'UTA"I' I ON D~'E H~Y~....'="-?, 1'.-.:'.'_::4 '~' .IA}~ ...... NUHBER ........................................................................ KELL. Y...Bk~HlblG._EI_E.~, - 71 _ O0 -.'- ". ~; .5 ";~ ': .. ; ' · - ' : OPERA'I'OR-$ELLER:3 ?'> ' :.'. :. ............................. INTERPOLATED VALUES FOR SF'ECIAL :'.'i;UF~VEY.F'OINTS .... TRUE SUB-E;EA ......... P. IE~$URED. ............. .VER.T I.CI~L ...._V.E~T.I C~iL ...... F:EC]FI'-..~IqOUL~R DEPTH DEPTH DEF'TH NORTH/SOLrH-I T'OTAI... C:O01:~:I) I I'IA"I'ER ............ E A S; T / WE :3 T ............. 8899. ._8.7.~ 1 ,....,.4.~_13.7,'L ..~ ......... 46 '-~":' ':' 8?23 0:31 :""i. 24 8744 · 24 45. '?:3 ::::; 8~4.-- 88:34.24 8763, 24 45../:.2 '.i.:'.; ,-' ,.--,, -,-~-, .--, .~.~_ ( - ,~ .-,.", ,-.{-:/--,(I ,~,-,5...-..-.-, ,~7,-,1.....;, ~5.:::(''1. :'~i ,- ..~-...,..,....~.,..,w.,w4..,.,;,'~-..~.. ~..' ............ ~ ..... ;m,,"P--"l,~"~-,~,-I~l'.;~'~...·....w~,,w.~--W'-.{-.-I'~ .-~'...'"" · -. ......... ~..-~..~ ......... ~ . 89q7 8889, 23 881 '~ '~-'-' o· .'-.=, 44.60 .:_._, ''' 916'.~ ?~061.20 8'~?'~,?(). 2A.. 4, ...-'='. .... ';.'-' 1 '.E; .................. ?212 .......... :P.! 0..4...2.Q .................. '~0:33. :.JO, ............. 41.79, ,..~ c, .-, q:: ~ 9112.20 9041.2A 41 g 2A'-'/ 91 "" ol 20 ':~11(i 2A 41 lP :.::; · -- · · · · · .,.~ .865. 8/_',5. 865. :!365. 866. 866. :366. :=:/'.,'7. :!ii:/:,".?.'.. 868. ::-':': ./:, ~::. ..... ~1 i-. 36 E .............. 1 LIE.. oAL~... R I VEE~ .......................................... : _.:_~.~_ iii =;i. ,'.: .... : ........ 43 E l"l'_iP E;HLIBL ! I'::: A 4'.::.~ :: TI:IF' '.:~;HI_I[~i... I i::: Ii) .5:':i:.. '"' ..TOF: .. ~;HL!I:J~L Z I.':, ..C ......... - "~ ....... I ..... ' " ~': ' ::': ",'::.'.'"i:!: ?':'-'~ . -- ,.'"'i '::._, :: 'fOP L-.,FtDt..E:R _"_.H I 1 ...... '"..':.: .' ~: :.:, · . · 5.1 = t"lt'.) T : '.e}'". i..' ' ' ':' ' , 'i 90,: ...... OIL/WAT'ER. CQNTACT, ............................... ~ :;. ....... ~........~-: .......... '.:.?'7 iF: ]"Cfi::' Z(':flqE" 3 '? .t E'{ I"OF:' Z(3N[!E 2 · ..J~ ~ ..-~ :=:.4 .... ::2.. ' ....... '"' ................. ~, F ~ E .. DEF'T'H. ..... ."~ I:.:' =' , : , . ,. :, · .'...., _ F'L. Uf'iiBACK TD ' ": '~: v- '~ .., 'l" ..... ' "i.:..'"'. '"'":i'.. '. '. :iii:() = ]'(':l"l' Al.. DEl::' T'H [. R .[ I_l..El'x ·; ' . ! ,'1 .... . ..................... ,,! ......... , ...... . ........ .,,,. ..... ..,,.,,..,~.o.o ...... o.,, ,~.o~,....~1...~,,- .......... :-~:'---,.~..., .. (. ARF:O ALASKA, INC, . ...,: '...i"..'.'~. :-'.':..'.',,.~..": ' : s .;,."": i ...... ..~.~'.:. . ............................................................................. D.S .. 12:.-23 ..; ':(SEC; ..... 1.8....T.I.0N f".~ 1.:.~'q E.) ................. .......... ' ,:::": _:~::_.,_..,:,~::-:.~ '! ~?'.:'i.~:.:'/,.~L~-E_.-':.i .~.::~ ~.~_:_~:.,:,.. -, :=-;TRAT I ARAPH I C~. SUMMARY DERIVED LISlNG DIL DEF'THS AND"SPERRY L::UN SURVEY DATA MARI:JEF~ ....... 'MEASURED DEF'TI.I .................. TVD I"HICk;NEF;S WiTH REF, I ~'.~"'.~J~LLHEAD . .............................................................................. Bt:;JB. ................................... BI:::B ......... EiUB'.-.-SEA ..................... .V. EI~.I.I.C:~L, ....... .(..QF~I.G~N~~F_.S'~.'i.:.._ 700Fi~_L_ ) .... '.=;EF: 1:3 T 1ON R 15E .......... _T..O .P.._-,C'?~.G.'_ .,R. I_?_ER _~.' ~ ?..:' ........................ E: ~'.?. 1. TOP SHLIBL I I< A 8'.~2:3 ":":> ,:.: ...... 15,, TOP SHUBL I I< B 8942: °'='":'4 i.j,l..!."l · # ......... ..1.r, .p...F'._. SHL!BL. ! F:... ¢ ................ .2_~.~.& 0 .. ,:..~_o ~ .-, .............................. . ........ *-,'=* .~., .~ · TOP SADLEROCHI T 8997 '="="-'":~ ,'", ,_, ,=.', :. .,mm HOT 9169 "" '~' . ::, L ,.:, 1 01L/WATER CONTACT 9':-" 1:2 91 ~'~ 4 · ...... .... ." .-..-. ..................... s, 2. TOP ZONE 2 9289 '--'""'~' .'.' .I. ,:::, .I. ............ E'LUG.~.ACK...,:.IT.D .......... .. ................ ..,'... ..... .~.C~4 ................................................. . TOTAL DEPTH DRILLER 9:3,.'30 'F/2'72, . ..:.4 ........ _';:Z.-.:';J. 46~:32S 865.36F. (' ~. ~ ; ......... .__._,._~ ..~ ..... : _..: _ - . -. ';:4 :q744.24 '' 45. '.~'3S.' :"':'?--!i:-~5 .~'~._~¥': .... , : , 24 87,':,3, 24 45, 62S' .8&5~ 4¢E' ~ · --i,-m '. . ' # ~ .. . ' .,;. ,,'.' ...' . :. ' .i:." " ,~.=, .. :-~'Z81 .. '"" ....... ,~ ............................................................ ,,_: .... ,,~.~.,_~.~3_.~_',s:.,'~.~~ 2.3 :381.9.2:3 44. ~:.OS 8~5.55E . 20 89'F~0.20 42.21S 8&&. 51E 20 .......... :~;fi~!..~;~ . . . 4.1. 799 8~,~, ~0~ , '":' "l "~ ' ~" ' ,.,.. :. u4 ~. ~,., "" :-4 i ,"7 i S"::.'?:' ?.:~'~'~'~'~":'~'./TM · ,:.~ .' . .,~'.. ,. . . ,,~' ~ '~ t~2o 1. ~ :~ 40. ~:,4s 8~e. 80E ' ..... , .--:.-.~ · .. ,, I ) FROM LINEAR EXTRA.POLATION BELOW DE.E:.F' I=.'" 'T STA'TIFq:I ' . :. :.'.... ... ~:,.'.j....Q~..F'LIIER I::~ROG..R."~ :~.P..E.R..RY .,.~c~;.LI.N. :I'}tREE D I MENS I ON. AL RAD I US. OF C:LIR.VA.TLI~E, ............................. ,. .... ' '" :' ':i'~':';~""';'~:':'~ ' ...................................................................... ,.,:~:,~.:~_ L~.,.~=__.i~ ~.' .., '.,,, DA'I'A CALCUI_A'F I ON AND I N'T'ERF'OL. A'T'I CIN BY RAD I t.l'.3 OF CI...IF~VA'T'LIRE :[ "! ;' · :'"' : i' . , 0.00 2000.00 ~000.00 6000.00 10000.00m 'ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40045 Well ~ D.S. 12-23 (Sec 18 T10N R15E) Prudhoe Bay Field North Slope, Alaska Survey Date: May 27, 1984 Operator: Sellers Scale: 1" = 2000' 869.75' @ S 87° 19' E 20~0.00 VER T I CI::IL PROJE C T I ON TRUE NORTH Surface Location 289 FSL-700 FEL ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-B0-40045 Well ~ D.S. 12-23 (S~C 18 T10N R15E) Prudhoe Bay Field North Slope, Alaska Survey Date: May 27, 1984' Operator: Sellers Scale: 1" = 100' 869.?5' @ S 8?° i9' ~ ?0~ O0 BOO?O0. HORIZONTRL PR O.J E C T I QN Sug, fo rm to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. ' Operat6r, Wel- and Number Reports and Materials to be received by: ~~t~e Required Date Received Remarks · Ccmpletion Report Yes ~ ~_//._~_~ Well History Yes ~--/1--~ · .. .,u~ ,..o~ -'Pi ., Core Chips '' ,~//~ ~ ' 6/~ ' Core. Description A/~~' i1_ , ,, . · Inclination Survey .... 4:~ · Directional Survey y _p/ ~ , ...... '...,... ~F '-,,,~ . Drill Stun Test Reports ~/~~ --. · Prcddcti0n Test Reports STATE OF ALASKA ALASKA {r' "' AND GAS CONSERVATION C(~ .... /IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 8/+-58 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21105 i4. Location of Well 9. Unit or Lease Name 288' FSL, 701' FEL, Sec.18, T10N, R15E, UN Prudhoe Bay Uni~, at surface 5. Elevationinfeet(indicateKB, DF, etc.) 6. LeaseDesignationandSerialNo. 71' RKB, Pad ABL 28330 10. Well No. 12-23 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. May ,19 84 ;12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks , Spudded well ~ 1800 hfs, 05/07/8~. Drld 17-1/2" hole to 2500'. Ran, cmt,, & tstd 13-3/8" csg. Drld 12-1/~+' ho]e to 8906'. Ran, cmtd & tstd 9-518' csg. Drld 8-1/2' hole to 9380'. OH ]'ogs. Ran, cmtd & tstd 7" Int. Displaced to brine.. Ran CBL. Ran 5-1/2' completion assy. Secured we]~ & RE @ 2200 hfs, 05/1918~. Inject reserve pit fluids into 9-$18' x 13-3/8' annulus. Displace t,o diesel & set pkr on 05/21/8~. Arctic Packed 05/2~/8~. 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#1ft H-~0 weld conductor set ~ 80' Instld w/1925# Poleset 13-3/8" 72 0#/ft L-BO BTC csg w/FS @ 2~+75' CIP w/200.0 sx Perm "E"+~+00sxPerm "C" 9-5/8" ~7.0~/ft, L-80, 'BTC csg w/ES ~ 8895'. CIP w/500 sx Class "G" cm~ + 300 sx PF "C" Ca~. 7" 29.0~/f~, L-80, BTC csg f/9335~ - 860~~. ClP w/280 sx C3ass "G" cm~. 14. Coring resume and brief description 15. Logsrunanddepthwhererun DIL/BHCS/GR/SP f/9380' - 8895'. LDT/CNL/GR/Ca] f/9380' - 8895' (GR f/8895' - 2~76').. CBL f/9318' - 8500'. .16. DST data, perforating data, shows of H2S, miscellaneous data Nas~ 0it & 6as C0~S. l:;0mm~ss~0n 17. I hereby certify that the foreg~i~g is true and correct to the best of my knowledge. , SIGNED ~ ,- TITLE Area Dri 11 ing Engi neer DATE ~) _ . NOTE--Report on this form is required for each calendar month, regardless of the status of operatiOns, and must be filed in d[plicate with. the Alask~ Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 J NH/HR1 0 Submit in duplicate Rev. 7-1-80 .. DS 12-23 DRILLING HISTORY NU 20" diverter. Spudded well @ 1800 hrs, 05/07/84. Drld 17-1/2" hole to 2500' Ran 63 jts 13-3/8" 72#/ft, wo/nF,,S @ 2475'. Cmtd 13-3/8" csg w/2000 sxs P~rm "E" + 400 sxs Perm "C". ND-v diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok, Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8906'. Ran 221 jts 9-5/8" 47#, w/FS @ 8895' Cmtd 9-5/8" csg w/500 sxs Class "G" cmt. Tstd csg to 3000 psi - ok. Drid FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg MEW - ok. Drld 8-1/2" hole to 9380'TD. Ran DIL/BHCS/GR/SP f/9380' - 8895'; LDT/CNL/GR/Cal f/9380' - 8895' (GR f/8895' - 2476'). Ran 17 jts 7" 29#/ft. Cmtd 7" lnr w/280 sxs Class "G" cmt. Drld cmt to 9334'PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to brine & freshwater. Ran CBL f/9318' - 8500' Ran 5-1/2" completion assy w/tail @ 8635' & pkr @ 8561' & SSSV @ 220~' Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & ts~d to 5000 psi - ok. Secured well & released rig @ 2000 hrs, 05/19/84. Injected reserve pit fluids into 9-5/8" x 13-3/8". Leave diesel cap for freeze protection. Displace to diesel & set packer, 05/21/84. Arctic Packed 05/24/84 w/300 sx PF "C". JMM/DHIO'tw RECEIVED JUN 2 2 !964 ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June.14, 1984 Reference: ARCO Cased Hole Finals ~ D.S. 1-21 5-4-84 ~D.S. 1-25 5-26-84 ~D.S. 2-17 3-28-84 ~D.s. 3-13 5-21-84 ,~D. S. 3-27 5-18-84 ,~ D.So 4-1 5-6-84 ,~D.S. 4'4 5-14-84 /D.S. 5-8 ~-5-84 /D.S. 6-4 5-30-84 ~D.S. 7-20 4-18-84 ~,D.S. 12-16 5-20-84 ~'D. S. 9-4 5-7-84 ~D.S. 7-25 4-22-84 ~D.S. 7-22 4-20-84 ~D.S. 12-18 6-1-84 ,~D.S. 12-23 5-19-84 · .,~D. S. 14-2 5-3-84 ~D.S. 14-25 5-18-84 ~D.S. 14-32 5-20-84 ~,D.S. 14-34 6-5-84 ~,D.S. 17-1 5-24-84 Epilog Spinner Log Spinner Log/Basket Flowmeter CFS/Spinner ACBL/VDL/Signature/GR Epilog CH CNL Epilog CP1/TDT-M w/listing Spinner PLS Epilog Spinner Spinner CPL/TDT?M w/listing ACBL/VDL/Signature/GR Epilog CFS/Spinner CFS/Spinner C?L/TDT-M w/listing Collar/Perf Log ~ P~~lease sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Run 2 5" DA Run 1 5" Camco Run 2 5" Camco Run 1 5" GO Run 1 5" DA Run 2 5" DA Run 1 5" GO Run 1 5" DA 5" Sch Run 1 5" Camco Run 1 5" DA Run 1 5" DA Run 1 5" Camco Run 1 5" Camco 5" Sch Run 1 5" DA Run 3 5" DA Run 1 5" GO Run 1 5" GO 5" Sch Run 1 5" GO Kelly McFar land ATO-1429F Trans. # 242 D I STRIBUT ION ~hevron D & M Drilling Exp. Services Ext. Exploration Exxon C~tty Marathon Mobil Mobil E & P Ph£11£ps Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska. Inc.~ ~r' Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference: ARCO Magnetic Tapes ~,- D.S. 14-34j' 4-30-84 .~D.S. 9-23 - 3-4-84 ~ O 1 ~10 /. ~ O/. ~D.S. 12-18 ~" 4-22-84 ~.S. 12-23~' 6-7-84 ~D.S. 4-4 --' 6-11-84~ TDT Arrs~e~ ~*=n~n, ../~' · , ,.,.....,.,. w/ .iSLing TDT Lis #69200 w/listing OH #69242 w/listing TDT Answer ./~n,n/. / _'_~ ....... w I =.o,. ins TDT Lis #69193 w/listing OH #281794 w/listing CH/CNS ~281792 w/listing /q'-~'-'~.. ~of?-.-'~-c~J,- //psa-// :~ ' o ' ~ :~ lease sign and return the attached copy as receipt of data. .... I Sch--- Run 1 Sch Run 1 Sch .... 2 Sch Run 2 Sch GO Don't Forget Dad on his day! Kelly McFarland ATO-1429F Trans. # 230 DISTRIBUTION Chevron D & M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay.Well Files R & D Carolyn Smith Sohio .State of Alaska ., ARCO AlasKa, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 14, 1984 Reference: ARCO Open Hole Finals 1 D.S. 12-23 5-16-84 WEL / 5-16-84 BHCS f 5-16-84 DILL/ 5-16-84 CDL z 5-16-84 CDL/CNL 5-16-84 GRv~ 5" GO7 Run 1 2'Y& 5"/ Run 1 ~2" & '~5" Run 1 /~" & 5"~ Run 1 ~2" & 5";,.w- Run 1 5" .,.. '~~Please sign and return the attached copy as receipt of data. Don't Forget Dad on his day! Kelly McFarland ATO-1429F Trans. # 238 DISTRIBUTION Chevron D&H Drilling Exp. Services Ext. Exploration Exxon ·.Ne.fatima Alaska Oil & Gas Corm, Gommission Anchorage Mob i 1 Phillips Prudhoe Bay Well Files "P. & D Carolyn Smith ............ .,.', '. ..... h:,....~ .., /.......'4,. ' MEMOR/ NDUM TO: THRU: Sta e of Alaska ALASKA. OiL AND GAS CONSERVATION COMMISSION ~~erton.' /~ Lonnie C. Smith '"' Commissioner Douga~os ~ SUBJECT: FROM: Petroleum inspector DATE: May 17, 1984 FILE NO: D. 4 I. 18 TELEPHONE NO: Witness BOP Test on ARCO's DS 12-23 Well, Sec. 17, T10N,R15E,UM, Permit No. 84-58 at Parker Rig No. 176. Monday, May 7, 1984: I traveled-this date from Anchorage to PrudhOe t6"witne'ss" the BOP test on ARCO's DS 12-23 Well. Tuesday, ~ay .8~ 1984: The BOP test commenced at 5:00 pm and was 'concluded at '7:4~'-pm' One inside kill line valve failed, this" valve was repaired and retested before drilling out the casing shoe. I filled out an AOGCC BOP test report which' is attached. In summary, I witness.ed the BOP test on ARCO's DS 12-23 Well. Attachment 02-00IA(Rev. 10/79) O&G 3~ 4 4/80 i STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector /~,~ Date Wel 1 Operator ~~ Well .Z).S.. /Z'Z~ Location: Sec ~'% T 14~R Drilling Contractor t~r~~'''~ ~,~, Rig # /7~ Representative '~. ~u"\!W~O Permit # ~4- ~ /'~ ~/~asing Set @ Z~7~ ! ft. Representative ~ ~ ~/~ Location, General Well Sign General Housekeeping Reserve pit Rig ','BOPE Stack Annular Preventer .~'/~ Pipe Rams ~4''~t'P'''' "Z. Blind Rams w? ; . Choke .Line Val ve'JTM ~ ACCUMULATOR SYSTEM Full Charge Pressure %'~O psig · Pressure After Closure___~u~_~___psig 200 psig Above Precharge Attained: min ~ sec Full Charge Pressure Attained: ~ min I~-sec N2 ~.%~ ~9~-L~OI~.~06 ~sig ' ,,9,~( Controls: Master H.C.R..Valve ~ Kill Line Valves Check Valve' Test Pres sure Test Results: Failures t! Upper Kelly Lower Kelly Bal 1 Type I ns ide. BOP-- .. Remote .O~ Kelly and Floor Safety Valves / /Test Pressuru / ~'Test Pressure /~Test Pressure / ~Test Pressure 'Choke Manifold Blinds switch cove ! ~Test Pressure " No. Valves // Z$ No. flanges Adjustable ChOkes Hydrauically operated choke Test Time ~ hrs. II] Repair or Replacement of failed equipment to be made within ~ days a~d Inspector/Commission office .notified. ' ,...i ' Distribution orig.' - AO&GCC · cc - Operator cc - Supervisor Inspector April 18, 1984 Mr. T. L. Fi thian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 12-2.3 ARCO Alaska, Inc. Permit No. 84-58 Sur. Loc. 289'FSL, 700'FEL, Sec. 18, T10N, R15E, UM. Btmhole Loc. 191'FSL, 288'~.7L, Sec. 17, T10N, R15E, Dear Mr. Fithian: Enclosed is the approved application for permit to drill the above referenced well. .If coring is conducted, a One' cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(5)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title.5, Alaska Administrative Code). Prior to commencing operations you may ~e contacted by the Habitat CoordinatOr's Office, Departm~ent of Fish and Game. Pollution of any Waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control .Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. ' To aid' us in scheduling field work, please notify this office.24 hours prior to commencing installation of the blowout prevents_on Mr. T. L. Fi thi=,). Prudhoe Bay Unit DS 12-23 -2- April 18, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Chairman of aY ORDER OF THE COMMISSION Alaska Oil and Gas Conse~ation Co~sston be Enclosure cc= Department of Fish & Game, Habitat Section w/o encl. Department o,f Environmental Conservation w/o encl. ARCO Alaska, Inc. i Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 9, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-23 Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 12-23 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; proximity plats showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on May 10, 1984, your earliest approval will be appreciated.. If you have any questions, please call me at 263-4610. Sincere, T. L. Fithian Area Drilling Engineer TFL/JG:tw GRU6/L87 Enclosures APR 1 2198~ Alaska Oil & Sas Cons. AnChorage C°rnrnissiorl ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · A{r,~, STATE OF ALASKA L ALASK ~L AND GAS CONSERVATION C ,,~MISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X lb. Type of well EXPLORATORY I--I SERVICE F-]XX STRATIGRAPHIC I-1 REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [~XX Injection We11 DEEPEN '1-) DEVELOPMENT GAS[] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc.~c3 3. Address {2° P. 0. Box 100360, Anchorage, Alaska 99510 .~.~ ~C) 4. Location of well at surface ............. 9. Unit or lease name ~ 289' FSL, 700' FEL, Sec.18, T10N, R15E, UM Prudhoe Bay Unit .~ At top of proposed producing interval 10. Well number ~ 198' FSL, 216' FWL, Sec.17, T10N, R15E, UM 12-23 At total depth 11. Field and pool 191' FSL, 288' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe Bay 0i 1 Pool RKB 71'I ADL 28330 12. Bond information (see ~0 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 131 Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 1 mi. NE of Deadhorse miles 4580 feet 12-1Z~vell 197' (~ 4000'TVD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. ApProximate spud date 9349' MD, 9253'TVD feet 2560 05/10/84 19. If deviated {see 20 AAC 25.050) 120. Anticipated pressures 3142 psig.~.~~Surface KICK OFF POINT 4000 feet. MAXIMUM HOLE ANGLE 11 oI (see 20 AAC 25.035 (c) (2) 4068 psig@ c~2_~A ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole CaSing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30" 20" 91.5# H-40 We1( 8C 30' I 30' 1101 110' 2000# Poleset 17-1/2" 13-3/8" 72.0# L-80 BUT~ 2470 30' 30' 25001 2500' 2300sx CSIII & ~O0sx CS I 12-1/4" 9-5/8" 47.0# L-80 BUT; 8843 29' I 29' 8872]. 8785' 500sx Class G & 9-5/8 x 13-3/8" .~rctic Pm:k I I 300 sx CS I , 8-1/2" 7" 29.0# L-80 BUT~ 677 8672' ~ 8589' 93491 9253~ 400 sx Class . 22. Describe proposed program: ARCO Alaska, Inc., proposes to directionally drill this well to 9349'MD (9253' TVD) to inject into the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#~ L-80 tubing and packer will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud. DS 12-23 will be 197' away"from DS 12-14 @ approximately 4000'TVD. There are no other wellbores closer than 200' anywhere along the proposed well course. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption of the disposal process (i.e., rig move or shutdown of disposal process for an - . extended peri od,,of ti me . . SIGNED TITLE Area Drilling Engineer DATE The space below for Commission use CONDITIONS OF APPROVAL ,. Samples required Mud log required Directional Survey required APl number I']YES[~O I--] YES [~NO ~ES J-]NO 50- 0 - Permit number Approval date ~.C~g ,-" ~ 0/_+/18j~8~l SEECOVER LETTER FOROTHER REQUIREMENTS APPROVEDBY OMMISSIONER DATE April, 18, 1984 ~ .jr . ~ ~.~~/'~/~J by order of the Commission Form 10-401 GRU6/PD29 Submit i n triplicate Rev. 7-1-80 1000 2000 3000 4000 5000 6000 7000 8000 900O 10000 D812-( 1 VF'.RTICRL SECT 0 1000 2000 3000 4000 5000 8000 tCASING ' ARCO Ai.A~.,~~.9 jl~C.SI-IL: T10N289'FSL', KISE700'FF-'L', tN Sec 18, TI-I~: 200'FSL, 200'~/'L, Sec 17, _ TION, RiSE, UM ~ 18-818' CABING TVD -- 2800 , -.. 7.5 .... .. EOC ~Dm4~ MDm4447 DEiSm48 · ,,, , YO T AR~ET) ., .. ,, K-lO T~rD m 7~51 MD ' ;20e DEP m 578 . ,.,,, ~ ~,, ~G RIVER TVO m ~78G MD -- 8672 OEP m 001 ~/8' CASING T~'D -87B5 MD - 1872 OEP -001 T ~ReET TVD ~81~00 MD ~ ~8~7 [~EP -004 ~ 3P 8ADLEROCHI'~ TVD - 8881 MI) - 8870 OEP -- 120 J/W CONTACT TVO -- 0100 MD - 0100 OEP -- ' rD TVD - 0253 AID -- 8348 DEP - 883 ' ~ BASE SADLEAOC~,HIT ~O -- 0403 MD --958~ OEP -- 1035 , , ,, 7O0O 0 10 201 301 401 50( 80( 70C 800 900 100, ( (" 'DS 12-23 E~ - ~ COOROINBTF:S Z -~000 -2000 ' ~ -~000 0 ,~ ~000 2000 ~000 ._t_l._I ARCO ~,LA$1~ A, INC. , · SHL' 289'FSL, 700'F~L, Sec 18, T10N, R15E, IlVl THL' 200'FSL, 200'F~, Sec 17, TION, R1SE, UM · 4444 .. ,,._ ~800 -. 2-2 · T.&R(~ .... TVD - 8800' lVlD - 8887' ...... DEp - 904, ......... · South- 89' East - 900' i ii i i i i i i i i , ' RE~E~¥F!D - APR 1 2 191~4 Anchorage ! i i ! i i i i ! i i i i i ! i i ! i i i i i ! ! i i ! ! i i i i i i i i i ! i i i ! i i I i i i ! i i i i ! ! ! i I i i i -3000 -2000 - 1000 0 1000 2000 3000 E - IA COORDINATES 4000 I '. Z I DS 12-23 E - N COOROINRTES -100 0 100 200 300 '~00 500 · i~ i i i i i i i i I I I I i I i i ! i i ! I I I I I I I i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i I I IN( · ' $~,,ALE 11. - ~ ~. 444'4 ~01 ' ' ~ 728 - ~,P ':'/'"'~ ~ ' 12-2 3 iii i i i i . ,.~ .,. ' '-' ~PR 1 2198~ Naska ( il & Gas COns'. ~' amission' ~, : . . . . . - 1 O0 0 1 O0 .200 300 {00 500 600 E - ~ CO08DISflT~5 600 DS 12-23 -3000 -2000 Q~ 0 Z F.. - N COORDINATES - 1000 0 ! 000 2000 3000 4000 __ I I I I ! i i ! I I i I I i i i i i i i i i ! i i i I I I | I I I I I ~. 4444 ,.,,,-.-_1_%~...D3 12-2: 8800~ 171 ' · ~~3727 7424 ~qPR 1 :? 1984 i i i i i i i i i i i i I i i i i i i i i i i i I i i i i i i i i i -3000 -2000 - 1000 ' O 1000 2000 3000 400( E - N COORBINF~TES DS 12-23 o -3000 -2000 Z CD E - W O00RBINB~ES - 1000 0 1000 2000 3000 4000 -3000 -2000 - 1000 0 ! 000 2000 3000 ~[000 E - H COORBINflTES DS 12-23 -3000 -2000 W' Z E - ~ COORDINRTES -1000 0 1000 2000 3000 ~000 i i i ! i ! I I ! i i i I I I I I I I I I I i i I I I I i i i i I i I · ALAS(A, IN, -~i .... 1~.1~71 1 ~ , 4/:,c.,~.,.?~. Cot ..... ',ago I · i i i i i i i i i i i i i i i i i i i , i i i i i , i i i , i i I i i i i i i i I i . -3000 -2000 - 1000 0 1000 2000 3000 '~000 E - N O00RDINBTES DS 12-23 o -3000 0 W CC) R. - N O00RDINR~FS -2000 - 1000 0 1000 2000 3000 Z ~000 // CO ALASKa, INC. 4444 ,'"~ DS 12-2 3 ,,~097 . i , i i I i i i i i i i i i [ i i i i i i I i i I i i i [ i I i i i , i i i i i , i i i i [ i i i [ i i i i i [ i i i i -3000 -2000 -1000 0 1000 2000 3000 4000 E - N OOOROINBTES o -3000 W n/ 0 CJ C~ I Z D S 12-23 i"' P.. - N O00RD I NRTES -2000 - 1000 0 1000 :2000 3000 4000 i i i i i i i i ! ! i i I I I I I I I ! i I i i i i i i ! i I I I ! I I I I I I I I I I I i I ! i ! ! i ! I~ l CCi ALASK ~, INC / 4444,., · ~ ~88O0 2_2 3 ' .-'~148 '755 ~ 12-8B i iiiii i i ", " '~'.~hO.a~.e Coo, · 1 ! i i i i i i i i i i i i i i i i i i i i , i i i i i i i i i i i i i I i i i i i v i i i i i i i i i i -3000 -2000 - 1000 0 1000 2000 3000 4000 g - N COORDINRTP. S RNNUL.qR PREVENTOR PIPE RRHS BLIND RRH$ SPOOL PIPE RRM$ 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accmmlator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-$/8" BOP Stack Test 1. Fill BOP stack and .manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predetermined plug sea.~ing depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. 6. -In each of the following tests, first hold a 250 psi low pressure test for a m~ of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 5 minutes. Bleed pressure to zero. 7. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 5 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokea. Increase pressure to 5000 psi and hpld for at least 5 minutes. Bleed pressure to zero. 9. Open top set o£ pipe rams then close bottom set of pipe rsms. Incresse pressure to 5000 psi below the bottom set o£ pipe rams and hold for at least 5 re. in- utes. 10. Test reamining untested manifold valves (if any) wit. h 5000 psi upstream, of valve and zero pressure downstream. 11. Bleed pressure to zero. Open bottom set of pipe r~ms. 12. Back off running joint and pull out o£ hole. Close blind rams and test to 5000 psi for at least 5 minutes. 13. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. 14. Test standpipe valves to 5000 psi. 15. Test Kelly cocks and inside BOP to 5000 psi' with Koomey pump. 16. Check operation of Degass~r. 17. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. 18. Perform complete BOP~ test once a week and func- tionally operate BOPS. daily. APR 1 21984 Alaska Oil & Gas Corm, CommJssfon Revised 2/21/84 SURFACE HOLE DIVERTER SYSTEM ARCO ALASKA INC'. SCHEMATTC ~ IO" HYD. OPR. BALL VALVE ;WELL BORE (SEE DETAIL) /~-- I0" HYD. {)PR. BALL VALVE )ALL 90' TURNS ARE "TEE" IcUSHION I 1NELL BORE _1 RESERVE PIT AREA NOTE- FLOWL INE F DR ILL ING R I SER L 20" 2000 PSI WP ANNULAR PREVENTOR I I /,,.~~-.--"r--~ I O" HYDRAULIC OPERATED BALL VALVES Valves on diverter lines open automati- 20" cally when the annular co~ouc-ro~ "DFIAIL" preventer is closed. PIPE 2026OIO20 ARCO Alaska, Inc. {' Post Office~,.,,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 19, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Wells 22 & 23 Dear Elaine: Enclosed is an as-built location plat for If you have any questions, please call me Sincerely, Plat - DS'I2 the subject wells. at 263-4944. Gruber Associate Engineer GRU5/L133:tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 22. 113 YV'~Z z. '~ ZZ Y · .5'930 GO/. ~$ K: G 96 .q/d/.. /.AT: '70 / Z, SZ. zO/,/6: /4.8'z+'~1, 9 g Z " oaru~4 (~LL W) I HEREBY CERTIFY THAT I HAVE MADE A SURVEY OF THE ABOVE DESRIBED PROPERTY AND THAT 'THE IMPROVEMENTS SITUATED THEREON ARE WITHIN THE BOUNDARIES OF SAID TRACT AND DO NOT OVERLAP OR ENCROACH ON THE PROPERTY LYING ADJACENT THERETO. EXCEPT AS INDICATED HEREON. MONUMENTATION REPRESENTING BOUNDARY CONTROL BY PLAT 18 SI-K)WN IN DETAIL AND IS ACCURATE TO THE BEST OF MY KNOWLEGE. . ,, OES. W. 5. CHK. i'~;~;-o.'--/-.,,~ ......... 61-~~' '/'""" ' A RCoD'S/ Alas: <'a u, Inc. -',,.,.,, '"'~'-o,~ ' - Sub~.;dlory of ,~tlon~ic Richfield ¢;mpony j~ NC, ATH SLOPE DRILLING-PRUDHOE BAY CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. / ITEM APPROVE DATE (2) Lo_._~c thru 8) Admzn ~ (3) · v (10 and ll) (4) Casg ~ ,z-/-../,2.-..~¢ (12 thru 20)- (21 thru 24) 1. Is the permit fee attached ............................... 3. Is well located proper distance from property line 5. Is sufficient undedicated acreage available in this pool .... 6. Is well to be deviated and is well bore plat included ....... 7. Is operator the only affected party ......................... 8. Can permit be approved before ten-day wait .................. 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES Does operator have a bond in force .................................. .~"k... Is a conservation order needed ...................................... Is administrative approval needed ................................... NO REMARKS Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ............... Will all casing give adequate safety in collapse' and Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... '~/~f~ Does ROPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78)...' .............. Additional requirements ............................................. ~0 Additional Remarks: d~a~xT/~F/~Rz~/~_~ IS lYT' Tz~ la-~z~ ~ /-/,~rz, / . Geology: Engineering: HWK ~ LCS ~ BEW '~- aA,. rev: 12/08/83 6. CKLT INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS ARE~. NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. CompmnM ARCO ALASKA INC. Well DS 12-23 Fimld PRUDHOE 8AY County NORTH SLOPE Statm ALASKA Coon'try USA CLIENT FORMA'T DATA TAPE LOG INFORMATION :_~ T A N DARD FORMAT ( L . I , S , ) (de.._.'~ _'1 ,.,_,'.,~r., : ~RCO 12-23 D--'_pths-'. ,:..~._,: 00 to 93~2 ~"" Nam~; DS 'i .':""-'2..::q Fi ~ld: PRUDHCE BAY [.',ate..: 7 ,JUNE., _ 1984. Tim~: !1:25 AH THU, Pag,:-": 1 L, I, S, TAPE RECORDS ~** REEL HEADER Servi,:¢ name: &GSF01 Pr~_'0.,' i'-Duz tee I: HEADER Data: 84/0G/07 Origin: Commentz: RECORD'-" , Reel name: 28i794 Pag~ Continuation ~: Oi ~** TAPE HEADER **** Servi,-e name: &G.SFO1 Previous tape: 84/06/07 Origin: Comment~: Tape name: 281794 Continuation #: EOF ~:~.:~ FiLE HEADER *-~*~: Film n.~mm: &GSF01 ,001 HEADER RECORDS Maximum imngt, h: 10'24 Film type: LO Vmr.~ion #: Prmviou~ file: Datm: P~g~ M N E M CN WN FN COUN STAT CTRY SECT TOWN RANG EKB EDF EGL PD LblF DHF RUN LCC LUN FL LUL EN6I WiTN ~L TLI TCS TLA8 BHT MRT ~T MVIS RM RMF MFST MFSS RMO MOST MOSS COHTENTS ARCO ALASKA DS 12-23 PRUDHOE 8AY NORTH SLOPE ALASKA USA 1 ON .... 15E' .... 71 OOO 70 000 , 41 000 SL K8 .... 30 28 794 76 i NORTH SLOPE NOETH SLOPE HIJPP MC CULLOUGH 9380, OOO, . . 9380,000.,, 8894,000,, , 9376. 000,., 930,000 1350,000,., i90,000 .... 190,008 .... L I GNOS FLOWLINE 33,000 ...... 2,430 ....... 2,i60 ....... 65,300 ...... MEAS, '2,600 ....... 65. 000 MEAS, t NC. IIIlI lIIlI INFORMA i TION RECORDS UNIT I i i I ! i i i · i i i i · i , i i i I : a i I I i I I i i I i I I i i i i I i I i I i I I i I I I I I I i I I I I i i · i i i i I I I I i I i i I TYPE C A TG OlZE CODE .... 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 '2 65 0 0 .S "'5 0 0 .3 65 FT 0 .7. 4. 68 FT O 3 4 68 FT O .~ 4 0 3 2 65 0 3 2 65 0 3 ':; 65 0 0 2 79 0 0 2 0 0 i0 65 0 0 i O 6,5 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 ,SS FT 0 ~ 4 68 FT 0 .~ 4 68 FT 0 3 4 E. 8 FT O 3 4 68 HR O 2 4 68 HR 0 4 4 68 DEC, F 0 i 4 68 DEGF' 0 i 4 6.8 0 2 20 65 0 2 20 65 CP 0 2 4 68 OHHi'i 0 2 ,4 68 OHMH O 2 4 68 DEGF' 0 2 4 68 0 2 12 6,5 OHHM O 2 4 68 DEGF' O 2 4 68 0 2 i2 65 Pmg~_ COMMENT RECORDS mm This LIS tape was written by Gmarhart Industrims Wireline Smrvice~, mm All curve and tool mnemonics u~ed are those which mo~t closely match · m Gearhart curve and tool mnemonics. GEARHART TO SCHLUMBERQER MNEH SERVICE UNIT MNEM ~ERVICE UNIT I--I IliI --lli DEPTH FEET DEPT FT TEN DIL?BCS NV 'FENS DILBCS MV GR DIL/BCS GAPI GR OlLBC$ GAPI ILD DIL/BCS ILM DIL/8CS OHMM ILM DILBCS OHMM [.L~ DIL?BO$ OHMM LLSU DiLBC~ DELT DIL?BC$ AMPS DIL/BCS MV AMPL DILBCS CILD DIL?BC$ MMHO OILD DILBCS MMHO Page DATA ENTRY BLOCKS .~ :+:.,m ENTRY FORMA T SPEC I F I CA T IONS TYPE SIZE CO[:,E 0 1 66 Page ENTRY BLOCK LEGEN[:, m~:.** TYPE DESCRIPTION 0 Tmrminator ( no morm mntries ) D TA FORMAT SPEC I F Ii ONS ~m~ DAzUH SPECIFIr'AZi":N... .-o 8LOCKS *m.m MNEi'I SERVICE SERVICE APl AP1 AP1 AP1 FILE iD ORDER e UNIT LOG TYPE CLASS MOD ~ DEPT 281794 FT O 0 0 0 0 TENS DILB~.~ 281794 HV 0 0 0 0 0 SP DiLBCS 28i79,¢ HV 0 1 0 0 0 Q~ DILB¢~ '~°17~4. CAPi 0 ~1 n 0 iLO DiLSCS 28~794 OHHH 0 i~ 46 0 0 ILH DILSCS 281794 OHHH O 12 44 0 0 LLSU DiLSCS 28i794 OHHH 0 22 8 0 0 DT DiLBC~ 281794 US?F 0 52 32 0 0 AHPL DiLBCS 281794 NV 0 57 ~ 0 0 CILD DILSCS 28i?~4 HHHO 0 68 46 0 0 PRC SIZE LVL SHPL RC 4 0 i 68 4. 0 i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 6,8 4 0 i 68 4 0 i 68 4 O ~ 68 PROCESS iNDiCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 P.~,g m DEPT AMPL TENS CILD SP DA GR TA RECORD ILD iLM LL8U DT 9390. 000 0,000 9290,000 292.800 9i90.000 286,300 9090.000 270.000 8990,000 272.500 8890,000 266,600 0,000 !000,000 3308.000 592.925 3274.000 201,837 3240,000 57,412 3206,000 43,152 3181,000 21 31 46 79 14.6 000 500 800 100 3OO 000 0.000 15.000 16.100 29,400 90,000 56.300 1 ,000 1 ,687 4,955 i7,418 23,174 63,973 1 ,982 5.808 1 4,355 27.861 i ,000 5,458 8,730 14,757 33.884 ,601 0,000 87,500 94,i00 93.300 82,600 74,600 ~-mm FILE TRAILER File name: &GSF01.001 Ma×imum lmngth: 1024 TRAILER RECORDS Vmrsion ~: Fil~ 'typ$: LO Nmxt ~ile: Datm: Pag~ ~'.' EOF .'.~.:,.,i.'. FILE HEADER File name: &GSFOi.002 ~a×imum l~nq~h: 102~ HEADER RECORDS V~rsion ~: Film tppm: LO im Previous ~ile: Datm: Page 10 M H E M CN WN FN COUH STAT CTRY SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN ' LCC SON LUN FL LUL ENGI WiTN DD DL TLI TC.S TLAB BHT MRT MT MSS MVIS ~H HF~T MFSS ' RMC MCST MCSS CONTEl'iTS ARCO ALASKA DS i 2-23 PRUDHOE BAY NORTH SLOPE ALASKA USA iON .... i5E, , , 71 ,000 70,000 4i ,000 KB .... 281794 76i i NORTH SLOPE NORTH SLOPE HUPP tic C 9380 9380 889.4 9376 930, t350 190, ULi. OUCH ,000 ,000 . ,000 ,000 , 000, . ,000 . 000, , 190,000, , LIGNOS FLOWLINE 33; 000 ...... 2,430 ....... 2,160 ....... 65,300 ...... MEAS, 2,600 ....... 65,000 ...... MEAS, I NC, t I I .I ! I : I I ! ¢ 1 I NFORMA IJIlJIIIlIIIII |lllllllliIiii , i : : t i I I i i : TION RECORDS U I'.! I T TYPE CATG SIZE CiD DE 0 O 4 Fi 65 O O 40 65 O O 4 O 65 0 0 20 65 0 O 20 65 0 0 20 65 O O 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 'FT O :g 4 68 FT 0 .3 4 0 3 2 65 0 .3 2 65 0 3 2 65 0 O 2 79 0 0 2 7'9 0 O 10 65 0 O i O 65 0 0 20 65 0 0 20 65 0 O 20 65 0 0 ~.° 0 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 i 4 68 DEGF 0 i 4 68 0 2 20 65 0 2 20 65 CP 0 2 4 68 OHMH 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 'i 2 65 OHMN 0 2 4 68 DEGF' 0 2 4 68 0 2 t2 65 P.ag ¢_ 11 COMMENT RECORDS This LIS tapm was written by Gmarhmrt Industrims Wirmiinm Smrvicms, Ali curve and tool mn~moni,zs u~d mr~ t. ho~m which most clo~mly match G~arhart curve and %~ol mnemonics. GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT CNDOI C:DL/CNS f~ DnL NPHI FDCCNL PU TEN t CDL?CNS MV TENS FDCCNL MY GR i CDL/CNS ~]AP I GR FDCCNL GAP I ,,,,..AL l ~DL/bN~ IN ~ALI FD~NL IN YCAL1 CDL?CN8 IN ~AL~ FDC~NL IN FCDL1 CDL/~]NS CPS FFDL FDCCNL CPS NCDL1 CDL./CHS CPS NFDC' FDCCN:L CPS RHOB1 CDL/CHS G/C~ RHOB FDCONL G/CJ DRHO 1 ODL?CNS G/C~ DRHO FDC0NL. ' n~,.~S-~_..., bN..,1 CDL~ ~,~ :~. L.~H~ NPH~ FDCONL PU F.~N~ i CDL/ChIS OPS FCNL FDCONL OP~ N ~.N~ 1 CDL/ONS OPS NCHL FDCOHL CPS ~N~:~l CDL/CN~ ~ S~ND NPHZ FDCONL PU CDL1 coMPUTED DPHZ Page_ 12 DATA ENTRY FORMA T SPEC i F i CA TYPE SIZE CODE 0 1 66 T i ON'-'o P.ag m ~:** ENTRY BLOCK LEGEND **** !': :+: * ~: ~ .,~ * :+: :+: :'i': :+.' .'+: :i': * :~ :'1': :+: ~ :+: :~ -'l': :+: ~ ~ .'i': :~ :+: .'+: :~ TYPE DESCRIPTION 0 Tmcminator ( no more mn'tries ) FORMRT ~.~* DATUM ~PECiFiCATION 8LOCKS ~ SERVICE SERVICE MNEH ID ORDER # APl AP1 APl APl FiLE UNIT LOG TYPE CLASc' MOD ~ DEPT 28i794 NPHi FDCCNL 28i794 TENS FDCCNL 281794 GR FDCCNL 281794 CALl FDCCNL 281794 CAL2 FDCCNL 281794 FFDL FBCCNL 28i794 NFDC FDCONL 281794 RH08 FDCCNL 281794 DRHO FDCCNL 281794 NPNI FDCCNL 28i794, FCNL FDCCNL 281794, NCNL FDCCNL 28i794, NPHi FDCCNL 281794 DPNI 281794 FT 0 0 0 0 0 PU 42 68 i O MV 42 0 O 0 i GAPi 42 3i 0 0 IN 42 28 0 0 i iN 42 0 O O CPS 42 O 0 O i CPS 4,2 0 0 0 i ~7C3 42 35 i 0 i ~703 42 PO 42 68 2 0 i CPS 42 0 0 0 CPS 42 O O 0 i PU 42 68 3 O 0 O O 0 i SPECIFICATIONS PRC ClZE LVL SMPL RC 4, 0 i 68 4, O i 68 4 O i 68 4 0 ~ 68 4 0 i 68 4 0 1 68 4 0 i 68 4, 0 I 68 4 O i 68 4 0 1 68 4 O i 68 4 0 i 68 4 0 i 68 4, 0 1 68 4 0 i 68 M N UL: b. ~ :-_; INDICATORS mi 000000 000000 OOOO00 OOOO00 000000 000000 O00OO0 000000 000000 · ..'"'V fi. i':...," 0 n 00 ~j 00.. ' 0 n ,', 000...... . . i) i'lt'.lOI.'li'l 000000 O00FlO0 O000OO O000OO O000OO 000000 OOOO00 000000 O00001j 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 O000OO O000OO OOOOOO 000000 000000 OOO000 000000 000000 000000 000000 14 DEPT RHOB NPHI DRHO TENS NPHi DA GR F C N L TA RECORDS CALl N C: N L CAL2 NPH ~ FFDL DPHi [',IF DC - · 1 5 9392. 000 i , 856 'B;--_'...:"B2,000 2,245 9i 92, 000 ":',. , 288 9092,000 270 8992,000 '" 545 88'92,000 2, 029 -'i , 663 , .z, V2 19,504. ,038 18,050 ,046 'i9,967 ,015 54,497 -1,088 · 3.000 0,000 -1.000 -j 9, 000 · -2, 000 21 , 050 i ,000 6.000 5;2,4~ 0 0.000 II, 0 "" 0 18,900 347, i O0 i 6,300 27, 100 362,200 9i ,lO0 745,800 62,800 92,200 0,000 0,000 8,810 · _'355,300 9, 080 349,200 8,690 .'3_.60,600 8,940 348,1 O0 8,6,80 i46, OOO 0,000 4,000 :3,95 0 26. 500 9,200 29, 000 8,810 25.05 0 8,990 26,960 8.700 56,4-50 i33,000 48,i2! 4.66,600 24,545 · .752, .3 0 0 2i 473,500 2.'3;070 274,000 6, .7,64 i04, iO0 37,636 81 .100 50:'5, 1 O0 45 :S, 'B 00 515, .30 0 4.~i ,800 89,800 name: &GSF01,002 .-- Ma×imum lmngth: !0~4 TRAILER RECORD'~'~ Version File ty, pm: LO Nmxt ¢i 1~: 16, ~': EOF' ~:~ -:*:~ FiLE HEADER -+-.~.+--+. File nam,i: ~,GSFOl.OO3 Maximum Imngth: HEADER RECORD" ._~ Fil~ tpp~: LO V~r.~ion Q: Pr~viou~ ?il~: Page 17 I NFORMA TION RECORD¢',., M N E M C 0 N T E N T ~ UNIT TYPE. CATG ._.~-IZE p -, r,.~-_ ,_, ,: ,- CH WN FN '",-. 0 !J N · _, tAT '" T R Y ,ECT T n W H RANG EKB EDF EGI._ F'D LMF DMF RUN LCC SON LUN FL LUL ENGI WiTN DD DL TLI BLI TCS TLA8 8HT HRT MT MSS. HVIS RH RMF HFST HFSS RHC HCST HCSS ARCO ALASKA DS i 2-2~ PRUDHOE BAY NORTH SLOPE ALASKA USA 1ON i5E ..... 7i ,000, , 70,000, , 41 ,000, SL ...... KB ...... ,SU ...... 2817'94 , 76~ i NORTH SLOP~ NORTH SLOPE H U P P HC CULLOUGH 9"R , , ~,~0 000 9380, 000, 8894,0 O 0, 9376, 000, 930, 000, , i350,000, 190, 000 .... I90, 000, , LIGNOS FLOULiNE 33,000 ...... 2,430 ....... 2, i60 ....... 65,300 ...... 2,600 ....... 65,000 ...... MEAS, i NC, i iI ii |i ii Ii I iI |I ii :| ]I , ~i ii Ii ii Ii , I I i i i : I i i I i I I I i i I i I i i i i I ., I i I I l i i i i i i i , 0 0 4 n 65 0 0 40 65 u 0 40 65 0 0 20 65 0 0 '~0 65 0 0 '20 6:... 0 0 2 65 0 ~3 3 6 = 0 0 3 65 FT 0 ..7 4 6,9 FT 0 3 4 68 FT 0 .7 4 ~8 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 1 0 65 0 0 iO 65 0 0 20 65 0 0 20 65 0 0 2 0 ,55 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 6:9 HR 0 2 4 68 HR 0 '4 4 68 DEGF 0 1' 4 68 DEi]F O i 4 68 0 2 20 65 , O 2 20 65 CP 0 2 4 68 OHHH 0 2 4 68 OHMH O. 2 4 68 DE6F 0 2 4 68 0 2 ~2 65 OHHH 0 2 4 68 DEt]F 0 2 4 68 0 2 12 65 COMMENT RECORDS :~:+: This LIS tape ,.~a:s v.~rit'b~_n bi.' Ge._~rhmrt Industries Wire!in¢ S~rvicm~, · m All curve and tool mnm~oni,-~ u~md arm t. ho~m which most closmlp match mm Gearhart curve and tool mnemonics. GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT Im DEPTH FEET TEH2 CDL?CNS MV ..,R,-- CDL?CNS GAPI MNEf4 SERVICE UNIT DEPT FT TENS FDCCNL MV GR FDCCNL GAPI P.ag e 19 DATA EN TRY FORMA TYPE T.~,°PEC I F I CA 0 1 66 TIONS 2 0 ,~,~,$ ENTRY BLOCK LEGEND mm** ,~: :~. :;~. :~: :~; :~c .~: .~ .~ ~.. ~..~..~ .~..~ .~: .~ :.~: .to 8: ~. :~: .~ 8: :~- :~: .~. -~. TYPE DESCRIPTION 0 Tmrminmt, or < r;o mor. a mnt.~-i~s ) DATA FORMAT DATUM SPECiFiCATiON 8LOr~KS SERVICE SERVICE APl AP1 AP1 APl FILE i"INEM iD ORDER ~ UNiT LOG TYPE CLASS MOb # DEP'F 281794 FT 0 0 0 0 0 TEHS FDCCNL 28i794 NV 42 0 0 0 2 ~.~i;: F[.:,CCNL ~8 i 794. GAF' i "~' ~ 4,-= 3i O 0 2 · =,PEC I F I CAT IONS PRC SiZE LVL SMPL RC 4 0 i 68 4 0 i 68 4 0 i 68 PROC:ESS iNDiL.~:IuR...,c' O00FiO0 000000 000000 OOOAOn 000000 000000 000000 000000 000000 21 OEPT TE NS C, A TA RECORDS °889.000 i 7' h "" "" ~ ...... ~,000 i 000 5.3,i00 8689,000 2 000 o~. oc~ 000 I..m ..) ~.., . I 0 000 ,4.7,300 8489,000 -1 000 8389.000 -1 000 77 900 R.~oo dO0 -! 000 59 400 -1 000 78 500 8089 000 -t 000 43 200 7989 7889 000 00'0 0 000 0 000 4'i 900 900 7789 000 -1 000 48 000 7689 000 -.3,000 41 900 ,' ~,z,~ 000 -2,000 45 700 7489 000 I ,000 42 700 7389 000 -~ 000 40 200 7289 000 2,000 45 'BOO 7189 000 2,000 72 200 DEPT 7089 .- 000 6:389,000 6689 000 6589 000 6489 000 6389 000 6289 000 6189 000 60:39. 000 5989,000 5789,000 5589,000 ~4.89,000 5389,000 T E N '.3 GR I ,000 400 -2,000 47 700 -2, 000 48 800 0,000 32 900 -~,000 34. 200 -2,000 36 000 I, 000 37 400 1 .000 0,000 27 300 1,000 34 000 0,000 800 0,000 28 600 -1 ,000 26 100 -2. 000 26 100 0,000 27,1 O0 .-3,000 3~.200 I ,000 36,300 -i ,000 34,100 DATA RECORD'--'o 2.3 DEPT TENS DR TR RECORDS · 5289 000 ~: 000 3?, 200 5~ 89 600 -3. 000 5:)89 600 I ,000 4989 000 -3,000 40,4.00 4889 O00 0,000 40:800 4789 000 0.000 .37.000 4689 000 0,060 14,666 4589 000 1.000 19.4.00 4489,000 '-2,000 'I 8,300 4389 000 '0,000 33 ?00 4289 000 0,000 32 806 4i89 000 0.000 26 400' 4689 000 -2,000 3989 000 0,000 21 100 3889 000 I ,000 41 400 ,..,at 0,000 34 100 3689 000 0.000 28 906 3589 000 1 ,000 39 800 DEPT T E N S GR DA TA RECORDc'._, P ag m 3489.000 O~ 000 Z,,O, 900 3389.000 i,O00 29,500 ~289, 000 0,000 3i89.000 0,000 39.100 3089,000 0,000 26,600 2989 000 -i ,000 33,S00 i , 000 2789 000 -1 ,000 29,300 0,000 39,400 2589 000 0.000 20,800 2489 000 0,000 t7,200 FiLE TRAILER. *~.*~. Film nature: &GSFO~, 003 Mmximum lmngth: 1024 'TRAILER RECORD~- · miliIll Vmrsion ~: File typm: LO Nmxt ?i Date: P ag m 26 ': EOF EOF ***
