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Home My WebLink About185-007MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2U-04 KUPARUK RIV UNIT 2U-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2U-04 50-029-21270-00-00 185-007-0 W SPT 5643 1850070 1500 1440 1440 1440 1440 190 190 190 190 4YRTST P Austin McLeod 8/7/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2U-04 Inspection Date: Tubing OA Packer Depth 520 2200 2100 2090IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220808193827 BBL Pumped:2.4 BBL Returned:2.2 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:39:57 -08'00' MEMORANDUM TO: Jim Re, -,g P.I. Supervisor C�� iUZ( FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT 2U-04 Insp Num: mitMFH210818073917 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 20, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, hie. 2U-04 KUPARUK RIV UNIT 2U-04 Sre: Inspector Reviewed By: n P.I. Supry = I` Comm API Well Number 50-029-21270-00-00 Inspector Name: Matt Herrera Permit Number: 185-007-0 Inspection Date: 8/15/2021 Packer Depth Well 2U-04 Type Inj w -TVD i 5643 Tubing YP PTD 1850070 Type Test SPT Test psi 1500 IA BBL Pumped: 2.4 ' BBL Returned: 2.3 OA Interval 4YRTST P/F P Notes: MIT -IA Performed to 2600 PSI Per Operations Pretest Initial 15 Min 30 Min 45 Min 60 Min 1770 1780 1780 1780 710 2600" 2460 - 2425 160 160 160 160 Friday, August 20, 2021 Page I of 1 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2U-04 Run Date: 7/13/2019 RECEIVED AUG 0 5 2019 AOGCC 105007 3 106 0 July 19, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2U-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21270-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS–ANC@halliburton.com Date: MQ�9 Signed: A_ t,—J Operations Performed: Depth Depth CONDUCTOR SURFACE PRODUCTION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Plug for Redrill ❑ erfomte New Pool ❑ Repair Well ❑+ Reenter Seep Well ❑ CODOCOPhIIIIpS Alaska, Inc. 4. Well Class Before Work: 5. Penn Development ❑ Exploratory [E]P. O. Box 100360, Anchorage, Alaska Stratigrephic❑ 99510 Service p e. API r 25644 N/A measured 8,020 feet Plugs true vertical 6,149 feet Junk measured 7,906 feet Packer true vertical 6,062 feet Length Sim MD 77 feet 16 115' MD 3,504 feet 95/8" 3,541' MD 7,953 feet 7 7,989' MD Well Name and Number: River Field / rr II •� . Operations shutdown ❑ Change Approved Program ❑ Other: Tubing/Casing Patch El nIt Number: 185-007 KRU 2U-04 River Oil Pool measured None feet measured None feet measured I, 7437, 7460, 7582, 7596, feet true vertical -5714,5731 , 5821, 5832, feet TVD Burst Collapse 115' ND 2999' ND 6125' ND Perforation depth: Measured depth: 7500-7556 7668-7730 7795-7801 feet True vertical depth: 5761-5802 5885-5931 59805994 feet ing (size, grade, measured and true vertical depth) 3.5" L-80 7,629' MD 5,856' ND oars and SSSV (type, measured and true vertical depth) PACKER - OTIS RRH RETRVBL PKR LWR PACKER (ME) - LOWER ER PKR 7,340' MD 7,460' MD 5,642' ND UAERMPERRR 7,582' MD 5,731' ND 5,821' ND LWR PACKER (ME) - LOWER ER PKR 7,596' MD 5,832' ND PACKER - OTIS WD PACKER 7,604' MD 5,838' ND Itimmation or cement squeeze summary SSSV - CAMCO TRDP-1A 1,900' MD _ 1,819'TVD treated (measured): N/A It descriptions including volumes used and final pressure: =Fly nveFage rrooucnon or Infection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: o e 3500 900 1150 Subsequent to operation: e e yypg 900 2500 Chme0i5 (requiree par 20 A:25,070,25o7l,425.283) 15. Well Classafterworie sport of Well Operations Exploratory ❑ Development ❑ Servoof Logs antl Surveys RuStretigraphic ❑16. Well Status anter work: Oil ❑ Gas ❑ WDSPL ❑and Electronic Fracture n Data ❑ GSTOR ❑ WINJ ❑ WAG ❑+ GINJ ❑ )USP ❑ SPLUG ❑ :reby certify that the for is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 319-150 ed Name: Steve Drake Contact Name: Steve Drake ed Title: Sr. Wells Engineer Contact Email: steve.g.drake@Cop.com sit Signs ure: C' Date: �Contact Phone: (907) 263-4062 Form 10-404 Revised 4/2017 p(p �i y/� RBDIVIS-604UG 0 12G19 Submit Original Only �,l KUP INJ 'r.�l' We11AtVibutea COQi000�1ska�75 DeltlName Alaska. Inc KUPARUN RIVER UNI omment SSSV' LOCKED OUT WELLNAME 2U-04 WELLBORE 2U-04 awi.na.Dle+z3a:m vu Last Tag yMv916MamaEclsbel) Ammp edmn DaPpia B) Elapses "Res"'Iasi MaB aY " ..............................................._____......................._..... Last Tag: SLM ).811.0 112/2018 2U-04 X9NGER3� : m ^hn n n .. n n n n CONDUCTOR. 290-1150 3AIFEWWV, Tki GA6 Up dep". eighACE: V ea.1 a_ G4suFlIel 1 GA8 upr:4.mss GASLIET 5,.4 GASLMT:5.al .D1,asel daptUrT.1inall GeB JIT. T.M. SM , 7,vP4 PACKER: 1.33,45 IwECTloN:1,3)511 UPR PACKER IMEk ).e31.o SPACER PIPE: 1,¢340 IWECTIDN:TKIa LWR PACKER IME): 1.1N,0 IPERF:1.0.756l.p VPR PACKEq (MEI: 1.5020 INJECTION' , 1,5043 SPACER PIPE 7.W0 LWRPACKER(ME):1,53so LOCATOR: 7.6gi PACMR;Tpai WE,TAI HIPPIE; ].6188 sol: 1.8S.t WIeG:7,aaa PERF7898.0 7ati IPERF; Taaa0,7.parl PROWCTION, 3637.1 7/02009 Last Rev Reason MEnd Dale WpIIMre Iasi Mctl Oy Rev Reaspn. PDII Existing Patch aned SetSel Two Patches )/16/2019 2U-04 Inverammi Casing Strings asmp oeserlRam OD pnl In(in) Top east slt WhMB) seelp,marvil Lan it l) jo Gnw Top Thread 06 38.0 11 CONDUCTOR 16 1550 115.0 62.50 H40 WELDED Casing Deccnptlon Oapn) 1011,4 Top lkKsl SN11 IK, get pep, I I vDI... WIILan a.. Ga]e Top Thread SURFACE 996 8.92 3].0 3,541.0 2,999.1 36.00 J-55 BTC 2,9 Caeln Dezcnplbn OO In urn To IINB Sei De h ryKa g 1 1 r( 1 PI ( 1 damph (NOL.. wtlLas 11... Gm r Tap Thread PRODUCTION ] 628 35.2 ),9885 6,1255 2600 J-55 BTC Tubing Strings Tubm oescnpuon s1,mp Ma... 10n", TopinKel Ser Oepm lk jai a EVD1(... WIP") Gmde Top connenOR TUBING 31/2 '2 9 33.3 ],629.3 5,856.2 9.30 L-80 EUEBRDMOD Completion Details ToPmp) Top 1-101 Nominal Top(Mlal (rt 0 Item pn Com ID (in, 33.3 0.0 HANGER MCEVOY TUBING HANGER 3.500 000 1,818.9 37.18 1 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE (LOCKED OUT 917/01) 2.812 ], 8.4 5,834.2 42.76 SEIR OTIS SBR .13 ],3395 56424 4276 PACKER OTIS RRH RETRIEVABLE PACKER )0 ),488.6 5,752.1 42.32 BUST RINGS CARBIDE BUST RING (3) 2.992 7,6038 5,83).3 4.36 LOCATOR OTIS LOCATOR 3.00 7,604.4 5,83).] 42.36 PACKER UIB WD PACKER 4.000 ),60)4 5,8400 4.35 SBE OT IS SEALBOREEMENSION OW ].fiiS6 5.849.0 4.30 NIPPLE CAMEO D NIPPLENO GO 2.]50 ,7,626.1 5.865.3 4227 SOS 0 1 HEAR OUT SUB 3015 UIDE 3015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(ND) I Top Incl Top perks, (PIKE) ci Des I Com Run Dab ID (m) 7,iISITO 5,714.0 42.55 UPR KER 3-1/"Upper ER Pa erw/Anchor Ladd. DAL 7118 19 1750 (ME) 22.37'(SN . CP350087T CPS350026) 7,430.0 5,714.8 42.55 SPACER PIPE 2-3M.r Spacer Pipe /1 019 1750 7,460.0 5,]310 4245 L A KER 3-112' Lower ER Packer (SN: CP50006) 711&2019 1750 (ME) 7, 02.0 5.821.2 42.36 UPR R 3 peer ER Packer AncNw tcb, AL 7/152019 17M (ME) 14.25- (SN: CP35%MW CPS350058) ]583.0 , 5,821.9 42.36 SPACERPIPE 2-318" Spacer Pipe 4152019 1750 -LW--R-PA ),596.0 5,831.5 42.38 PA KER 3 VZ Liver ER Packer (SN CP350054) ]/13/2019 1750 (ME) Perforations d slots shoe TopINDI BMINDI Dens ese Toplitl(al amlmpalB) IKMKS) Unkedzone Dale (•hI Tape am 7,50. 7,556. 5)60fi 5.802.0 Ca,2U-04 YIva 1985 120 (PERF b-ratedTCP 7,880. 7,730.0 5.804.0 5,930.9 A -3,A<, 2U-04 3l /1985 40 IPERF 5"Baker TCP 7,795. ),801.0 5.9]9.8 5,984.1 A-2, 2U-04 Yt W1985 4.0 IPERF 5"Baker TCP Mandrel Inserts St an an Top IND) valor I Lakh acme. Parl B Topme) IRKS) Make I MadN OD tin) sell TOP,, Type (in) 051) Run Dab Com 1 ZJIKUB 1,900.1 CAMCO IMUG 1 GAS LIFT DMY ltdru, I 0000 00 923/1985 4:00 2 3.MST 3,1 37 CAMCO IKBUG 1 GAS LIFT DMY BK2 0,000 00 MVV 85 830 3 4,985.5 3,985.9 CAMEO IKBUG 1 =LIFT- DMY 10 0000 0.0 323119&5 1200 4 5,54 .4 4,3728 CAMEO IKBUG 1 dWLIFT DMY BK2 0000 00 Y2311985 9:00 5 5,994.8 4,684.1 CAMCO IMUG 1 GASLIFT DMY BK2 0.000 00 32L19 55 400 6 6,40377 4,974.1 CAMCO IKBUG 1 GAS LIFT DMY BK2 0.000 0.0 3291 5 3:00 ) 88484 5,28 .5 CAMCO MUG 1 GASLIFT DMY BK2 0.000 00 3231985 1200 8 7,286.9 5,603.8 MERU TPDX 110 GAS LIFT DMY RM 0.000 0.0 98/1997 2:30 -RU- 9 7,375.8 5,869.1 WE TPDX 1112 INJ DMY M 0.000 00 1021/1996 9:00 1 7,447.9 5,]22.1 MERU TPDX 1121NJ DMY RM 0 C. 00 IW281201 200 4.3 1 7,58 5,822.9 MERIA TPD% 111 INJ DMY RM 0.000 0.0 811/1996 900 1 Notes: General B Safety Ela ogre Anammon NOTE: Surface CSG Pasch Sleeve MIT 12" 500 wall API SL -X65 pipe (DAILIES') See W17/09 WBR 2U-04 TUBING/CASING PATCH DTTMSTPJOBTYP SUMMARYOPS 7/12/19 ZONAL PULLED UPPER 2.74 ER PATCH ASSEMBLY @ 7441' RKB, PULLED 2.74 LOWER ER PACKER @ 7462' RKB, BRUSH n' FLUSH TBG TO 7619' RKB BRUSH PATCH SETTING AREA FOR 20 MIN'S DRIFT TBG W/ 16' x 2.74 DUMMY PATCH CLEAN DRIFT TO 2.75 NIPPLE @ 7619' RKB. IN PROGRESS. 7/13/19 ZONAL SET LOWER 2.74 ER PACKER @ 7596' RKB (ME) (SN: CP350054 / OAL 2.87 / 1.75" ID), JOB POSTPONED FOR RIG JOB. 7/14/19 ZONAL RAN 2.74" UPPER ER PACKER PATCH ASSEMBLY (OAL 14.25,/ SN: CP3500112) ATTEMPT TO SET PATCH ASSEMBLY AFTER JARRING DOWN ON PATCH ASSEMBLY 15 TIME PULLED UP TO CONFIRM ANCHOR LATCH IS STUNG INTO LOWER PACKER @ 7596' RKB, TOOLS WERE MOVED UP HOLE AND RELAY COMMS LOST. RECOVER WIRE. RELAY TOOLS AND PATCH ASSSEMBLY LIH. IN PROGRESS. 7/15/19 ZONAL TAG FISH WITH 2.68" LIB @ 7489' SLM LIB SHOWS TOP OF ROPE SOCKET W/ SMALL TAIL OF WIRE, RAN 2" RJ SPLIT SKIRT PULLED FISH AFTER 15 MINUTES OF JARRING WITH LFTJ'S OF FISH ANCHOR LATCH WAS MISSING ALL SEALS & WAS SHEARED, SET 2.72" UPPER ER PACKER PATCH ASSEMBLY @ 7582' RKB (OAL 14.25 / SN:CP350004). IN PROGRESS. 7/16/19 ZONAL SET LOWER 2.72" ER PACKER @ 7460' RKB (ME) WHILE PUMPING @ 1 BPM TO OVERCOME CROSS FLOW (SN: CP350006 ), SET UPPER 2.72" ER PACKER SPACER ANCHOR LATCH ASSEMBLY @ 7437' RKB (ME) PUMPING @ 1 BPM (SN: CP350087), SET 3 1/2 ER TEST TOOL IN UPPER PACKER @ 7437' RKB MIT TBG 2500 PASS. COMPLETE. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Steve Drake Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2U-04 Permit to Drill Number: 185-007 Sundry Number: 319-150 Dear Mr. Drake: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ~v.acgcc.olaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this day f March, 2019. �8®{J1S�� MAR 101019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 RECEIVE® MAR 2 6 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well F1 Operations shutdownLJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing/6esing-13atchEl ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 0 . 185-007 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21270-00 7. If perforating: 8. Well Name and Number: . g�a7• What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2U-04 ' Will planned perforations require a spacing exception? Yes ❑ No O 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25643, A?'L Kuparuk River Field/ Kuparuk River Oil Pool 11. 6N, > , Z?. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,020' 6,149' 7906 6062 2500psi NONE NONE Casing Length Size MD TVD Buret Collapse Conductor 77' 16" 115' 115' Surface 3,504' 95/8 3,541' 2,999' Production 7,953' 7" 7,989' 6,125' Perforation Depth MD (ft) IPerforation Depth TVD (ft): ITubing Size: Tubing Grade: Tubing MD (ft): 7500-7556, 7668-7730, 7795- 5980- 3.500" L-80 7,629' 7801 15761-5802,5885-5931, 5984 1 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - OTIS RRH RETRIEVABLE PACKER MD= 7340 TVD= 5642 PACKER - OTIS WD PACKER MD= 7604 TVD= 5838 PACKER - WFD WIDEPAK UPPER PACKER MD= 7442 TVD= 5717 SAFETY VLV - CAMCO TRDP-IA-SSA SAFETY VALVE MD= 7462 TVD= 5733 MD= 1900 TVD= 1819 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 17 14. Estimated Date for 3/29/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG O GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Steve Drake Contact Name: Steve Drake Authorized Title: Sr. Wells Engineer Contact Email: steve.g.drake@cop.com Contact Phone: (907) 263-4062 3 Authorized Signature: Date: Z I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. SV 0�l � I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: a+xs / � MAR 2 ' ROWS Post Initial Injection MIT Req'd? Yes ❑ No p Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /,.12 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:./l Q 3 I o rY�� I (` t Submit Form and ro 0.403 Revised 211 Approved appliCati n a l f n date Of approval. Attachments in Duplicate General Well Work Request Form Well: 21.1-04 Date of Request: Request SPDC: Well Type: Injector Req. Written by: Job Scope: Tubing/Casing Patch Shut-in Reason Code: Budget Category: 1 Kuparuk Base Expense Well Shut in Date (if SI) Prioritization Category Network: Job / SAP Comment: 3/25/2019 I CPF2 PE David/Stephanie x7519, pgr 252 Steve Drake, 263-4062 270 Tubing / Casing / Packer Leaks 8/2412015 OpportunilylRate Adding OWell Work is not justified via increased Production ❑Preventive Maintenance Program Request In Well Data Surrounding Producer Data Current Injection Rale (RVBPD) 0 Total Offset (AOF) Oil Rate (BOPD) 50 Risked NOB (BOPD) Enter Rates Last SBHP 2894 psi Last Tag 7,811'md SBHP Date 6114/2016 Tag Date 11/2/2018 SBHP Datum (TVD/SS?) 5933 TVD Max Inclin. 48' Min. LD (at/above work) 2.812" Max Incl. Depth 3,900'md 1-12S FPM): Any Fluid Restriction on Well? 2U-02 150 No Max Dogleg 4" 1 100'and Max Dogleg Depth 1,600'md Well Work Justification & Objectives (and date required if appropriate): 2U-04 is an A/C sand injector that has been SI since August of 2015 for well line repair. In Decemeber of 2018 a leak was found in the selective at a depth of 7590' RKB. Patching the leak and returninLthe well to A only injection makes the impending well line upgrade economical. This procedure will outline the steps to pull the assisting patch, set the lower selective patch and reset the upper patch. Well to remain SI until surface r work is completed. p a 2' c,4 e- S— mra i" SG le- c f'Y= Risk/Job Concerns: Min ID above work: 2.812" Carrico TRDP-1A SSSV Exsisting selective patch @ 7439' RKB. Well has scale. See WV entry from 11/2/18. SL bailed 3 gallons of scale off of patch test tool. Steps: Relay (Pull batch, brush and flush tubing, set selective batches) 1. MIRU Relay and associated equipment. 2. MU and RIH with drift assembly to ensure patch can be pulled. Clean up any tight spots with BLB or swedge. 3. Pull upper patch section @ 7439' RKB. 4. Pull lower WFD patch packer @ 7462' RKB. 5. RU LRS to pump down tubing. B&F patch setting areas from 7400-7600' RKB. 6. MU and RIH with lower packer of lower patch assembly. 7. Set lower packer, center element, @ 7596' (in the 30' pup below GLM 11). 8. RIH with upper packer and spacer pipe. Stab into lower packer @ 7596' RKB, setting upper packer @ 7582' (in the 4' pup above GLM 11). 9. Set lower packer of upper patch @ 7460' RKB (in the 30' joint above the blast rings). 10. RIH with upper packer and spacer pipe of upper patch. Stab into lower packer @ 7460' RKB, setting upper packer @ 7437' RKB. 11. Set test tool in packer of upper patch. MIT tubing to 2500 psi. Troubleshoot any failing pressure test. 12. Pulltesttool. 13. RDMO. Ensure well is FP. Turn well over to OPS. 2U-04 Patch 03-25-195GD.Aam Printed 3/26/2019 KUP INA) WELLNAME 2U -O4 WELLBORE 2U-04 f �pPh ps h+" Well Attributes Max Angle & MD TD C `O" ''I''r�+ IF eH Name IWNIEort APYUW WeII-11 SUlus Cl MO 1XI(BI A 181T 1X ai Alaska. blc. KUPARUK RIVER UNIT 50029212]000 INJ R2R 390000 xronn 2uoe. 3rzenm9 6Wal AM Last Tag .xhmaucT.) Annatatbn pegp, Maj Ener DaleWalIV. I�tlier By Last Tag: SUM ],]]20 8+1112016 2U-04 Ippmven HANGER; 343 CIXIOUCMR. A�DilSO SAFENVLV; IAI GAS UET:2was SURFACE; 37.04.5410- GAS LIFT: aural GAS UFT: 4,M5 GAS un;ssla.4 Gas uFr; s.roe.e GAs uFr; B"mp GAS LIFT:.4 Ges uFTl ].MAe gag. 73Me PACIfER: T.93B. 5 INJECTION: 7]3 ER PACItFRV.MIS PATCH: 447O INJECTION,N. TT,Mg ERGon JACKER:T.4R0 IPERFn.DgooTssao_ IWECTI0N,7SE43 mCA1oR: T,eme PAc ,KER'T'ma" SI E', 7,6 belp.: IJI 806', T,o WLEG:T.AMB /PERE', 7,6T.]91.0� IPERF.>,AB.D7b10-e PRODUCTION: 35 Onr8.5 Last Rev Reason pn,rolalion Entl Dale I WejlMe I Last MI By Rev Reason'. TAG Ipp.s.g Casing Strings eeeine Deaenption oo grit ID (in)roe MKej ax psoas IaKM saD sin MIS enp._eme Toprnreatl CONDUCTOR 16 1506 380 115.0 115.0 62.50 H-00 WELDED Casing Description DD get 110 (in) ToringutI era Depth IXKM Sen Depth (TV0L.MLen(I...Ignore ITurp TM1rwtl SURFACE 9518 8.92 370 3,5410 2,999.1 36.00 J-55 BTC Casing Description 100 (in) Ip (in)Tap IMtB) 9tl Oepq Met aet pepq RX.)-VMeB... G,atle Top iM1reatl PRODUCTION ] 630 35.2 ],9885 6,125.3 2600n d55 BTC Tubing Strings Tubing Descripfwn Sling CA...ID pnj Top 1aKBI aN DepM M.Se1 DepIM1 IND/ I_.. WI I1Mlj GrWe Top tonnedion TUBING 3112 2.99 33.3 7,629.3 58582 930 L-80 EUESRDMOD Completion Details Top(NDI "Incl Nortop(ME) InKB) 1°) Item Des Co. ID(in) 33.3 333 0.03 HANGER MCEVOY TUBING HANGER 3.500 1,9000 1,818.9 3].18 SAFETYVLV CAMCO TRDP-1ASSA SAFETY VALVE (DOMED OUT W1 7101) 2.812 7,320.4 5,634.2 42.76 SBR OTIS SBR 2,813 1,339.5 5,6424 4276 PACKER OTIS RRH RETRIEVABLE PACKER 2970 ],488.6 5,7521 4232 BLAST RINGS CARBIDE BUST RINGS (3) 2.992 7,603.8 5,8323 42.36 LOCATOR OTIS LOCATOR 3,000 7,604.4 5,83]] 42.36 PACKER OTIS WD PACKER 4.000 ],8014 5,840.0 42.35 SBE OTIS SEAL BORE EXTENSION 3.000 5,849.0 4230 NIPPLE CA NO GO 2.7 1,62.1 5,855.3 42.2] SOS UIBSHEAROUT SUB 3015 1,288 5.35581 42.26 WLEG I OTIS WIRELINE RE-ENTRY GUIDE 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(Noj Top Net TOP(XRe) Y-) EI m Des CoRon Do. ID(In, 7,439.0 5,]15.5 42.54 PATCH PATCH(OAL26) 3119)2015 1992 ],4415 5.]1)4 4233 ER PACKER 3 i/ " WFD WIDEPAK UPPER PACKER W bPAGIEH 311912015 1.810 AND SNAP LATCH 7,4620 5,732.5 42.44 ER PACKER 312' WFD WIDEPAK LOWER PACKER W ANCHOR jjn6w15 1 1.810 Perforations 8r Slots snot Oen, IhohlX top)Mal Lm1b4Zaw Dela I Type Com 7,5000 ],55fi0 5,]60.6 5.1302.0 C4, 2UH04 3119/1985 1 120 1 IPERF 9 Bak,TGP 7,6680 ],]30.0 5,8848 5,830.9 73, AI, 2U-04 YT79gr 40IPERF 5 -Bake, TCP ]]95.0 ],801.0 SW9fi 5,984.1 9.2,2U-04 111 5 40 (PERF YBaker TCP Mandrel Inserts at atl Top(ND) VaM la2M1 PoNSrse TRO Run N Top 1a"I' MKBj Mae MOEN OD (in) Sere Type Type (In) Dun) Run Do. Com 1 2,003.9 1,900.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 00 3)2311985 4'00 2 3,609.1 3,193] CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3123/1985 830 3 4,9055 3,985.9 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3123/1985 1200 4 5,5494 4,372.8 CAMCO KBUG 1 GAS LIFT DMY BK2 0000 00 312311985 9:00 5 5,994.8 4, .1 CAMCO KBUG 1 ME LIFT DMY BK2 0000 00 M2 lN5 4:00 6 6,4039 4,974.1 CAMCO KBUG 1 AS LIFT DMY BK2 0.000 00 312311985 3 D ] 6,8484 5,2885 CAMCO KBUG 1A LIFT DMY BK2 0.000 0.0 323/1985 129.0 8 7,2869 5,603.8 MERU TPDX 112 M LIFT DMY RM 0.000 0 WM997 230 9 ],3]5.0 5,669.1 MERU TPDX 112 NO DMY RM TWO 0.0 10121/1996 9'.00 ]AQ.9 5.7221 MERU TPDX 1112 INJ DMY RM 0.000 VV 102W2010 2.00 0 1],5843 5,822.9 MERU TPDX ttl2 INJ DMV RM 0.000 0 W1/199fi 800 Notes: General & Safety En4Dace I Annolatian 7117/2009 NOTE. Surface CSG patch Sleeve Mir 12'.500 well API SL -X65 pipe (DAL =9'5'7 See ]11]109 WSR Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC v ATTN: Natural Resources Technician II Alaska Oil &Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 185ui� I 30209 WELL NAME API p SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE-- Color DATE LOGGED Prints CD's dtt I Receipt / / X ame Signat e return via courier or sign/scan and email a copy to ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the v `-I package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this and CPAL point. SLB Auditor- —SLj Schlumberger -Private STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMh..0SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Plug Perforations r Perforate rOther Tubing Patch Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185-007 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21270-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643 KRU 2U-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8020 feet Plugs(measured) none true vertical 6149 feet Junk(measured) none Effective Depth measured 7906 feet Packer(measured) 7340,7604,7442, 7462 true vertical 6062 feet (true vertical) 5642,5838,5717, 5733 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3504 9.625 3541 2999 PRODUCTION 7953 7 7989 6125 RECEWED APR 10 2015 Perforation depth: Measured depth. 7500-7556,7668-7730,7795-7801 True Vertical Depth 5761-5802, 5885-5931,5980-5984 SCANNED , , ! 1 2, .''. AOG GG Tubing(size,grade,MD,and ND) 3.5, L-80, 7629 MD, 5856 TVD Packers&SSSV(type,MD,and ND) PACKER-OTIS RRH RETRIEVABLE PACKER @ 7340 MD and 5642 TVD PACKER-OTIS WD PACKER @ 7604 MD and 5838 TVD PACKER-3.5"WFD WIDEPAK UPPER PACKER @ 7442 MD and 5717'ND PACKER-3.5"WFD WIDEPAK LOWER PACKER @ 7462 MD and 5733'TVD SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE @ 1900 MD and 1819 ND 12.Stimulation or cement squeeze summary. Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG 17 GINJ r SUSP r SPLUG r 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 314-621 Contact Tyson Wiese an,263-4250 Email Tyson.M.Wiese@conocophillips.com Printed Name T on Wiese Title Wells Engineer Signature Phone:263-4250 Date 4....0\__ �S W Form 10-404 Revised 10/2012 i L 4//v //5__ RBDM �n� 0 D2 15 Only Submit Original - 40, 04 WELL WORK SUMMARY DATE . SUMMARY 3/18/2015 SET 3 1/2" WIDEPACK LE PACKER @ 7462' RKB. (2.72" OD, 1.81" ID, 5' OAL). HAD TO PUMP 1 BPM TO PASS BY CROSSFLOW @ LEAKING ST#10 GLM @ 7448' RKB. *JOB IN PROGRESS. 3/19/2015 SET 3 1/2"WFD WIDEPAK UPPER PATCH SECTION @ 7441.5' RKB (PACKER, 14' SPACER, SNAP LATCH). SET 3 1/2" TEST TOOL INTO TOP OF PATCH @ 7441.5' RKB. LRS PERFORMED MIT-T TO 2500#. PASSED. PULLED TEST TOOL. *JOB COMPLETE, TURN OVER TO DSO. 3/20/2015 PUMPING 20 BBLS METH FROM MANIFOLD F/P F/L ( JOB COMPLET ) ;. KUP INJ 2U-04 ConocoPhillipsWell Attributes Max Angle SMD TD Alaska,IncI :i` Wellbore APIIUWI Field Name Wellbore Status Inc!1") MD(ftKB) Act Btm(ftKB) 500292127000 KUPARUK RIVER UNIT INJ 48.28 3,900.00 8,020.0 °"° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2U-04.325201510:57:08 AM SSSV:LOCKED OUT Last WO: 41.09 226/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,870.0 11/16/2014 Rev Reason:SET PATCH lehallf 3/24/2015 A� f r HANGER'33.3 F- t.astng 3Yenga Ir 1 11, - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(NKB) Set Depth(TVD)...WI/Len p...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED ', I Casing Description OD(1n) ID(in) Top(ftKB) Set Depth MB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread J SURFACE 95/8 8.921 37.0 3,541.0 2,999.1 36.00 J-55 BTC assemesioukumsomumumurumuu W!�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(NAB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.2 7,988.5 6,125.3 26.00 J-55 BTC v Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;38.0-1150 .es.TUBING 312 2.992 33.3 7,629.3 5,856.2, 9.30 L-80 EUE8RDMOD Completion Details SAFETY VLV;1,9000 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(°) Item Des Com (In) Ill 33.3 33.3 0.03 HANGER MCEVOY TUBING HANGER 3.500 GAS LIFT,2.003.9 1,900.0 1,818.9 37.18 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE(LOCKED OUT 2.812 8/17/01) 7,328.4 5,634.2 42.76 SBR OTIS SBR 2.813 7,339.5 5,642.4 4276 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 7,488.6 5,752.1 42.32 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 SURFACE,37.0.3,541 0-e 7,603.8 5,837.3 42.36 LOCATOR OTIS LOCATOR 3.000 GAS LIFT;3,809.1 7,604.4 5,837.7 42.36 PACKER OTIS WO PACKER 4.000 1 7,607.4 5,840.0 42.35 SBE OTIS SEAL BORE EXTENSION 3.000 GAS LIFT,4.985.5 /11 7,619.6 5,849.0 4230 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,628.1 5,855.3 42.27 SOS OTIS SHEAR OUT SUB 3.015 GAS LIFT;5.549.4 11 7,628.8 5,855.8 42.26 WLEG OTIS WIRELINE RE-ENTRY GUIDE 3.015 III GAS LIFT;5.994.8 Other In.Hole(Wireline retrievable plugs,valves,pumps,. fish,etc.) II Top(ND) Top Incl 1 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;6,403.9 II 7,439.0 5,715.5 4254 PATCH PATCH(DAL 26') 3/19/2015 1.992 III 7,441.5 5,717.4 42.53 ER PACKER 3 12"WFD WIDEPAK UPPER PACKER W 3/19/2015 1.810 SPACER AND SNAP LATCH GAS LIFT;6,848.4 a. 7,462.0 5,732.5 42.44 ER PACKER 3 1/2'WFD WIDEPAK LOWER PACKER W 3/18/2015 1.810 & ANCHOR GAS LIFT;7,286.9 Perforations Slots 111 Shot • Dens Top(TVD) Btm(TVD) (shout( SBR;7,328.4 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com CI� 7,500.0 7,556.0 5,760.6 5,802.0 C-4,2U-04 3/19/1985 120 IPERF 5"Baker TCP Ili 7,668.0 7,730.0 5,884.8 5,930.9 A-3,A-4,2U- 3/19/1985 4.0 IPERF 5"Baker TCP PACKER;7,339.5 - `-: 04 7,795.0 7,801.0 5,979.6 5,984.1 A-2,2U-04 3/19/1985 - 4.0 IPERF 5"Baker TCP INJECTION,7,375.8 0.. 7,79E0 Mandrel Inserts 7,801.0 ati i . o Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn ER PACKER;7,441.5 _ 1 2,003.9 1,900.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 4:00 PATCH,7,4390 2 3,809.1 3,193.7 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 8:30 INJECTION,7,447 , .9 I 3 4,985.5 3,985.9 CAMCO KBUG - 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 12:00 I 4 5,549.4 4,372.8 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 900 5 5,994.8 4,684.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 4:00 ER PACKER;7,462.0 6 6,403.9 4,974.1 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 3:00 au4 a 7 6,848.4 5,288.5 CAMCO KBUG 1 GAS LIFT DMY BK2 0.000 0.0 3/23/1985 12:00 III 8 7,286.9 5,603.8 MERLA TPDX 1 12 GAS LIFT DMY RM 0.000 0.0 5/8/1997 2:30 P. 9 7,375.8 5,669.1 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 10/21/1996 9:00 (PERF; 17,500.0.7,5560_ _ 1 7447.9 5,722.1 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 10/28/2010 2:00 s 0 1 7,584.3 5,822.9 MERLA TPDX 11/2 INJ DMY RM 0.000 0.0 8/1/1996 8:00 1 INJECTION,7.584.3 aIII Notes:General&Safety 111 End Date Annotation LOCATOR,7.603.8 =. 7/17/2009 NOTE:Surface CSG patch Sleeve Mtl:12".500 wall API SL-X65 pipe(0AL=9'S")See 7/17/09 WSR PACKER,7,6044 ... ''. I. SBE;7,607.4 a II NIPPLE;7,619.6 4 I SOS,7,628.1 WLEG;7,628.8ilt (PERF;7,668.0-7,730.0-- IPERF,7,795.0-7,801.0- PRODUCTION;35.2-7,988.5 STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMIS REPORT OF SUND WELL OPE RATIONS 1. Operations Performed: Abandon Repair w ell Rug Perforations Stimulate � Other Install Tubing Alter Casing Pull Tubing Perforate New Pool Waiver Patch Time Extension "" Change Approved Program Operat. Shutdow n ] "` Perforate ] Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development" Exploratory " ' 185 -007 3. Address: 6. API Number: Stratigraphic �" Service P. O. Box 100360, Anchorage, Alaska 99510 S 50 029 - 21270 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25644 ` 2U -04 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8020 feet Plugs (measured) None true vertical 6149 feet Junk (measured) None Effective Depth measured 7906 feet Packer (measured) 7340, 7440, 7460, 7604 true vertical 6062 feet (true vertucal) 5643, 5716, 5731, 5837 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115 SURFACE 3541 9.625 3541 2999 PRODUCTION 7988 7 8020 6149 Perforation depth: Measured depth: 7500'- 7556', 7668'- 7730', 7795' -7801' DEC Q 7 2010 True Vertical Depth: 5761'- 5802', 5885'- 5931', 5980' -5984' Alaska Ail & Gas Gems. Commission Tubing (size, grade, MD, and TVD) 3.5, J -55, 7629 MD, 5856 TVD Anr.haraga Packers & SSSV (type, MD, and TVD) PACKER - OTIS 'RRH' RETRIEVABLE PACKE pd6iM and 5643 TVD PACKER - UPPER WEATHERFORD ER PACKER @ 7440 MD and 5716 TVD PACKER - LOWER WEATHERFORD ER PACKER @ 7460 MD and 5731 TVD PACKER - OTIS'WD' @ 7604 MD and 5837 TVD CAMCO TRDP -1A -SSA @ 1900 MD and 1819 TVID 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation na na 2245 -- Subsequent to operation Si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory " Development Service Stratigraphic r GSTOR Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX r WINJ WAG GINJ r SUSP SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N /a, if C.O. Exempt: 310 -325 Contact John Peirce (a) 265 -6471 Printed Name John Peirce Title Wells Engineer Signature / / ,/ Phone: 265 -6471 Date 12-1-7110 N�c Form 10 4 Revised 0/2010 Submit Original Only 4 - /a - ?• /r_ 11"/7�w 2U -04 Well Work Summary DATE SUMMARY 11/3110 GAUGED TBG TO 2.80" TO D NWE @ 7620' RKB. BRUSHED & FLUSH E BG FROM 7375'- 7500' SLM. DRIFTED TBG WITH 25'x 2.74" DUMMY PATCH TO 7620' RKB. READY FOR E -LINE. 11/5/10 SET WEATHERFOR 2.74" ER LOWER PATCH PACKER AT 7463' CENTER OF THE ELEMENT IS 6' INTO FIRST FULL JOINT BELOW INJ MANDREL LISTED AT 7448'. 11/14/10 ATTEMPTED SET PATCH ASS'Y ON WEATHERFORD SLICKPUMP. UNABLE TO WORK PAST SBR @ 7328' RKB BEFORE PRE - SETTING ER PKR. PULLED PATCH ASS'Y f/ SBR, NO INDICATING MARKS; POSSIBLY LENGTH /RIGIDITY ISSUE. DRIFTED TO ER PKR @ 7463' ELM WITH RIGID TOOLSTRING & 20' DUMMY PATCH (OAL =43'). IN PROGRESS. 11/15/10 PATCH DELIVERY DELAYED BY RIG ON ROAD. ON INSPECTION, SETTING TOOLS DAMAGED IN TRANSIT. JOB SUSPENDED. 11/19/1 SET UPPER ER PKR SPACERPIPE AND SNAP LATCH ASSY FROM 7463' RKB TO 7442' RKB (OAL= 21'8 ",MIN ID 1.75 ") NEED TO RUN TESTOOL. 11/20/10 DISPLACE TBG WITH 65 BBL'S DIESEL A MITT UPPER ER PKR a@ 7442' RKB TO 3000 #.G OOD.GIVEN TO DSO TO BOL "A" SAND INJECTION. JOB COMPLETE. KUP • 2U -04 ✓ e - t��j W_gll .Attributes Max Angle_& MD _ TD {fl(: Wellbore APl /DWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) . 50029212/000 _ KUPARUK RIVER UNIT IINJ 48.28 3,900 8,0200 Comment H2S (ppm) ,Date An otation End Date KB (ft) Rig Release Date SSSV_ Locked Out .Last WO 41.09 2/26/1985 _ .it, Annotation Depth (ftKB) End Date Annotat n Last Mod By End Date Last Tag: SLM 7,717.0 4/25/2010 Rev Reason. SET PATCHH ASSY ImosborL 1202010 - Casing Strings String OD String ID Set Depth Set Depth (ND) String Wt String Casing D r�ion_ (in) (in) T (ft KB) (HKB) (ft KB) (Ibs/ft) Grade St ring To �hrd CONDUCTOR 16 15.062 I) 0 115.0 115.0 62.50 H40 CONDUCTOR,___, tts SURFACE 95/81 8.765 0.0 3,541.0 2,998.6 36.001J-55 �_ _ -, PRODUCTION 7 6.151 32.0 8,020.0 6,149.1 26.00 J -55 sateyv' Valve, _. -__ .e, .,,,. Tubing Strings_ .. __.. string OD String ID Set Gepth Set Depth (ND) String ) Stnng : T.M. De (in) (inl �7�(n M (kKBI (ft KB) (Ibs/ft) J Grade Strin To Thrd TUBING 3112 2.9921 0!0 7,629.0 5,856.3 _9 -301J 55 EUE 8RD GAS LIFT, _. 7 111 2'004 - 7 Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth' SURFACE, (ND) Top Intl 3,541 Top (ftKB) (111(13) (°) Descd on comment Run Date ID (in) L0.0 1,818.9 37.18 Safety Valve Camco TRDP- 1ASSA(LOCKED OUT 811712001) 3/23/1985 2.812 GAS _- 1,898.5 40 3,809 .05 GAS LIFT CAMCO/KBUG/1/DMYBK2/// Comment: STA 1 3123/1985 2.875 3,808 3 795.3 48.55 LIFT -- CAMCOIKBUC.Il /DMY /BK2 // /Comment: STA2 3/23/1985 128875 3,985.6 4714 GAS LIFT CAMCO/KBUG/1/DMYBK2/// Comment: STA3 3@3/1985 GAS LIFT. 4,986 ,,.. 4,372.5 46.24 GAS LIFT CAMCO/KBUG/l/DMYBK2// /Comment: STA4 3/2311985 w _ 4 ,684.2 4506 GAS LIFT CAMCOIKBUG11/DMYBK2/A Comment: STA 5 3/23/1985 6,403.0 4,973.5 45.03 GAS LIFT - CAMCO/KBUG/l/DMYBK2/// Comment: STA 6 3/23/1985 GAS LIFT 5,549 6,848.0 5,288.2 44.93 GAS LIFT CAMCO/KBUG/1/DMYBKW1 Comment: STA 7 3/23/1985 7,287.0 5,603.9 42.79 GAS LIFT MERLA/TPDX/1.5 /DMY /RM/ // Comment: STA 8 5/811997 GAS LIFT, 7,328.0 5,633.9 4276 SBR OUs 3/23/1985 2.813 5 ' 7,340.0 5,642.8 42.76 PACKER Otis'RRH' Retrievable Packer 323/1985 2.970 7,376.0 5,669.2 42.731NJECTION MERLA ITPDX11.5IDMYIRM / 11 Comment: STA9 1021/1996 2.875 GAS LIFT _ :7 7,440.0 5,716.1 42.20 PACKER -- UPPER WEATHERFORD ER PACKER 11/192010 1.750 6.403 7,442.0 5,717.6 4227 PATCH - WEATHERFORD SPACER PIPE, SNAP LATCH 17/792010 1.750 ASSEMBLY GAS LIFr, _ - 7,448.0 5,722.0 .42.21 INJECTION MERLA/TPDX/1.5/DMY /RM /// Comment EXT Pkg STA 10 10/282010 2.875 6'6°6 ],460.0 5,730.9 42.23 PACKER - - LOWER WEATHERFORD ER PACKER set 5' BELOW TOP 11/5/2010 1.750 OF FULL JOINT GAS LIFT, ],584.0 5,822.7 42.36 INJECTION MERLA/TPDX/1.5/DMY/RM /// Comment: STA 11 8/1 /1996 2.875 7,287 _ .., _ 7,604.0 5,838.1 42.75 PACKER Otis WD' 32317985 4.000 7,620.0 5,849.7 42.62 NIP Camco D' Nipple NO GO 32311985 2.750 = -- .a 7,628.0 5,855.6 42.56 SOS Otis 32311985 2.992 SBR, 7,328 - _ 7,629-0 5 42 55 WLEG Otis WIRELINE RE-ENTRY GUID 323/1985 2.992 7,630.0 5,857 0 42.54 TTL 32371985 2.992 Y l .,• _ - T � r;?�� O.ve`�'�n�'t��Y,Y3:.E wi rc a . - . PACKER, 7,360- -..- . Perforations & Slots Top (TVD) etm (TVD) Dens Top (Ill al. (ftKB) (11K8) (111(13) Zone D omm ale (sh° Type Cem INJECTION, 7,376 7,500.0 7,556.0 5,760.6 5,802.0 C 2U - 04 3/19/1985 12.0 IPERF 5" Baker TCP _.... 7,668 30 .0 7,730.0 5,884.9 5,9.7 A -3, A-4, 2U-04 3/79/1985 4.0 IPERF 5" Baker TCP 7,795.0 7,801.0 5,979 6 5,9841 A -2, 2U -04 3/19/1985 4.0 IPERF 5" Baker TCP PACKER, 7,a4o - - -- Noe Safety End gate Annotat ion 6/112008 NOTE' WAIVERED WELL OA x ATMOSPHERE INJECTION, 7117/2009 NOTE: Surface CSG patch Sleeve Mtl: 72" .500 wall API SL X65 pipe (OAL =9'5 ") See 7 117/09 WSR 7,468 PATCH, 7,u2 -- PACKER, 7,460 IPERF, •I?'! 7,500 -7,556 INJECTION, 7,584 PACKER, 7,606 NIP,7,620 SOS, 7,628 - WLEG, 7,629 TTL,7,630 - __ - _ _ PERF, - 7,668- 7,730 IPERF,_ 7,795 -7,801 PRODUCTION, TD, Be 0 �_ 6,020 - . • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 10, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2U -04 Run Date: 11/5/20 10 The technical data listed below is being submitted herewith. Please address any problems or concerns to fie attention o£ Minton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2U -04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -029 - 21270 -00 Nr ;1h PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. ,- Anchorage, Alaska 99518 9 Office: 907 -273 -3527 Fax: 907 - 273 -3535 j klinton.wood#halliburt_on.com A Date: Signed: MEMORANDUM To: ,Tim Regg ~ ~ P.I. Supervisor `~ ~ t ~° FROM: Chuck SCheVe Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2U-04 KUPARUK RIV UNIT 2U-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -~ " Comm Well Name: KUPARUK RIV UNIT 2U-04 Insp Num: mitCS1008230s394s Rel Insp Num: API Well Number: 50-029-21270-00-00 Permit Number: 185-007-0 Inspector Name: Chuck Scheve Inspection Date: 8/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zU-oa ' Type Inj. ' ~ TVD 6643 ~ IA aao P.T.D Iasoo~o' TypeTest SPT Test psi Isoo ~ OA o Interval 4YxTST p/r, F 'Tubing 2960 NOtes: pre-test pressures were observed for 30+ minutes and found stable. pressure gain noted. Fluid level shot indicated fluid at surface, 10 bbl pumped in IA and no Wednesday, August 25, 2010 Page 1 of 1 • ~/ • . ConocoPhill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 12~`, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~~~~~ ~l:T ~ ~ I00~ ~1~as~C~ ~ii ~ ~as Cnns. ~ommissio~ Anchora~e 5 ~ ~`~~~ " '~' ~' ~- ~`µ ~G~~ ~ 0 ;~'~~ „r ~ `;'~~ ` 5 l`b a~_ a~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was purnped September 2"d, 2009 and the corrosion inhibitor/sealant was pumped September 4~', and September 5~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. ely, Perry K ' ConocoPhillips Well Integrity Projects Supervisor • ' ~ • . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 10/5/2A09 .~~ ~ o n~ n w n Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corcosion inhibitor/ sealant date ft bbls ft al 2U-04 50029212700000 1850070 10'5" 1.5 6" 92R009 1.27 9/5/2009 2U-11 50029213030000 1850400 6' 1.00 9" 9/2/2009 1.9 9/5/2009 2Z-OS 50029209240000 1830380 5' 1.50 24" 9/2/2009 2.5 9/4/2009 2Z-09 50029213770000 1851360 4'6" 0.70 22" 9/2/2009 6.3 9/4/2009 2Z-20 50029218760000 1881240 6' 0.80 30" 9/2/2009 8.9 9/4/2009 2Z-29 50029218810000 1881290 26'5" 3.50 24" 9/2/2009 8.9 9/4/2a09 • n ` }ice ` r 77_3 t ' � � e ! i r 1; i ? [ I! — ° i ? t �' \\\,, SEAN PARNELL, GOVERNOR i '. L' ° LPL\ i. `� r 1_! ALASKA OIL AND GAS f' . 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ' ANCHORAGE, ALASKA 99501-3539 CANCELLATION ` PHONE (907) 279-1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL NO. AIO 2B.032 Ms. MJ Loveland Well Integrity Projects Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360, `^ ~'D JUN l l RE: Cancellation of Administrative Approval AIO 2B.032 Kuparuk River Unit Well 2U -04 (PTD 1850070) Kuparuk River Oil Pool Dear Ms. Loveland: Pursuant to ConocoPhillips Alaska Inc. (CPAI)'s request dated August 2, 2009 the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 2B.032, which allows continued water injection in Kuparuk River Unit (KRU) well 2U -04. This well exhibited a surface casing leak and CPAI did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. CPAI has since repaired the surface casing leak with a welded steel sleeve. Results from a surface casing integrity test (post - repair) were provided by CPAI in support of their request to cancel the administrative approval. Based on the information provided, Administrative Approval AIO 2B.032 no longer applies to operation of this well. Instead, injection into KRU 2U -04 will be governed by provisions of the underlying A1O No. 2B. DONE at Anchorage, Alaska and dated August 10, 2009. The Alaska Oil and Gas Conserve o Commission • iI 4 L !J' tyG Ca by P Foe ter ,or . N. an Co ssioner omm loner , • f* >r ~E~Ei'1/~Q `' . . ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 19, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: .JUL 2 ~ 2Q~1~ :'~laska Oi! & Gas Cons. Cammission Ancht~r~p~ ~ , ao7 ~~ ~ ,. ~~r, ~ tW.~{u~~~~~ ~ ~ ~ f~ L. . ~ . `~ 2~i ; Enclosed please find 10-404 Report of Sundry Well Operations & picture of repair for ConocoPhillips Alaska, Inc. well 2U-04 (PTD 1850070, Sundry #309-055). The report records the successful surface casing patch job Please call M.J. Loveland/Perry Klein at 659-7043 if you have any questions. Sincerely, Perry lein Well Integrity Project Supervisor t ~~~EIVEL~ JUL 2 $ 2009 STATE OF ALASKA ka O~t & Gas Cons. Commission ALASKA OIL AND GAS CONSERVATION COMMISS(~~ REPORT OF SUNDRY WELL OPERATIONS~~chorage 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ~ Stimulate ^ Other Q SC repair Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: o f ' ~~ 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. ~Exploratory ^ Development ` ~ 185-007 • 3. Address: Stratigraphic ^ Service ~i ° U 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Z 7 50-029-21270-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' ' 2U-04 . 8. Property Designation: 10. Field/Pool(s): ADL 25644 ALK 2575 Kuparuk River Field / Kuparuk Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 8020' ~ feet true vertical 6149' . feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 3436' 9-5/8" 3541' 2998' PRODUCTION 7988' 7" 8020.01' 6149' SC Sleeve 9'S" 42" 9'S" 9'5" Perforation depth: Measured depth: 7500-7556, 7668-7730, 7795-7801' true vertical depth: 5760-5802, 5885-5931, 5980-5984' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7629' MD. Packers & SSSV (type 8~ measured depth) packer = Otis RRH Retr, Otis WD 7328, 7604' SSSV: Locked out 1900' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operatio~ N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG ~^ • GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. exempt: 309-055 Contact Print Name Perry IIl Title WI Project Supervisor Signature Phone 659-7043 Date 7/19/2008 1~~_¢~'3 ~'L w `~`~,~~ ~ ~~~ ~ , ~ °r E ?~~~~i ~3 ~~ Form 10-404 Revised 04/2004 ~`° Submit Original ~~~~~ ~ 2U-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary CZ~I~F~7I~~7 07/17/09 07/18/09 Cut additional 2' of conductor off. Buffed surface casing and braden head with wire wheel, for inspection. Marked "A" and "B" and "C" bands. From top of "A" band, "B" band measures 70" - 77" and "C" band measures 106" - 113". Kakivik inspection in progress. Final T/I/O = SI/0/0. Surface casing patch weld.- Complete. Welded bands and sleeve per M.E. specs. Inner "A" band = 15" and inner "C" band = 5", are fabricated from 12" .500 wall API 5L - X65 pipe. Outer "A" band = 6" and outer "C" band = 3", are fabricated from 12" .375 wall API 5L - X65 pipe. Sleeve = 8' 6", fabricated from 12" .500 wall API 5L- X65 pipe. Overall length of collars and sleeve = 9' 5". Called QC for inspection T/I/O = SI/0/0. SCIT-OA (passed), Initial T/I/O = SI/0/0. Established LLRT of 15 gpm, with no fluids to surface. Total fluid pumped 56.25 gallons. Return @ later date to verify SCIT-OA. Denso wrapped surface casing. Ready to install conductor. • :'~ '•_,, ~ ` t'r ~;;- ~r,i~~ ,~. ~ . } • ° ~ +~~.~- ~- '~ R ~' k ~~ ~ R :~-' :. ; • ~ , , k t~~ .. ~~~ ~;~ ~~~~ }rR ~ € ~ '~'•~ ~ ~ ~f ~ •~±,i ~,I~;~ f L.'~ w,. ~~ ~ j~~t~~ ~ ' Y t~~ 7S ~ t ~ / ~g ~ _ ~` `' ~ ~ ~! ~ ~+e~ ~ ~ `~ ~"~:. ~ ~rv, y . ~ ~"a3k ,,~ : , '~,~~~°~~ ~ ~,'~y4'y `~ ~ ' ~~ ~'~~~`~~. 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"~ ' 4~ ~ .. . 1 ~ . . l~ . , . , . . . , . . ( 1 r ~ ' ~~ ~~ * n ^ ~~ ~ ~t 4 .,~ . ~ ~ , , . ~ ~ ' 1~ :;. ~' ~ ``~~~~ ~' ' ~ r ~, y' ~, j~ -~, ~, ~ f ~ ~ f { . ~S ~ d ~n. }tr 1 ~, t,• 1 ~ ~~ . 1 ~ ~. ~; .~_ i , . ~ , '~~ ~'vT~~~p . I?~ :y,:, k ~ b~ . ~ ~ ~r r w y~. ~~ . fi~~ ~y,~,~ ~ ~ ~ ~ 1 ~'] ' ` ' ' ~? : r,.r r .~r k 4 ~'. y/, ~ ~ t. P ~~~ 1 Y• _ •~ `.%C Y ~. ` ~~- , ' . ' ._ - .- , . ~ ~ r [f , 'x~,ry~ . .. "~1y.y ~~; ~. +~ .. ` F ~I. ' * M r"; * -' ; ~ S ~ ~ ~ 4 ' ~~ . ~~~A . ~ •, Z « Y~ . y t ~-.;~ y ~. I ~:M' ~ ~ .~ ~ ~ . . * . . . ~ . • + .~ ~ ~ ~~R ~jy"~ ~ . ~ ~ • "' - .;,3` _ ~ ;' ~.,. :. A' ~ ~ ~ Y ' . /: % .~t "~ ~ Vq ~'e ~ x~ ~ r ~ 'T~ '.~ . ._. . . ~, - , , , ~ ~~ ~ Y ~~~~ +~ ` '. . a ~t~ ~ ~ ?~` i , r . ' "~ - .;; f ~ ~ ~ ~~ d i~.'~ s- ~'~'w' ~ g~, . . ~ ~ ,di ~.~..Vuf C > ` _ . ~' ,.,~, _ d . i 1 gs -o~ ~l ~~ -~~ ~ ~~ ,~ ~ ~~ ~.~ • • U,: ALASS-A OII, AI~TD GAS COI~TSER~ATIOI~T CO1tII~IISSIOI~T MJ Loveland Well Integrity Project Supervisior ConocoPhillips Alaska Inc. ~;./,f~i~~~~;; ~.~~ ;' L ~~~, PO Box 100360 - SARAH rALIN, GIVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage AK 99510 ~ ~~ ~ ~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 2U-04 Sundry Number: 309-055 Dear Ms. Loveland: 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 Corrunission'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, Daniel T. Seamount, Jr. Chair DATED this ~g day of February, 2009 Encl. • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 14, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~G~~ ~/ E® FE~3 17 2009 Alaska Qit & Gas Gons. Commission Anchorage Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we112U-04 PTD 185-007 surface casing excavation and repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, i' ~< ~ ~ ;,s MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures .~% ~' A c~ STATE OF LASKA ([~ ALASKA OIL AND GAS CONSERVATION COMMISSION RGl.~~~ V FED 1 7 X009 APPLICATION FOR SUNDRY APP~E~P~-~~as Cans. Curnmis~6W~ 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other /^ Alter casing ^ Repair well^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ SC repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 185-007 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21270-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO ~ 2U-04 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25644 ALK 2575 RKB 105' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth Mo (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8020' 6149' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 3436' 9-5/8" 3541' 2998' 3520 2020 PRODUCTION 7988' 7" 8020.01' 6149' 4980 4320 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7500-7556, 7668-7730, 7795-7801' 5760-5802, 5885-5931, 5980-5984' 3-1/2" J-55 7629' Packers and SSSV Type: Packers and SSSV MD (ft) packer = Otis RRH Retr, Otis WD 7328, 7604' SSSV: Locked out 1900' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Perry Klein Printed Name MJ Loveland/ Perry Klein ~<. ° Title: Well Integrity Project Supvr. ;~~ ' . , . '~ '•} ` / , , ~ Signature ~ -rt;..--+ C------~ ,, ` Phone 659-7043 Date ~ f ~, ~ r Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~``l ~1 ~ GJC~kJt`~~~c'~~~`~V~CT~ ~~`L~. ~((` (Xe ~ APPROVED BY Approved b . COMMISSIONER THE COMMISSION Date: Form 10-403 Revd 06/20 ~ ~ I ~ ~ ~ ~ f ~ i Submit in plicate ConocoPhillips Alaska, Inc. Kuparuk Well 2U-04 (PTD 185-007) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02/14/09 This application for Sundry approval for Kuparuk well 2U-04 is for the repair of a surface casing ~ leak. The well is an injector and was drilled in June 1985 as a producer then converted in November of that same year. On 03/24/08 the DSO reported that positive pressure could not be maintained on the OA. The well was subsequently reported to the AOGCC with a suspected surface casing by conductor annulus leak on 3/25/08. Diagnostics confirmed a leak in the surface casing approximately 5 feet below the starting head. With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA as needed to remove all gas. Freeze protect the T and IA as needed. PT plug to verify barrier. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. ~~~- ~~r~~~~~G1"fir Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ ~~ 00 ~~ ~ ~ O ~~ Well Job # Log Description NO.4985 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11 /25/08 2V-07 12096561 INJECTION PROFILE - ~ 10/31/08 1 1 3A-11 12100434 INJECTION PROFILE - 10/31/08 1 1 1G-09 12100434 INJECTION PROFILE 3 ~ 11/01/08 1 1 2V-11 12061724 PRODUCTION PROFILE ~- ~ 11/02/08 1 1 2C-14 12096565 PRODUCTION PROFILE ~-~ - 11/04/08 1 1 30-01 11975792 LDL 3 11/05/08 1 1 3F-09 12100435 PRODUCTION PROFILE 11/06/08 1 1 2V-12 12096567 PRODUCTION PROFILE - (~ 11/06/08 1 1 3A-07 12096568 INJECTION PROFILE - 3 11/07/08 1 1 2A-20 12100434 INJECTION PROFILE • - 11/08/08 1 1 iG-17 11975792 LDL 11/09/08 1 1 2U-04 12100434 INJECTION PROFIL 11/10/08 1 1 2U-05 12096572 INJECTION PROFIL ~ ~ -' 11/12/08 1 1 iF-06 12100457 PRODUCTION PROFILE 11/13/08 1 1 1B-06 12080456 PRODUCTION PROFILE 11/13!08 1 1 iB-05 12080457 INJECTION PROFILE ~j 11/14/08 1 1 2U-10 12080459 PRODUCTION PROFILE 11/16/08 1 1 2C-15 12100462 PRODUCTION PROFILE L 11/18/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ • • • • 1 �_� SARAH PALlN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL 2B.032 Mr. Martin Walters Problem Well Supervisor ConocoPhillips Alaska, Inc. . P.O. Box 100360 � rte1 JUN �, 6' 20 1 i Anchorage, AK 99510 -0360 RE: KRU 2U -04 (PTD 1850070) Request for Administrative Approval Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission AOGCC or Commission) hereby grants ConocoPhillips ( ) Yg s p Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 2U -04 exhibits communication between the surface casing and conductor at approximately 5 feet below ground level. All positive pressure tests performed on the well's tubing, inner annulus (IA), and wellhead seals have passed since communication was first identified and reported in March 2008. The Commission finds that CPAI intends to pursue repair options and will make appropriate application if a viable option is available. The Commission further finds, based upon reported results of CPAI's diagnostic procedures and wellhead pressure trend plots, that KRU 2U -04 exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in KRU 211 -04 is conditioned upon the iulivwing: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 2B.032 • • June 9, 2008 Page 2 of 2 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 6. The MIT anniversary date is April 20, 2008. DONE at Anchorage, Alaska and dated June 9, 2008 oil, O� Cathy P Foerster Jo r, ' . No an Commissioner 'om oner O I 44 0N t:0 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t)he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • ConocoPh Alaska P.O. BOX 100360 A k ‘ ANCHORAGE, ALASKA 99510 -0360 of d �N ' as k 0 9 Oi1� 008 G 2 s May 31, 2008 co . Lar a ge - • Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 JUN 0 6 20l'i Dear Mr. Maunder: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 2U-04 (PTD 1850070) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue options to repair the casing leak. If a viable option is available, the appropriate paperwork will be submitted at that time. If you need additional information, please contact myself or Brent Rogers at 659 -7224, or MJ Loveland / Perry Klein at 659 -7043. Sincerely, Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 2U -04 (PTD 1850070) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with known annular communication for Kuparuk injection well 2U -04. Well History and Status Kuparuk River Unit well 2U -04 (PTD 1850070) was drilled and completed in February 1985 as a development well and was converted to a service well in November 1985. On 3/24/08 following application of positive gas pressure to outer annulus, diesel was discovered to be topping the conductor. The suspected surface casing leak was reported to the AOGCC on 3/25/08 and was determined to be at 64" on 4/11/08. Additional diagnostics performed on 03/30/08 and 04/20/08, confirmed production casing and tubing integrity with passing MITIA's to 3000 psi. Wellhead seal integrity was also confirmed on 06/01/08 based on passing tubing and inner casing pack off tests. Barrier and Hazard Evaluation Tubing: The 3.5 ", 9.3 ppf, J -55 tubing has integrity to the packer at 7340' MD based on a passing MITIA performed on 04/20/08. Production casing: The 7 ", 26 ppf, J -55 production casing with an internal yield pressure rating of 4980 psi has integrity to the packer at 7340' MD based on the MITIA described above. The well also passed an MITIA on 03/30/08 and a 4 year MITIA on 08/18/06. Surface casing: The well is completed with 9 -5/8 ", 36 ppf, J -55 surface casing with an internal yield pressure rating of 3520 psi. The surface casing is set at 3541' MD (2999' TVD). Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing it will be noted during the daily monitoring process. Any deviations from approved MAOP require investigation and corrective action, up to and including a shut -in of the well. T /IJO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. NSK Problem Well Supervisor 6/2/2008 • • Approved Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Inner annulus pressure not to exceed 2000 psi (40% internal yield) 3. Outer annulus pressure will be maintained as low as reasonably possible not to exceed 100 psi (3% internal yield) 4. Perform a passing MITIA every 2 -years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 5. Submit reports of daily injection volumes and tubing & IA pressures on a monthly basis; 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems; 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 6/2/2008 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; tom. maunder@ alaska. gov ;bob.fleckenstein @alaska.gov;doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2U -04 DATE: 04/20/08 OPERATOR REP: Greenwood /Phillips - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 2U -04 Type Inj. W ND 5,643' Tubing 2,325 2,325 2,325 2,325 Interval 0 P.T.D. 1850070 Type test P _ Test psi_ 1500 Casing 640 3,000 2,925 2,900 P/F P Notes: Diagnostic MITIA for AA OA 0 0 0 0 Well Type Inj. ND Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2U -04 04- 20- 08.xls • • KRU 2U -04 11:' ConocoPhillips Alaska, Inc. '2U -04 i _ API: 500292127000 Well Type: INJ Angle @ TS: 42 deg (7a 7502 SSSV Type: LOCKED OUT Orig 2/26/1985 Angle @ TD: 41 deg @ 8020 sssv - Completion: (1900 -1901, OD:3.500) Annular Fluid: Last W /O: Rev Reason: TAG FILL Reference Log: Ref Log Date: Last Update: 8/29/2005 Last Tag: 7803 TD: 8020 ftKB Ai N I Last Tag Date: 8/14/2005 Max Hole Angle: 48 deg (0 3900 Casing String - ALL S TRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 31 MOO SUR. CASING 9.625 0 3541 2999 36.00 J -55 PROD. CASING 7.000 0 7988 6125 26.00 J -55 Tubing String - TUBING Size Top Bottom TVD Wt Grade Thread 111 41111 3.500 0 7629 5856 9.30 J -55 EUE 8RD Perforations Summary Interval ND Zone Status Ft SPF Date Type Comment 7500 - 7556 5761 - 5802 C- 4,UNIT 56 12 3/19/1985 IPERF 5" Baker TCP III OM B 7668 - 7730 5885 - 5931 A -4,A -3 62 4 3/19/1985 IPERF 5" Baker TCP 7795 - 7801 5980 - 5984 A -2 6 4 3/19/1985 IPERF 5" Baker TCP Gas Lift MandrelsNalves 111 4111 St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2004 1900 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 2 3809 3194 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 a LSI 3 , 4985 3986 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 4 5549 4372 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 5 5995 4684 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 6 6403 4973 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 a Egli 7 6848 5288 Camco KBUG DMY 1.0 BK2 0.000 3/23/1985 8 7287 5604 Meda TPDX DMY 1.5 RM 0.000 5/8/1997 Injection MandrelsNalves St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Viv :;1111111 Mfr Run Cmnt 9 7376 5669 Meda TPDX DMY 1.5 RM 0.000 0 10/21/199 10 7448 5722 Meda TPDX CAMCO HFCV 1.5 RM 0.500 0 5/18/2004 11 7584 5823 Merla TPDX DMY 1.5 RM 0.000 0 8/1/1996 SBR (7328 -7329, , Other (plugs, equip., etc.) - JEWELRY OD:3.500) Depth ND Type Description ID 1900 1819 SSSV Camco TRDP -1A -SSA (LOCKED OUT 8/17/2001) 2.812 7328 5634 SBR Otis 2.810 PKR (7340-7341, 7340 5643 PKR Otis 'RRH' Retr 2.970 00:6.1 (7 D:s.151) 7604 5837 PKR Otis WD' 4.000 7620 5849 NIP Camco 'D' Nipple NO GO 2.750 7628 5855 SOS Otis 2.992 a OM 7629 5856 WLEG Otis WIRELINE RE -ENTRY GUID 2.992 7630 5857 TTL 2.992 AI Ow Perf __ (7500 -7556) NI PKR (7604 -7605, 00:6.151) NIP i I l (7620 -7621, 00:3.500) TUBING (0 -7629, — OD:3.500, 10:2.992) Perf _ (7668 -7730) — - Perf (7795 -7801) ,_ uoipefui ui - gnus HeM Jo eAA oT J8AUO3 elect 80 A 80 80 leW - l0 0 - 1 t 1 I I. ' I `.h ' .__ a \` — .....` 005 09 -- � 0001 c T 0001 r. ool ; o0az N i - 0 �1 ---�, ��-,, __ 000Z 1 08 r 1 — 0000 aanssaad JapeaH 6uisues Jeonpsu8al uo!T3GEul seo 009£ 00Z - ' I t , ' Po-nz - }OId ma dVO dVI 11d - ._..._. -- did y1OH3 Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, June 09, 2008 4:53 PM ~. ~~,~` To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Subject: RE: MITs for KRU 2U-04 (PTD 1850070) Attachments: MIT KRU 2U-04 04-20-08.x1s; MIT KRU 2U-04 3-30-08.x1s Jim, Here are the MIT's you have requested. The test data from 3130 was incomplete due to the tubing pressure was not documented during the test, and that is why it was re-tested on 4120. Please let me know if you need anything else. ._ Russ Colee ~~A-NNE®JUN 1 7 2008 Pws _. ._ _... From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, June 09, 2008 2:12 PM To: NSK Problem Well Supv Subject: MITs for KRU 2U-04 (PTD 1850070) Please submit MITs performed on 3/30 and 4/20 for the subject well Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 6/10/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~ ' 1 ( ~', if2'L~j FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Kuparuk /KRU / 2U-04 04/20/08 Greenwood/Phillips - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2U-04 ype Inj. W TVD 5,643' Tubing 2,325 2,325 2,325 2,325 Interval O P.T.D. 1850070 Type test P Test psi 1500 Casing 640 3,000 2,925 2,900 P/F P Notes: Diagnostic MITIA for AA OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal 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 O =Other (describe in notes) MIT Report Form BFL 11/27/07 2008-0420 MIT KRU 2U-04.x1s • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk !KRU / 2U-04 03/30/08 Greenwood - AES 5~(~43~ K~ y~~zs MITIA Packer Depth Pretest Initial 15 Min. 30 Min. Well 2U-04 Type Inj. N TVD Tubing SI SI SI SI Interval O P.T.D. 1850070 Type test P Test psi Casing 620 3,000 2,840 2,820 P/F P Notes: Diagnostic non-witnessed MITIA i~ OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Weil Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Gycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27/07 MIT KRU 2U-04 3-30-08.x1s 2U-04 Produced water injector PTD #185-007, notice of possible surface casing leak Page 1 of 1 Re James B DOA • • 9J, ~ ) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, March 25, 2008 2:24 PM To: Regg, James B (DOA) ~~~ ~~Z~~~a Cc: Maunder, Thomas E (DOA) Subject: 2U-04 Produced water injector PTD #185-007, notice of possible surface casing leak Attachments: 2U-04 90 day TIO.jpg; 2U-04.pdf Jim, 2U-04 Produced water injector PTD #185-007 is suspect of having a surface casing leak from either shallow corrosion or the casing head starter threads. ~- The operator attempted to charged the OA from the IA in and effort to keep positive pressure on the OA, to assist monitoring of surface casing integrity. After charging the operator noticed a damp area of diesel on the tanko top. T/I/O = 1050/800/0 Immediate action will be to shut in the well and freeze protect the tubing / flowline. DHD will begin diagnostics as soo csan ellar gravel is removed and a pit liner is installed.. `~ The. most recent MITIA was on 8!18/06. The IA was tested to 2460 psi and passed. We will contact your office with the results of the diagnostic test as soon as they are complete. I've enclosed a schematic and 90 day TIO plot for your convenience. Let me know if you have any questions. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 «2U-04 90 day TIO.jpg» «2U-04.pdf» ~;~ MAY ~ ~ 2008 4/24/2008 KRU 2U-04 PTD 185-007 • • i~~ C onc~coFh`rl~ps A1as~Ca, 1n~. -- - 2 U-04 API: 50029212 sssv r SSSV Type: LOCKED (1900.1901, ~ OD:3.500) v "` AMUIar FIUId: SBR (7328-7329, OD:3.500) PKR (7340-7341, OD:6.151) Perf (7500.7556) PKR (7604-7605, OD:6.151) NIP psza7sz~, OD:3.500) TUBING (0.7629. OD:3.500, ID:2.992) Perf (766&7730) • KRU 2U-04 TS: 42 d 7502 --Ji @ TD: 41 deg @ 8020 •. I Last Tag Date: ~ 8/14/2005 ____ I Max Hole Angle: 148 dera (c~ 3900 I Casing String -ALL STRINGS __ - Descri lion Size To Bottom ND Wt ~ G , -- rade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 ~ ~ -~ SUR. CASING 9.625 0 3541 2999 36.00 J-55 - ~ ' . t PROD. CASING Tubin Strip- TUBING - -- Size To 7.000 0 .Bottom D 7988 Wt 6125 ?6.00 Grade J-55 Thread ~ ~ 3.500 0 7629 5856 9.30 J-55 EUE SRD ~` ~ __ Perforations Summar~~ Interval ND Zone Status Ft SPF Date T e _ Comment ~~ s' ~ 7500 - 7556 5761 - 5802 C-4,UNIT B 56 12 3/19/1985 IPERF 5" Baker TCP 7668 - 7730 5885 - 5931 A-4,A-3 62 4 3/19/1985 IPERF 5" Baker TCP ;. ®~. ~~~~ 7795 - 7801 5980 - 5984 A-2 ----- - - Gas Lift Mandrels/Valves - --_ St MD ND Man Man Type V Mfr Mfr 6 4 3/19/1985 IPERF Type V OD Latch Port 5" Baker TCP _ _ TRO Date Vlv Run Cmr 1 2004 1900 Camco KBUG DMY 1.0 BK2 0.000 0 3/23/1985 2 3809 3194 Camco KBUG DMY 1.0 BK2 0.000 0 3/23/1985 ~~ ~ _~ 3 4985 3986 Camco KBUG DMY 1.0 BK2 0.000 0 3/23/1985 . 4 5549 4372 Camco KBUG DMY 1.0 BK2 0.000 0 3/23/1985 5 5995 4684 Camco KBUG DMY 1.0 BK2 0.000 0 3/23/1985 6 6403 4973 Camco KBUG DMY 1.0 BK2 0.000 0 3/23/1985 -~ ~ ~ . ~ n 7 o 6848 ~~e~ 5288 rr_n Camco u__i_ KBUG DMY ns 1.0 i t BK2 0.000 n nn 0 3/23/1985 ] __ -~ Injection Mandrels/Valves St MD ND l Man Man Type V Mfr V Type Mfr V OD Latch Port ~ TRO Date Run __ _ Viv Cmn 9 7376 5669 Merla TPDX DMY 1.5 RM 0.000 0 10/21/199 10 7448 5722 Merla TPDX CAMCO HFCV 1.5 RM 0.500 0 5/18/2004 "- 11 7584 5823 Merla TPDX DMY 1.5 RM ~- ----- Other 'lu s e ui - _~, q p., etc. JEWELRY De th ND T e Descri lion 0.000 0 8/1/1996 D 1900 1819 SSSV Camco TRDP-IA-SSA LOCKED OUT 8/17/2001 2.812 7328 5634 SBR Otis 2.810 7340 5643 PKR Otis'RRH' Retr. 2.970 7604 5837 PKR Otis'WD' 4.000 7620 5849 NIP Camco'D' Ni le NO GO 2.750 7628 5855 SOS Otis 2.992 ~ ~ ~ 7629 5856 WLEG Otis WIRELINE RE-ENTRY GUID 2.992 ' ' 7630 5857 TTL 2.992 ~. ,.; ff .la,,,.. ~> ~~ ... I Perf (7795-7801) ( f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test (c!t(1 b -vo jC4 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 2U-04 06/22/04 Rogers I Sauvageau \c¿5 ~()D 7 Well\2U-04 I Type Inj I S P.T.D.1850070 Type Test P Notes: Diagnostic test weill \ Type Inj I P.T.D. Type Test Notes: weill I Type Inj I P.T.D. Type Test Notes: weill \ Type Inj I P.T.D. Type Test Notes: weill \ Type Inj I P.T.D. Type Test Notes: Test Details: TYPE INJ codes F = Fresh Water lnj G = Gas Inj S = Salt Water Inj N = Not Injecting M1T Report Form Revised: 05/19/02 Packer Depth Pretest Initial 15 Min. 30 Min. I T.V.D. I 5643 I Tubing I 11601 11601 11601 11601 Interval \ 0 Test psi 1500 Casing 1060 3000 2950 2940 P/F P OA: 80 I 80 I 80 I 80 \ T.V.D. I \ Tubing I I \ \ \ Interval \ Test psi 1500 Casing P/F I T.V.D.I I Tubing I I 1 I Intervall Test psi 1500 Casing P/F \ TV.D. I \ Tubing I I I I \ Interval I Test psi 1500 Casing P/F I TVD. I I Tubing I , I , \Interval Test psi 1500 Casing P/F TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = other (describe in notes) 2004-0622_M IT _KR U_2U-04.xls 6/28/2004 MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Commissioner P.I. Supervisor Jeff Jones Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 2U Pad 2U-03, 2U-04, 2U-05, 2U-16 KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. 1850060 IType testI P Test psi 1500 Casing 1350 2400 2360 2350 P/F P Notes: Test fluid 2 BBLS diesel I ool,nt a,I P.T.D. 1850070 TypetestI P Test psi 1500 Casing 1150 2450 2390 2360 P/F ?_P Notes: Test fluid 2 BBLS diesel I P.T.D. 1850180 Type testI P Test psi 1500 Casing 1550 3200 3050 3025 P/FI ~P Notes: Test fluid 4.3 BBLS diesel WellI 2U-16 ITypelnj. I S I T.V.D. I 5617 Tubing 2750 2750 2750 2750 Intervall 4 P.T.D. 1842490 Type testI P Test psiI 1500 Casing 675 3500 2000 1150 P/FI _F OA 600 1860 1800 1100 Notes: Test fluid 3.1 BBLS diesel. 3 casing hanger Iockdown leaks at packing glands were repaired. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval i= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) May 14, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAl) water injection wells 2U-03, 2U-04, 2U-06 and 2U- 16 to witness 4 year MIT's. Jared Break was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with wells 2U-03, 2U-04, 2U-05 passing their MIT's. When the inner annulus of well 2U-16 was pressured up the outer annulus pressure also rose, exhibiting IA/OA communication and this well failed the MIT. It appears that well 2U-16 wellhead pack-off is leaking. CPAI Problem Well Supervisor MJ Loveland indicated diagnostics and repair of this item would begin within 24 hours. Four well house inspections were also conducted with three exceptions noted. Three casing lockdown screws were leaking at the packing glands on well 2U-16 and were immediately tightened, stopping the leaks. Summary: I witnessed successful MIT's on CPAI's water injection wells 2U-03, 2U-04, and 2U-05 and a failed MIT on well 2U-16 in the Kuparuk River Field. Four well house inspections conducted, three exception noted. M.I.T.'s performed: 4 Number of Failures: 1_ Attachments: wellbore schematics (4) Total Time during tests: 3 hrs cc: MIT report form 5/12/00 L.G. 2003-0514_M IT_KR U_2 U- 16_jj.xls 5/19/20O3 ARCO Alaska, Inc. Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Wel ! Action Date Performed 1L-1 Convers 1L-7 Convers 1Q-2 Convers 1Q-7 Convers 1Q-11 Convers 1Q-13 Convers 2B-5 Convers 2B-9 Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D-2 Convers 2D-7 Convers 2D-11 Convers 2D-14 Convers 2F-1 Convers 2F-2 Convers 2F-13 Convers 2F-14 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers on on on on on on on · on · on on on on on on on on on · on · on · on · on on · on · on · on · on · on on · on · on on on on 11/1 11/1 11/1 11/1 11/1 11/1 11/2 11/2 11/1 11/1 11/1 11/1 11/2 11/2 1112 11/2 11/2 1112 11/2 11/2 11/1 11/1 11/1 1111 11/1 11/1 11/1 11/1 ~1/1 ~1/1 11/1 11/1 11/2 8/85 8185 7/85 7/85 7/85 7/85 3/85 3/85 9/85 9/85 9/85 9~85 O/85 0~85 0/85 0/85 1/85 1/85 ~/85 1/85 4/85 4/85 4/85 4/85 4/85 4/85 4/85 R[CEIV[D 6/85 6/85 3AN.SQ.III 6/85 5/8,~ 0il& Gas Con~ 2/85 ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 85-7 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 270 9. Unit or Lease Name 400' 1052~ FWL, Sec. 32, KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCAT ION- FSL, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 05 ' (RKB) 6. Lease Designation and Serial No. ADL 25644, ALK 2575 10. Well Number 2U-4 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 16, 1985 Kuparuk well 2U-4 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into "A" sand. the RECEIVED 20 198G Alaska 0il & Gas Guns. C0mmi3:.' .... 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~,/~ C~,/~ Title KUPARUK The space below for Commission use OPERAT ION$ COORD! NATOR Date 1 2 / 1 8 / 85 .. 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 ARCO Alaska, Incf~--~, Post Offic( .x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-22-85 T~J~NSMITTAL NO: 5410 RETURN .TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING · " kECORDS CLERK . ATO-1115B ' -- ..... ' P.O. ~OX 100360 ' ANCHORAGE, AK 99510 - ~ TRANSMITTED }{ER/~4ITH AKa-' T~ FOLLOWING IT~l$. ' RECEIPT~ AND RETURN ONE SIGNED COPY OF THIS' TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE * OF EACH CEMENT~ BOND LOG/ VAKIABLE :~3B-8 '- ~42X-15 · '~2X-13_ '~ 2X- 12. '~2X'11 '~2X-10 '~ 2X-9 '~ 2W-6 DENSITY 06-06-85 RUN #1 5850-8369 11-07-.84 RUN ~1 5900-8258 11-17-84 ~i RUN #1 5896-8410 12-08-84 ', RUN #1 3050-7215 12-08-84 ' }{UN #1 3100-6370 12-21-84 kUN #1 3350-6973 12-20-84 PJJN ~1 5100-8338 11-25-85 RUN ~1 5700-7290 06-06-85 06-07-85 06-03-85 04-02-85 '~ 2V-16 . "'~ 2V- 15 ~' 2V-13 ::i: '-~2U-8 .'::_::j.:: ~2U- 7-/~:~i_ 04- 01- ~ 5 ~ 2U-6' ~:~::: 03-31'85 * ~au- 5;:~(.:/~. 04-0 ~- 8 5 '-~2u-4:':-'? 03-02-85 '~2D-16.: :'~ 12-19-84 "% 2D-15 ~:~:~~ 12-18-84 : RUN -': RUN · RUN -..'RUN. --l-tUN .:--:~: -.:<UN- .'::;-: ~UN: kUN- :'~2D-l:...:, 11-03-84 RUN # · "~lR-8 ..... '- 06-17-85 I~UN ~ '"'IR-7.:-. 06-08-~5 - RUN # "~JIR-5 .- : 06-08-85 - RUN ~'~lL-15 . :i'. 11-05-84 RUN lQ-15 (:' 05-27-85 RUN- '~'~lQ-3 :::.' 04-17-85 ' RUN %CPF-1A 12-21-84 ~{UN CEMENT EVALUATION YOOL 1F-'16 - 03-12-85 RUN ~la-5 !:?~i:?~i 06-26-85 ' RUN' ~lR'5 ::::~:.:: 06,27-85-'. ~' RUN ~2U-2'.J:':'::~:~:: 03-25-85"' -' kUN '~2U-15 :.': .03-07-85 . ~UN "~3B-9 ::":.:? 06-30.85 RUN '~3C-11.:::: 06-29~85 :' RUN ~3C~12 :.:--':: 06-29-85~ RUN :::..- ::7-:: :~7: .:- : .... . ~CEIPT ACKNOWLEDGED: 1 1 1 . 1- . . 1 - 1' ' 1 1- 1 #1 LUGS #1- #1' _#2 ~1 ' #1 #1-' 4550-710~ 4650-6428 6590-8553 4970'6938 0070-8122 5600-8107 5994-9161 6284-7850 5200-7469 3285-6454 5693-6652 5987-8324 4302-7028 6950-8628 .. BPAE B.. CURRIER CHEVRON.- D & M.:-:--'. -. _ ~ _ · .-.- .:. DRILLING*BL '"_ . L._ JOHNSTON. mOBIL- ''' NSK CLE~K*uL PLL.'AS~ ACKNOWLEDGe: 4883-660U 6490-7566 . '- 897~-10744 2200-3856 _ Ck24ENT ~VALUATION LOGS 8269-8712 6974-8~44 8254-8532 5790-9450' 6400-7002' 6000-8246 6500-8726 5400-7457 W. EXXON PHILLIPS OIL J. RATH~ELL" .. · so~:o . .- ........ .7 su~:. .- UNION VAULT/~'O* FIha - _ ARCO Alaska. Inc. is a Subsicliary of AtlanticRichfielcJCompany ARCO Alaska, Ino~-''~. Post Offic~ ax 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED 0, ~ ro~s Co~,s. Commission. ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASK/~IL AND GAS CONSERVATION ¢-'MMISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. see attached 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- see attached OTHER [] 4. Location of Well N/^ 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. I 6 . Lease Designation and Serial No. see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River 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 [] [] Other ~ Pulling Tubing [] Pull 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). Pursuant to form 10-403, it is proposed that the attached list o producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. sEP 2 o 19" 5 AlasKa Oi) & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,/¢~'~/~ ~,~_~'~,-'~---~ Title Kuparuk Operations Coordinator Date. 9/18/85 The space below for Commission use Conditions of Approval, if any: Form 10-403 Rev. 7-1 ~0 ^pprove~i Co~y .J~.oturrte~ / By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 8O 85 106 128 132 85- 6 7 2O 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 25658 25657 25656 25644 25643 25655 25644 !! 25655 25642 !! 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 '! 12/15/85 " 10115/85 2584 12/15/85 " 12/15/85 '! 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 '! 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 -tECEIVr_u/ s/ s _- ARCO Alaska, Inc. Post Office B,.,,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports. Dear Mr. Chatterton: Enclosed are the Well Completion Reports for the following wells: 2U-4 2U-6 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L59 Enclosures RECEIVED JUL 2 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ' STATE Of ALASKA .- ALASKA _ _AND GAS CONSERVATION CC ,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL C~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-7 3. Address" 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21270 4. Location of well at surface 9. Unit or Lease Nam; 400' FSL, 1052' FWL, 5ec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval '~'0. Well Number 1361' FSL, 1194' FWL, Sec.5, TllN, R9E, UM 2U-4 At Total Depth 11. Field and Pool 1014' FSL, 1191' FWL, Sec.5, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 031 Pool 105' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 02/19/85 02/25/85 02/26/85*I N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8020'MD,6148'TVD 7906'MD,6062'TVD YES I-~IX NO []I 1900 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SP/GR, FDC/CNL, Ca1, Gyro, GR/CCL/CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 230 sx CS II (Approx) 9-5/8" 36.0# J-55 Surf 3541' 12-1/4" 725 sx PF "E" & 725 sx PF "C" 7" 26.0# J-55 Surf 7988' 8-1/2" 295 sx Class G & 250 s~ PF "C" 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) 7500' - 7556' w/12 spf, 120° phasing 3-1/2" 7629' 7604' & 7340' 7668' - 7730' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7795' - 7801 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addel~durn, dated 5/2/85. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIo TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 2'8. CORE DATA NONE Alaska 0il & Gas Cons. C0rr]rnJssJon Anch0ra0e Form 10-407 * NOTE: Tubing was run and the well perforated 3/23/85. GRU10/WC08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. :~i?:'~'~i ~' :;;' ::i -2:': (~'i~o L_O~-{0-:.~R~~ ¢~:;::T~:: ~:'~:t:~:~..~i:¥... ;?'~::,~..~-:.,7':.:7 :~;:: F(~; :r :":)'~5~R~'~'i"~N'~EST~-':,: '"~' . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7498'. 5758' N/A . Base Upper Sand 7550' 5796' . Top Lower Sand ' .-7646' 5867' " ~: ~. Base Lower Sand 7809' 5989' . . , ... , . ~ ;' . . ,. . : - , . . . ... . . . . .. . ; : . : ; ' 31. lIST OF ATTACHMENTS - ..... ~:.: - AdHendum ' · · '. -. 32. I hereby ~ertify that the foregoing is true and correct to the best of my knowledge Signed 4~ ~ Title Assooia~e Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases, in. Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent t° such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". - , ADDENDUM WELL: 2/28/85 4/23/85 2U-4 Arctic Pak w/250 sx PF "C", followed by 58 bbls Arctic Pak. Frac'd well in 8 stages w/total of 323 bbls gelled diesel, 700# 100 mesh & 15,830# 20/40 mesh. RECEIVED Alaska Oil ~ G~s Cotj~. Commission Drilling ~uperintendent Date /~.RCO Alaska, Inc. ~ Post Office Bo,, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 28, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 2U-4 2U-14 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU10/L33 Enclosures RECEIVED J U L 0 2 19tl5 ,!~as..,a 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · ' ~--. STATE OF ALASKA ALASKA~. .AND GAS CONSERVATION CC AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-7 . 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21270 4. Location of well at surface 9. Unit or Lease Name 400' FSL, 1052' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 101 Well Number 1361' FSL, 1194' FWL, Sec.5, TllN, RgE, UM 2U-4 At Total Depth 11. Field and Pool 1014' FSL, 1191' FtNL, Sec.5, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 105' RKB ~ ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/19/85 02/25/85 02/26/85* N/A feet MSL 1 17, Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set {21.Thickness of Permafrost 8020'MD,6148'TVD 7906'MD,6062'TVD YES I-~X NO [] 1900 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SP/GR, FDC/CNL, Cal, Gyro, GR/CCL/CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 230 sx CS II (Approx) 9-5/8" 36.0# J-55 Surf 3541' 12-1/4" 725 sx PF "E" & 725 sx PF. "C" 7" 26.0# J-55 Surf 7988' 8-1/2" 295 sx Class G & 250 s~ PF "C" , 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) 7500' - 7556' w/12 spf, 120° phasing 3-1/2" 7629' 7604' & 7340' 7668' - 7730' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7795' - 7801' 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 OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ ' I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c0rr) 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 .r~, J U L 0 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing run and the well perforated on 3/23/85. JMM2/WCS0 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · _. _. . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS: DEPTH TRUEVERT. DEPTH : ~GOR, and time of each phase. -. Top Upper Sand 7498' 5758' N/A .. _ Base UPper Sand 7550' 5796' Top Lower Sand -7646' 5867' Base Lower Sand 7809' 5989' . . 31. LIST OF ATTACHMENTS. . · Well History-(completion) 32. I hereby ce[tify that the foregoing is true and correct to the,bes~ of my knowledge Signed ~6~~ ~ Title Ass°el ate Engi neer 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- 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". ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit Ihe "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish I State Alaska North Slope Borough I Alaska Field Lease or Unit I Well no. Kuparuk River ADL #25644 I 2U-4 Auth. or W.O. no. Title AFE 603619 Completion WWS #1 API 50-029-21270 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun J Date Comp letion I 3 / 20/85 Date and depth Complete record for each day reported as of 8:00 a.m. 3/21/85 3/22/85 3/23/85 I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our J Prior status if a W.O. I 0200 Hrs. 7" @ 7988' 7906' PBTD, Pmp BridgeSal pill 10.0 ppg NaC1/NaBr Accept rig @ 0200 hrs, 3/20/85. RIH w/TCP guns, set pkr, drop bar & flow to tst tank. Pmp BridgeSal pill & kill well. 7" @ 7988' 7860' PBTD, RU to rn GR & pkr 10.0 ppg NaC1/NaBr Kill well w/BridgeSal pill & 10.0 ppg-brine, POH w/guns. RIH w/bit & scrprs to 7848', circ, POOH. ND flow nipple, NU perf flange. 7" @ 7988' 7860' PBTD, Setting BPV 10.0 ppg NaC1/NaBr RU & rn 6.125" GR/JB. Rn perm pkr @ tail pipe assy. Set pkr @ 7588' WLM. Rn 237 jts, 3½", J-55 9.3# EUE-8RD IPC tbg &lnd. Set pkr, tst tbg to 2500 psi. Tst ann to 2500 psi. ND BOPE. NU & tst tree to 5000 psi. Displ well w/30 bbls diesel, followed by crude. Tst SSSV. Shear out ball. Set BPV. RR @ 0600 hrs, 3/23/85. SSSV @ 1900' Perm Pkr @ 7604' Pkr @ 7340' "D" Nipple @ 7620' TT @ 7629' Old TD Released rig 0600 Hrs. New TD Date 3/23/85 PB Deplh 7860 ' K nd of r g Rotary Classifications (oil, gas, etc.) O'f[ Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production 0,, on test ~l~s~ml, er~day~_ I ~/ ~ ".-. m.. I V Pump size, SPM X length Choke size T.P. C.P. Water % CDR correctedGravity Allowable ~Ldeg_~_~ 3~ Alaska 0~1 & Gas Cons. The above iS correct __ _ 4/11/85 For form preparation and distribut~n. see Procedures Manual, Section 10, Drilling, Pages 86 and 87. D 5 ,ornmlsslor, Drilling Superintendent ARCO Alaska, Inc. Post Office Box ,d0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-4 Dear Mr. Chatterton' Enclosed is a copy of the 2U-4 Well History to include with the Well Completion Report, dated 03/26/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L79 Enclosure cc' 2U-4 Well File RECEIVED 0[I &/.,,.,..~G?,.s .. Cons. Commission , h ,, t(tFP ,~1~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and GaS Company Well HiStory - Initial Report - Daily Instnmlfona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 603619 Doyon 9 Operator ARCO Alaska, Inc. ICounty, parish or borough North Slope Borough ILease or Unit ADL 2S644 Drill IState API 50-029-21270 Spudded or W.O. begun Spudded Date and depth as of 8:0~ a.m. 2/20/85 2/21/85 2/22/85 2/23/85 thru 2/25/85 I Hour 2/19/85 Alaska IWell no. 2U-4 Complete record for each day reported 2300 hrs. 16" @ 115' 900', (900'), Drlg Wt. 9.4, PV 12, YP 21, PH 9.0, WL 10.8, Sol 8 Accept rig @ 1930 hfs, 2/19/85. NU diverter sys. 2300 hfs, 2/19/85. Drl 12¼" hole to 900'. IARCO W.I. Prior status if a W.O. Spud well @ 56.24% 16" @ 115' 3560', (2660'), Short trip f/csg Wt. 9.3, PV 13, YP 21, PH 9.0, WL 9.8, Sol 8 Drl & surv 12¼" hole to 3560', short trip to rn 9-5/8" csg. 856', 3.3°, S2.5W, 855 TVD, 3 VS, 38, OW 1251', 15.8°, S1.2W, 1244 TVD, 67 VS, 688, 9W 1558', 27.5°, S .SW, 1530 TVD, 178 VS, 1798, I0W 2060', 42.2°, Sl0;2E, 1939 TVD, 465 VS, 4658, 24E 2819', 44.9°, S 7.7E, 2476 TVD, 997 VS, 9938, 104E 3344', 43.1°, S 9.5E, 2854 TVD, 1361VS, 1353S, 159E 9-5/8" @ 3541' 3560', (0'), Drlg cmt & flt equip Wt. 8.7, PV 5, YP 6, PH 8.5, WL 6.8, Sol 3 Fin wiper trip, circ hi-vis sweep. RU & rn 82 jts, 9-5/8", 36#, J-55 HF-ERW BTC csg w/FC @ 3455', FS @ 3539'. Cmt w/725 sx PF "E", followed w/725 sx PF "C" w/.65#/sx PF retarder. Displ using rig pmps, bump plug. CIP @ 1900 hrs, 2/21/85. Tst csg to 1500 psi; OK. ND diverter sys, NU & tst 11", 3000 psi csg head. RIH w/BHA, tag cmt @ 3455'. 9-5/8" @ 3541' 7970', (4410'), Rm'g tight hole Wt. 10.1, PV 13, YP 11, PH 9.5, WL 4.2, Sol 13 Drl cmt, FS + 10' new hole to 3570'. Conduct formation tst to 11.5 ppg EMW. Drl & surv 8½" hole to 7970', short trip, POH. RU & rn OHL; DIL/SP/GR/CAL f/3539'-7966', FDC/CNL f/7300'-7966'. RIH to 7684', rm to 7953'. vs, 4786', 47.5°, S 1.SE, ~878 TVD, 2399 VS, 2388S, 246E 5747'' 45'5°' S '5E' 4537 TVD' 3097 VS' 3087S' 246E ~[J~:~o]/~%~ · 6214', 44.7°, S .SE, 4866 TVD, 3428 VS, 3418S, 250E ~$ka OE 7148', 43.7°, si .2E, 5532 TVD, 4082 VS, 4073S, 259E 7510', 42°, S .8E, 5797 TVD, 4328 VS, 4319S, 264E AnCho~go' Comm~sion Cco' The above is correct Signature For form preparation and dls~l'butlon, see Procedures Manual, Sectgon 10, Drilling, Pages 86 and 87. 3/21/85 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final. Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after alJowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the enlire operation if space is availabJe. District ~County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth or W.O. no. ~Title I AFE 603619 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 2/26/85 Date and depth as of 8:00 a.m. 2/27/85 tA.R.Co. W.I. Date Complete record for each day reported North Slope Borough Accounting cost center code State Alaska ADL 25644 IWell no. 2U-4 Drill AP1 50-029-21270 rTotal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% Jabandonment of this well I IHour J Prior status if a W,O. 2/19/85 / 2300 hrs. I / 7" @ 7988' 8020', (50'), Instl Xmas tree Wt. 10.1, PV 13, YP 10, PH 9.5, WL 4.2, Sol 13 Drl 8½" hole to 8020', POH, LD DP. Rn & lnd 199 jts, 7", 26#, J-55 BTC at 7988', FC @ 7906'. M&P 295 sx C1 "G" w/l% CFR-2, 5% KC1, & .3% Halad-24. Displ w/brine, bump plug. CIP @ 2315 hrs, 2/25/85. Tst csg; OK, flts held. Had good circ through job. ND BOPE, set slips, cut 7" csg, instl pack-off & NU tbg head. 7" @ 7988' 7906' PBTD, RR Fin NU tbg head, tst pack-off; OK. RR @ 0800 hrs, 2/26/85. Old TD New TO Released rig Date 0800 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data I PB Depth IKind of rig 2/26/85 I Type completion (single, dual, etc.) Single 7906 PBTD Rotary Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AIIo~==,=-~ date corrected~,~ The above is /~J~ ~ JDate 3121185 Signature · JTiUe For form preparation and distribu~on, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-03{30 Telephone 907 276 1215 DATE: 05-2 9-8 5 TRANSMITTAL NO: 5199 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK · ATO-!llSB P.O. BOX 100360 A~HORAGE, AK 99510 T]L\NSMITTED I]EREWITIi ARE TiIE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK ~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-$ 03-21-85 2G-12 03-23-85 2t!-13 04-26-85 21~-14 04-28-85 2}I-15 04-29-85 2U-i 04-11-85 2U-2 04-11-85 2U-3 04-11-85 2U-4 04-11-85 2U-5 05-02-85 2U-6 05-03-85 2U-7 05-04-85 2U-8 05-04-85 2U-13 03-09-85 2U-i4 03-21-85 2U-!5 03-20-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 ~ ~- 0~ ~-13-85 2X-! 04-14-85 2X-3 04-13-85 2X-13 03-30-85 t-ltl m'r I l o.A~xC- C SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STA~¥C-'A' SAND STATIC-'A' SAND S TAT iC STATIC-'A' & 'C' SAND STATIC-'A ' &'C ' SAND STATIC-'A'&'C' SAND STATiC-'C' SAND STATIC-'C' SAND STATIC-'A ' &'C ' SAND STATIC-'A' SAND STATIC- 'A ' &'C ' SAND STATIC-'A' & 'C ' SAND PBU-'A' SAND :',ECEIPT ACKNOWLEDGE D: CURRIER* M* DRILLING m -~',~ ~,~c m~ MOB I L * ~,~SK CLERK DISTRIBUTION: EXXON PHILLIPS OIL* J. RATHMELL* ARCO.Alaska. Inc. Pos! Office box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 D ir., 1' [: ' () 5 - 0 7 -',., ::~ '.5 TRAN.S'MI 'T'[AL_ N.O · [5 f -76 I:;~['ZTUF:N TO ~ '¥ F,' A N,~ M I T '1' r:-' D R[:CEIF'T AND ARCO AI..A3'I< A, A T T N: I:;: E C 0 F;.' b 5' C I... Ii:' I:;,' K I::'.[). BC) X ~0':')36(') ANCHOI:;:A(;E, Al( 995 H Iii: I:;: [.:. W I 1' I-I A R E 1' I"1 Ii.'-. 1::' U L.. I... 0 W I N G R E" T IJ R N 0 N t:7. 5' I (; N E D C 0 F' Y I ] E~ bi 5-'. .... :~ 3' E A I:: I< N 0 W L_ I:: ]) G Iii: 0 F: T I--I I .Z T F,: A N.'.'-;' id I T T A L, F:' ]: N A I._ F'R I N ]' OF'EN HOI_E/5'CI"IL:L!M BE R G E I:~ '? W-- 4 5" I) ]: I_ / 3' F L - G R 0,-_ ''~ - .-.. '~ ,_,c~ ._ ,.,(:~ ':_, R LJ N ~: 1 S.. ,~. ''~ '";_. '? -' 7487 ,-~" D I I._ / 5' I-- L - (; F;.'. ~" ,-_ '~ -. '";:. 8 - "c! 5 I;: U N :~: 'i :'5257 - 7 '187 5" l) E: N / N I:: t.I -- G R ( P 0 I:i' 0 ) 02-" 2 iii -'-85 R U N ~'- ~ 58 '_"50 -' 74 (? 0 ~: I) E N / N I.:.: U-' G I:;~ ( F' 0 R 0 ~ ,32--- '~ o 85 R LIN '.?.: ~ · .-..,.,- .:>d :~ 0--, 490 5 · l) F: N / N E: U- G R ( R A L,J ) 02 -' 28 - 85 R U N ~'- 1 3 -."~" D E N./N I: lJ -" (} R ( I:;~ A I/J ) O '-~-.. - ''~;_ .'3-- 8 _,~ R U N ,~ .... t CYBERLO01( ,_,~"~-"~c~--8.5.... .-_,_, RLJN ,,.'"'t ~r2-5 5" I)IL/SI.--L 03--()7-85 RUN 9t 2" I) ]:l_/SFll 03-07-85,; RUN 5 · FDC/CNI_/GR (F'OI::,'[)) 03-07-85 RLIN .~¢'i 2" ' FDC/CNL/fiR (F:'OI:;:O) 03-'07--8_r5 RUN 5" F D C / C N I / (., R ( F;: A ~o ) ;; -, _. ~, -;_ c ,- [j .......... ~ ~ ..... !.) R N :,",,i 2" r.:'DC/CNI.../GR (RAW) 03 .... 07-8!5 RUi'-,~ ~l:i C Y Ii{E I:;,'L 001< 03-08-8!5 RLIN ARCO Alaska, Inc. Post Offic ~x 100360 Anchoragt., .,laska 99510-0360 Telephone 907 276 1215 DATE- APRIL i9, i985 TRAN,~MITTAL NO' 5i47. P A 6 ES RETURN TO: AF-.:CO ALA;.,TKA, INC ATTN- REF.;ORI)S C[_ERI< ATC) .... t i i YB F'.C). BOX f00360 A,UCHORAOE, Al( ;795t TR,'s,N,¢~.T. 7'TE!.)'--~F F'!._ ~' * .... NOI,J/.EDG .. ,,.:_F:FIJZTH ARc 7'I--I= FO[_LFII, IIN6 ITEMS ,=m..:.E. ACI< -.. -,. . L_ :' ....... · .. F:.'EC..i:-ZIPT Ai~D RETURN Oi'~.FSIGNED COF'Y OF THIS TI=4AN£HI'f'TAL· ,:;"='f-'.~ ~m~;CE OF EVENT?' tE-3 'A' YAN. D FRAC-GELLED WATEF~ 4m m ,~TATTC BI-IF' i Y-I t F'SU I Y- f f F'B[J ...... I" '--; L~ 2X-t .T. F'BU i ,m -- ~ r.., BI J f~-2 (;ELI_ED I.,,!ATEN FRAC ! G-t HYDRAULIC FF'.P-.,.C IL-t6 POST FRAC TEHP LOGS '7 r-,,- t ~,, F'BU '-'r',- I 5 F'B:I 2Z-6 ~TATIC r-;14 F' i E--f 2 F'BU ~b-~.:. ,' F'T:U ~'~' El_LED T i E--';- G WA ER BATCH FRAC ~E--'29 POST FRAC TEHF' LOG 2W ..... I ;TATIC BHF' ..~_/-: ,,..i IE-i6 INJECTIV!TY TEST iSIP 2U-4 ~-,,--, '~ T I C SI-iF' 2 U - ~ B H F' --,I ,_.o I?,_iF_, · m~ l- i .-.-_ ,...- .~,, .. ='~=_. ..... i ._. ~'' F'BU iE-i6 F'O;T FRAC TEHF' LOG F, I , 2X- i '~F-f,_, ~ POST I=RAC TEl'iF' LOG_: iF .... f-6 HYD. FRACTURE ~_r --:' F'BU 2F-7 F'BU 413/85 4/3/85 / ~. / Q .J 4/f -2/85 5/3 t/8~ 4/t 4/2/8~ 4/9- t 4/7-8/8~ 4/8,/8~ 4/i t -t 3185 4/t t -i 4/i ~',' , · .' '85 4/t '~ 4/i 3/85 4/t 3/85 4/t 4/t t/85 4/~ ~/0¢ 4/t 2/S5 ~/t 4/t 4-t ~/~ 4/t ~/'~'~ 4/~ 41t S-t ,1185 . 4/i ,I-i 5/85 F,'E[;'E IF'T ACI< HOWLEDEED - BF'AE B., CURRIER CHEVROns' DISTRIBUTION.: DRILL!N(.:.. W, F'ASFIER L, ,JOHNSTON EXXON MOBIL F'HILL IF'S OIL NSK CLERK J, RATI--IMELL ARCO Alaska, Inc. i~ a Subsidiary ct AtlanlicRichfieldCompany · '. 0 I"1 ]; 0 UNION I< ,~t][_ I N/':,'A UI_ T ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 4, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2U-4 Dear Mr. Chatterton- Enclosed is an addendum to the 2U-4 Well History to include with the Well Completion Report dated 03/26/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L92 Enclosure RECEIVED APR 0 9 19 5 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ADDENDUM WELL: 2/28/85 2U-4 Arctic Pak w/250 sx PF "C", followed by 58 bbls Arctic Pak. Drilling' S~fperintendent RECEivED .Alaska 0ii & Gas Cons. Commission Anchorage Date , . , ARCO Alaskal Inc." .. Post Office b,.,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 C (.3 ' ~'--~ L ,-5- .? I( A, I i'~ C ,_ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-4 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the 2U-4 Well History. When I do, I will forward a copy to you. Also, tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG/tw GRU5/L63 Enclosures RECEIVED i??~\~ 'ii~,'.. ';% c) .... ~i -"'~.,:, ,,.~ ~._,.. A!aska Oil & Gas Cons, Comrnis'~'ion Anchorag'~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '' ~1 ALASKA L _AND GAS CONSERVATION CC ~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-7 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21270 4. Location of well at surface 9. Unit or Lease Name 400' FSL, 1052' FWL, Se0.32, T12N, RgE, UM '~-~~q~ Kuparuk River Unit At Top Producing Intervalti VERIFIED~ 10. Well Number 1361' FSL, 1194' FWL, Sec.5, TllN, RgE, UM i S~_~-'i. ~ I 2U-4 1 1. Field and Pool At Total Depth ~_.~'. 1014' FSL, 1191' FWL, Sec.5, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 02/19/85 02/25/85 02/26/85I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8020'MD,6148'TVD 7906'MD,6062'TVD YES I-~X NO []I N/A feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SP/GR, FDC/CNL, Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 230 sx CS II (Approx) 9-5/8" 36.0# J-55 Surf 3541' 12-1/4" 725 sx PF "E" & 725 sx PF "C" 7" 26.0# J-55 Surf 7988' 8-1/2" 295 sx Class G & 250 s: PF "C" 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 N/A 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 OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY~APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. I: I: f.'-:, Form 10-407 JMM/WC43 ' Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . .... :.:. .... - :..:.~, , · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT; DEPTH -.GOR,'and.~tirne of.each phase:· .. .-- . . . ' ' ,'-: =:-i" ............................... Top Upper Sand 7~,98'{~.~, :~ 5758' N/A .' .! ,..',' :: ', 'Base 'Upper Sand 7550'- ~5796' ........ Top Lower Sand ~- '.-76~,6' il ~ 5867" "~' -- ,-:;, ' Base 'Lower Sand , -' 7809'-. ~ -- 5989' . . · . .:, .:, :~ ~ .. , . . . . : _ · . ,~, : ,. "i , . .'. , :., , .. .~ , .~ ,,,.. : F;~,:' ' ..- . : : ',ii . : . .. . _ · · · . . . . , _ . .... · . · .. . _ · 31. LIST OF A:FTACHMENTS ' ,: : . Cyrn_~_npin s,,r,~ey (2-.r. npies)':;': ..... ,:,~'- ..... , '~' 32. I hereby certify:that the.foregoing is. tiu, e .a,nd..co.r. rect to the..,b.'e_si of my knowledge Signed /~~~ Title Associ ate Engi neer 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- 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". $ UB-$ URFA CE DIRECTIONAL SURVEY r-~-] UIDANCE [~ONTINUOUS r~OOL Company_ ATLANTIC RICHFIELD COMPANY Well Name 2U-4 (400' FSL, 1052' FWL~ S32, T12N, R9E, UM) Field/Location ~~, NORTH SLOPE, ALASKA Job Reference No. Date 70170 13-MARCH- 1985 Loq~ed By: Computed By: KOZUSKA STEVENS II I C, CT OI~CT~I]MAL SUPV~¥ ARCO ALASKA, INC, KtJPARUK SURVEY [)ATF: 2-~1AR-85 ~N~I~EFR~ KOZ(J~KA ~BTHODS Db' Co-i.~PUTA*ION TOnL LPC~TT[j~!: '~A~GFNmlAI,- averaged deviation and azimuth V~RmlCAT. SECTIOn': Hr]ST~. hIST, PR~jECTf.;D ONtO A TARGET AZIMUTH OF SOUTH ] DEG 31 MIN EAST PAGE ! cr)NPUTATIf']N DATR: DATE OF' SURVEY: 2.,MAR.,85 KELL,¥ RUSHING EbEVAT!ON: ENGINEER; KOZUSKA INTERP[)I,ATI~]D VAI,UF.'CS I-'OR EvEM 100 PEET OF MEASi.!RF.D D~P"I'H ;E;A$~]MF'O VFRT]F'AI, VERTICAL DEVIATI. F}N DE. rH D~PTH PgPTH DEC; ~N DF'G NTm 105,00 FT' lnOO,no gg~,2n 89~.7() 7 5P 1100 DO 10q'1,8~ 092,g1 11 16 l~on.no ~2o1.~o ~1~,.s6 ~7 2~ 140n,00 13~b'12 19BJ,12 20 25 1SUn,n0 1678 ~R I~'/3,~H ?~ 2m 1600.00 1568:00 14t~3,00 ~8 3O 1700,O0 ~654,33 154q.]2 31 52 lPO~.O0 1737,7o 1639,79 34 5~ $ 9 26 W 1~,59 S 11 56 w 34, 50 5 6 44 W 56~26 ,~ 2 30 w 82.99 ,,:, 1 52 W 115 32 s 1 5',~ w 152:95 S i 12 W 197,65 S 3 26 ? ~4~,05 S 7 28 E 303,04 S 9 o E 361 .60 2000.00 1~06 9n 1791 nC 39 54 2100,00 1971:9n 1966:60 42 2200, nO 7043~ 00 lq 39, O0 4,~ 2 2]On. Ou 2112,u6 2nU7,Ob 46 2% 2400.0U 21~0.79 2n7~,7~ ~6 25 2~O0,nO ~250,1~ 214~,13 45 53 260n. Ot~ 9390,01 2215.01 ~5 ]0 2700.0U 2~eO.2e 278~,79 45 7 280n,nu 74~o,9~ 2355.05 ~4 5] 2OOo,Oo 2531 ,~7 2426,07 44 32 S 8 37 F 423.60 $ 8 4 E 489.49 $ ~ 2 E 550,58. a 8 R E 631,66 5 7 56 F 70d,08 S 7 2d F 775.05 S 7 14 ~ 847.32 ~ 7 20 P 918,30 S 7 46 ~ nSg.~7 S 7 5~ P ln50.07 300o.ou 2003.~7 249~,47 ag in 3100.~0 7675.37 2570.37 43 50 3200.o0 7747.71 2~47.71 d3 2n 33U~,00 ~890,57 2715,K2 d3 n 340o,o0 7893.90 278~.00 ~2 39 3500.00 7967.87 2a6~.n2 a2 360o.ou 3042,0a 2037,n4 ,~2 14 3700.nu ~115 7n 301o.7u 43 2! 3800,00 31~6;§~ 30~1.6d 45 47 390n,00 325t'4o 3140,49 a8 17 e 8 21 F 112P.76 S 8 44 ~1 1197.99 S 9 ~ F 1266.73 g 9 24 F' 1~34.~3 $ 9 3? ~ 1402.ag S 9 36 P 1460.48 a 10 31 ~ 1536,04 S 9 lg F 1603,?0 S 5 42 E 16'1~,47 $ q 1~ E 1746.94 1 O0 0n 200 on 300 OO 4no O0 500 00 60(.) 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SUB-SEA cnuRsF IEA$'ItF:Ir:~[) VERTICAT., VERTICAl., DF.,VIATION A?,I~.~UTH DEPTH DEPTH DEPTH DEG MTN [)Et.; tqTN SECT 101".~ SEVERITY FEET DEG/~ O0 1,27 1,09 0 63 0:42 0.51 0,2~ 0,35 u,2g 0,44 0.31 3216.05 47 59 3283.04 47 46 3~50,59 47 22 341¢.19 47 33 348~,61 47 38 3552.~I 47 53 3619,75 48 ~ ~ 2 25 E 1~21.,fi6 S 0 23 F 1895,76 ~ 2 3 W 1969.75 $ 2 20 W 2049.5'1 S 2 17 W 2116.04 S 2 2q w 2189,70 $ 2 ~0 W 2263.57 S 2 41 W 2~37,46 $ 2 4~ W 2.41~,n9 ~ 1 15 W 2484 0,27 0,42 0.11. 0,21 0,19 0,26 0,24 0,26 0,04 0,14 40(;0.0(:) 332~:05 4100.00 33~} 04 4200,00 345" bg 4300,0(' 357'~: lO 45U0.o0 ~65 8~ 370 ~:.~5 11 W 2557,61. 14. W 2630.85 20 W 2703,78 20 W 2775,B5 4:~ W 2848,19 53 W 2920.96 57 w 2992,12 50 w 3063.83 5'7 w 3135,00 57 w 3~5.85 0,23 0,35 0 85 0:48 0 56 0 26 0 45 0 43 0 43 4700,n0 3686.65 4'7 53 4~On. 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S 2 55 E 3272 85 S 161,68 F 3276 84 S 2 49 E 3343~16 S 159,64 E 3346 96 S 2 44 3413,4q S 157,74 F 341.7 13 $ 2 38 E 34~4,03 S 155,96 ~ 3487 51 S 2 33 E 3554 58 S 154,42 F 3557 94 S 2 29 E 3625 25 $ 153,03 E 3628 48 S 2 25 E 3ha6 18 S 151,88 E 3699,30 S 2 21 3766 7q S 150,96 E 3769,81 $ 2 17 3837 37 S 149,91 E ]840,30 S 3907 88 S 148,62 ~ 3910,71 S 2 10 3978,0~ S la7 2~ ~ 3980,74 S ~ 7 E 4047,85 S 145:93 E 4050,48 S 2 3 E 4116,96 s 144,70 F 4119,50 $ ~ 0 E 4185,28 S 143,58 E 4187,74 $ ! 57 E 142,58 ~ 4255,53 $ 1 55 E 4253,14 S 4320,58 S 141,69 E 4322,91 S 1 52 E 4387,85 S 141,02 E 43q0,1~ $ 1 50 E 4455,04 S 140,5~ ~ 4457,26 $ 1 48 E 4521,56 S laO,11 ~ 4523,74 S 1 46 g 458'I,33 $ 139,47 ~ 4589,45 $ I 44 E 1812,33 $ 206 15 E 1824,02 S 6 29 g 1886,55 $ 207:95 E 1897,98 S 6 17 E 1960,26 S 206.71E 1971,~3 S. 6 1E 2033,90 $ 203 82 F 2044,~9 S 5 43 E 2107,09 S 200 78 F 2117,23 $ 5 26 E ?181,68 S 197 73 E 2190,62 $ 5 10 E ~255,90 S 1~4 3~ E ~264 25 S 4 57 j 2330,14 S lO0 85 E 2337~94 S 4 4C . 2404 13 $ 187 32 F ~411i41 S 4 ~7 E 7477;79 S 184 68 $ ~484 67 S 4 i5 E RFCTANGULAR COORDINATES HORIZ, DEPARTURE NORTH/SOUTH E.AST/WEST DIST, AZIMUTH FEET FEET FEET DEG MIN ARCO .ALASKA, K~IP,~R~!K NORq~H $I, EIPE, A~,ASKA cni,,lpu?A?.[ni~ DATE: 1?.-~AR..,~5 PAGE ' 3 -" DATE O~ SURVEY~ 2-MAR-B5 KELLY RUSHING ~GE'VATION: 105.00 FT. gN(;IN[ER: KO~USKA I~:~'TF, RP£)I,,ATED YAIU.F,S FOI~ r~Vg~! 100 ~ 1~ DF twEASt,.IR~D D~PTH DEPTH DEP~'}i DEPTH [)~G VERTICAL DOCLEG R~CTANGI!LAR COORDINATe5 HORIZ, DEPARTURE ~ ~ AZIMUTH SECTION ,..EVERITY NORTft/SOUTH EAST/WEST DIST, FFET DCG/~O0 FEET FEET FEET DEG 8oOO.no 61~2,A9 6n27,49 41 7 8020.00 61a7.55 ~042.55 41 7 S 0 34 w 4665,O7 0,00 46~3,1,0 S 0,00 466b,25 S 118 8~ ~ 4655.17 $ 1 42 g 138:69 E 4668,3i $ 1 42 E PAGE 4 - ARCfl ALASKA~ NORTP, DATE OF SURVEY: ~-~AR-85 KEI~LY BUSHTNG .F..hEVATION: ENGINEF.~: KOZUSKA 105,00 FT- iH'I?E'RPL)I,ATEF) VALUES F~'l[~ EVEN 1000 FEET ,OF M,K'.ASURED DEP;I' VERTICAL DEVIATInN AXI~"I;TH r)EP'l'H DE(,; hTN DF.G tqJN VERTICAL DOGLEG RFCTANGUbAR COORDINATES HORTZ, DEPARTURE SECTION S~VERiT¥ NORTH/SOUTH E~ST/WEST DIST, AZIMUTH FEET DEC/1.00 FEET FEET FEET DEG o oo o.oo -~og oo o n tOOn:O0 9q9 20 ~94:?0 7 50 2000,nO ~8q6 90 1791,90 39 ba 3nOn,oO ~6o3 47 249~,47 44 lo 4000 O0 3371 O~ 3716 05 47 50 5000;nO 3!)94 39 30Sq:32 47 7 6000,Or) 4606.13 4581,1,3 45 3 7OO0,nO 53q5.01 5790,01 44 2~ 8000 O0 6132 49 6027,49 41 7 8n20:~o 6147:5g b04~,55 41 7 S 9 2~ W 18,59 $ ~ 37 ~ 42.3,60 $ 8 21 ~ 1!.2~,76 S 2 25 ~7 i~2~ 56 g 1 11 w 2557:~1 $ 1 46 W 3~76,61 $ 1 6 W 3079,56 S 0 34 W 465?,85 ~ 0 34 W 46~5'07 O0 ~ 75 0:36 ! 27 0~27 0,25 0,00 0,00 0 O0 N 1,8:6~ $ 423 66 S 12 1124 22 S 108 ~8~2 33 $ 2O6 ~551 lfl S 183 3272 85 $ 161 3978 02 S 14 7 4653 10 $ 138 4666~2~ S 1.38 0,00 E 0 13 E 18 16 E 423 53 E 1129 5 E 1824 7 E 2557 68 E 3276 28 E 3980 8~ E 4655 60 ~ 4668 0 O0 N 0 0 E 62 S 0 23 E 83 IS 1 38 E 44 S 5 30 E 02 $ 6 29 E 74 ,5 4 6 E 84 S 2 49 17 $ 1 42 ~ 31 S 1 42 g Cr)l~iP Uq'AT I..0, N D~TR: KIIPARtIK DATE: OF SURVEY: 2-MAR-85 KELLY BUSHING EGEVATION: E~IGTNF, ER: KOZUSKA 105,00 PT- INTFRPOr,ATED VALUF5 FOR EVEN 100 PEFT OF SUR-SEA DEPTH [EA$I.;RFD VF. RTICA[, VERTICAL DEVIATI. f'IN AXI~eUTd DEPTH DFPTH DEPTR DEG VERTICAL DOc, bEG RECTANGULAR COORDINATES HORIZ. DEPARTURF. SECTIOh SSVERiTY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FFET DEG/100 FE~T FEET FEET DEG SIN °.no 0.00 -t os.o() 0 o ,~I 0 C, E 5.n0 5.00 -lOn. O0 0 ~ ,~: 21 34 F lO~.OU 105.()0 n,oo 0 6 ~ lO 24 w ~05.00 2n5,0n 100.00 0 13 $ 80 46 ~ )05.00 305.00 ~On,O() 0 15 $ ~4 49 ~ 405.00 4n5 On 30n,o0 0 ~ s 47 21 P 505.00 505[00 400.00 0 14 $ 69 1 ~l 60~.no 6o5,0o ~On.OO () 1~ $ 3 55 ~ 705e01 7~5 O0 ~(:)O.OO 0 1! S 9 10 F 805.01 805[00 700.00 1 16 S 2 44m W OOS.?O 9o5 O0 q00.00 5 n 1005 ~6 ~005~00 900.00 8 10 1107:]4 !l. 05,0n lnOO.nO 11 31 1~10,n2 1205,00 llOn,nO 14 2] 1314.10 1305.00 l?O0.O0 17 57 1420.70 ~405,00 1300.o0 1520.oq 1505.0n ldO0.OO 95 47 1.~4~.47 16o5.0o 1~0o,00 ]0 6 1760.'~0 1~n5,00 160n,O0 188~.00 ~8o5,00 17~0.o0 36 45 2010.57 1905.00 lP, 0n.no 40 11 2145.R0 20n5.00 'tODD,no 44 36 2289.76 ?ln5,oo 2n0o.oo 46 2l 2435.o6 ~205,0n 2100.00 2~78.~6 ~3nS.0n 2POO,O0 45 2720.fl3 2405.0o 230n.n0 45 4 300~.13 7605,00 25on.00 ~4 3~4{.O4 ~7n5 0n 2600.0(, 43 3~7~.76 7~05:00 2700.00 3415.04 2905.0n 2Roo.oo 42 26 3K50.05 lO05.00 2oOn.O0 ~2 36~5.34 3105.0n 3o0o.00 a2 5° 3826.~1 3205.o0 3100.00 4b 37 3975.99 3305,0n 3~OO.OO 48 7 4125.?0 34n5.00 3300.q0 a7 3R 4~73.07 3505.00 340n.nu 4't 37 4421.35 ]bOS.00 3500.0C 4'1 41 4570.d5 37n5.0o 360o.n0 ~ 471q.89 3~ob. O0 37On.qu ~7 bl n.0o 0.00 0,00 N 0.00 E 0,00 0,00 0.00 ~ 0,00 E 0,23 0,33 0,2~ $ 0,13 E 0,26 0.59 0 78 0,57 S 0,31 E 0,65 O 79 0~46 0,76 S 0,'46 E 0,89 0:92 0,43 0,88 $ 0,73 E 1,14 1.16 0,52 1,11 S 0,85 E 1,40 ~.22 0,56 1,16 S 0,99 E 1,52 1.45 1,02 1,37 S 1,2] E 1,84 ?,45 3,0~ 2,37 S 1,35 ~ 2,73 ~.12 2,47 10.40 3,59 35,02 3,73 2,91 58.65 87.9.3 3 12 }2P.46 165.17 5,20 21~ 44 4,07 ~,80:70 4.08 351..38 2,54 A 8 32 ~ 430.37 ~ 7 59 E 521.14 $ 8 q F 62a.~7 s 7 40 E 729,37 S 7 )8 ~ ~3~.05 ~ 7 3P F 933.01 $ 7 aa ~ 1032.53 a ~ 22 ~ 1130.~3 S 8 5~ ~ 1~26.~7 S 9 21 E 1320.5! s 9 32 F 1412,59 S 10 12 E 1507.79 $ 9 4~ ~ 1593.24 $ 5 n F 1697,49 S 2 53 ~ 1~03,72 $ 0 11 w 1914.37 $ 2 1~ W 2022,~1 S 2 1~ w 2131.74 S 2 4n W 224m..72 K 2 41 w 2357.~2 2,63 3,53 0,39 1,28 O,lO 0,52 0,64 0,35 0,53 0,62 0,71 1.]5 2,91 4,57 2,0] 2,55 0,52 0,5] 0,46 0,26 8 07 S 19 44 S 30 21. 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E 1916,52 S 6 13 E 7014 05 S 204,62 E ~024,4~ $ 5 48 E 2123 46 S 200,15 E ~132.87 S 5 23 E 2233 95 S 195,34 E 2242,47 S 4 59 E 2344 87 S 190.16 E ~352,57 S 4 38 E Cf)i~PLiTATInN DATE: 12-NAR-R5 PAGE APCO ~,GASHA, NORTH 5[.,OPE,AIOA~KA DATE OF SURVEY~ 2-MAR-85 KEf, bY ~USHING EbEVATION: iCNGTNI?ER: KDZUSKA 105,00 IN]~F, RPOLATEP, VALUP;5 FOR EVElU 100 FEET OF SUB-SEA r~EPTH T P U r~' S LI ~ - $ [< .A C r~ u P ,5 E ".EASURFD V~RTICAL YEP'I"ICAh DEV.T.^Tir]r~ A.7.,iuU'rH vERI'TCAi,, POe, bEG RECTANGIIL~R COORDINATES HORIZ, DEPARTURF, SECTIOI~ SEVERITY Nr)R~H/SOUTH EAST/WEST DIST, AZIMUTH FEET DE.C/I O0 FEET FEET FEET DEG MIN 486¢~, 44 ~905,00 3n00,00 47 22 5015.~9 4005,00 3oo0.O0 47 5 5162 ?8 4~05,00 4000,00 46 52 53()R:75 /~2n5, on 410n,00 46 40 5453 56 4305 Oo 490n,00 46 21 ~ lb ~O0 4~(,)0,00 46 13 a4°5-on 4,~.oo.oo ~5 ~o 5742 15 ,aSh5, 588a~5 a605,00 450n.00 45 la 6026.a3 a705,00 460o.00 44 41 6167.2'3 aBaS.OB 4700.00 44 44 6~(')P 99 4905 Om 4R00.O0 44 50 b4,l.q: ~ q005:o0 qqO0.O0 44 57 6732, qtJ 5205,0o 510~,t)O 4, q 47 687~.&~ 93o5,00 5~0n,00 44 7013.0~ ~405.00 5~00,00 44 2r4 7!5].36 ~5nb,On 5400.00 43 7990,6u 5605,00 55On.nO 42 4q 7426,~0 ~Tns,0n 5600.n0 7561 .07 58n5.0n 57on.no 7697.09 K905.00 5g(~n.nO 41 bq 7830,76 &O05,00 5000,00 ll 7 7063.~1 ~105.00 ~oun,eo 41 7 802~.00 6147,5~ b047,55 41 7 ,i~ W 2461,35 1!. w 256q,06 16 w 2675.R8 ~ W 2781,83 40 W 2886,~3 ,57 W '02.90,79 4? %! 3795,~2 ]0 W 339].76 S I 22 W 349P.87 $ 1 O W 3597.76 S 0 ~'1 W 3692.32 ~ 0 47 W 3791.69 ~ I ] W 389},~2 S 1, 7 w 308o,t2 S I 1 w 4086.08 S 0 5n w 4~7o,R7 S O 45 W .&271,99 K 0 30 ~ 4362,68 $ t) 2~ W 4453.33 S 0 34 w 454~.03 $ 0 34 W 462~.n2 $ 0 34 W 4665,07 1,58 0.10 0,42 0,2~. 0,28 0.20 0,73 0,22 1.25 0,27 0,73 0,60 0,37 0,56 0,55 0,17 127 0,44 0.8~ 0,57 1,38 0.00 0,00 0,00 2454,61. 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I~,,,,,IqAR-R5 nATg OF SURV£Y~ 2-MAR-85 KELLY ~USHTN~ ~bEVATION: 105,00 FT, EN(;I~EER: KOZUSKA ir,!I'FP, PC]T,ATJt.~D V'A.I',UF.~:; FOR CHOSEN NOR IZOt")S ,.SURFAC~ LOCATION ?VDr]RIGTi'~= 400' FS.L,, 1.052'RF. CTANGUbARFWI,, SEC C06RDZN32 T12~..E~gE, U FROr,,~ K~'~ SUB-SEA NORTH/SOUTH EAST/WEST 7408,00 7550.00 764b,()0 78n9,0o 7906.00 8070.00 5757.6g 5652,04 5796,15 56g~,~5 5~67.10 5762.10 598~.61 58~3 01 6061.68 5956i6R 6147.55 6042 55 4319 24 $ 4354 ~8 $ 441n 85 $ 4527 49 S 4591 28 $ 4666 25 S 1.41. 70 g I41 29 g i40 80 g 140 06 g 138 69 ARCr! AI]ASk'A~ TNC., NORTH ST.:OPE, AI',ASI< A l~ ARK~'R "1' ft p L.tP PRR P lA TI", C clx'4 P L!T AT [ fi t',] !)A'['~: PAGE DATE O? SURVEY: 2-MAR-85 KELLY BUSHIN~ ELEVATION: 105,00 ~T. ENGIN~EP: KOZUSKA ;I,:** * **.** $* :~* STIr(A']~ I L;R APH T C 74¢t8, O0 7646,00 7t}09,00 7906,00 SURFACE LOCATION AT nR!~G.'l'l,,t: 400' 1~'$1.,, '!052' Fw[.,, SEC ..t2, T12N, Rgg, U TVD R~CTANGIIbi~R COORD~NAT SUB-SEA NORTH/SOUTH EAST/WEST 5757.64 5796,~5 5~67.~0 5988,61 6061.6~{ 6.~ 47.55 5652 64 50~1 15 5762 1~ 5883 61. 5956 68 6042 55 4119,24 S ~4~.70 g 4354.18 $ 14~,29 E 441~,85 $ 140,80 E 4527,49 S ~40,06 E 4666,~5 $ ~38.69 R / TiM.AL WEl,b b[1CATTON AT Tn: I~i~;,A S L.; P ED V r;", R?I CAL 5147.55 6042.bK 4608.31 $ 1 42 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC NELL 2U-4 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 2-MAR-SS REFERENCE 0000'70170 RECEiVE[~ · WELL: 2U-4 SURFACE LOCATION: 2U-/~--~400' FSL, 1052' FWL, S32, T12N. 9E, UM VERTICAL PROJECTION '--r..m.-'r.--?"t-'w~--+-.;----.~-*.'--.'-..~-t-+-+-+.-~ ..... -.:-.-~-~' .~.' ~-¢..--r-'-wr-rw..-t'"..'-*.."'~-'~ ..... .~..-?+-+--?-+--*:-.+--k.-.--.+-+-.~----:--~.--?+--+-+.---+-+..t..-?.-?-+--?.-~..-~. ...... +-.?...+...?t-.-:.-.~...~..+..~ .... ?'"?'"?'-?.-- -~--?--~...~--* .-*--~---~.--~--t--~.-~...~-~ .. 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HH~I"H~"+"~"+'I~l'l;'ll~'ll~ll'HHHHHHH "4'-~'"~'"~'-~'"~'"~'"~l"~"l;'"Hi'"~'"~'"~"H'b'~'l ~ ..... ;1. ~l...~...+.. ~ ..... ~ ~ .~ ..... ~. 1L.:.l.lb..?l.~..., ~.ll~ ....... ;...; ........... ~ ..... :.l .._~_.~_.~...~_~.~.._L..;...; ...... ;...;...L.L.~....L.L4...~...]...~...;-;...~.~~";...;...~-;.T.;.~;...~-.4...&...L.L..;...L..; ...~...~.._L..~...L.L...~...;...~ ....... :. ........ :....:...H;....~ ............ ; ......... ; ........ ;...~ ........ : ........ ~ ....... : ............... ~...~ .......... -4000 -9000 -2000 -1000 0 1000 2000 9000 4000 EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance wit~ our regulations. W~LL ~ME AND NUMBER Date , , Required Date Received Remarks Completion Report , Well History Mud Log ...... ,~~! ' ~/5 ,, Core ChSps Core Description ~~~ '-~ :) K., Registered Survey Plat .....Inclination Survey ~~ .... ¢ ]5. Drill Stem Test Reports , _ Production Test Reports ~~::~ .... " ., _._~:_>~ :'- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~-!arch 13, 1985 Mr. C. V. Chatterton Commissioner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells- 17-11 2C-11 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2w-1 2W-2 2W-3 2w-4 If you have any Sincerely, ' . Gruber Associate Engineer JG/tw GRUS/L18 Enclosures questions, please call me at 263-4944. RECEIVED MAR 1 4 198,5 Alaska Oil & Gas Cons. Commiss{on Ancr, orage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,--, STATE OF ALASKA ALASKA L_ _ AND GAS CONSERVATION CO. MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well)~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-7 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21270 4. Location of Well atsurface b~00~ FSL, 1052' FWL, Sec.32, T12N, ReE, UN 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 6. Lease Designation and Serial No. ADL 25644 ALK 2575 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2U-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 2300 hfs, 2/19/85. Drld .12-1/4" hole to 3560'. Drld 8-1/2" hole to 7970'TD. Ran logs. Continued drilling (2/25/85). Ran & cmtd 7" csg. PBTD = 7906'. Secured well & 2/26/85. Arctic Packed. Ran and cmtd 9-5/8" csg. 8-1/2" hole to 8020'TD released rig @ 0800 hfs, 13. Casing or liner ryn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 115'. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3541'. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 7988'. (Arctic Packed). Installed w/approx 200 cf Poleset. Cmtd w/725 sx PF "E" & 725 sx PF "C". Cmtd w/295 sx Class G and 250 sx PF It C I! 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/GR f/3539' - 7966' Cal f/3539' - 7966' FDC/CNL f/7300' - 7966' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, f.,ICi;0f::;U3 NOTE--RepoFd/on this form is required for each calendar month, regardless of ~: status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 T~'~D /E4DnQ Submit in duplicate ARCO Alaska, Inc. ~ Post Office box-100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 25, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Conductor As-Built Location Plats - 2U Pad Wells 1-8, 9-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU3/L77 Enclosure If ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany i i ii i! WELL 1 Y = 5,975,841.16 LAT. 70°20'42.7599" X = 509,642.25 LONG. 149°55'18.2508'' PAD =_LEV. 68.4 O.G. EI. EV. 64.2 FSL ~75 FWL 1,096 WELL 2 Y = 5,~75,782.54 LAT. 70°20'42.1835'' I X = 509,627.77 LONG. 149°55'18.6762'' . PAD ELEV. 68.4 O.G. ELEV. 64.1 FSL 517 FWL 1,O81 WELL 3 Y = 5,975,724.43 LAT. 70o20'41.6122'' X = 509,613.34 LONG. 149°55' 19.0999" PAD ELEV. 68.3 O.G. ELEV. 64.0 FSL 458 FWL 1,066 · WELL 4 Y = 5,975,666.21 LAT. 70°20'41.0397'' X = 509,599.09 LONG. 149o55' !9.5187" PAD ELEV. 68.4 O.G. ELEV. 63.9 FSL 400 FWL 1,052 WELL 5 Y = 5,975,753.43 LAT. 70°20' 41.902" X = 509,249.86 LONG. 149°55' 29. 720" PAD ELEV. 68.6 O.G. ELEV. 64.4 I FSL 488 FWL 703 WELL 6 Y = 5,975,611.41 LAT. 70020, 42.472" · t X = 509,264. 30 LONG. 149°55' 29.296" ® ~ PAD ELEV. 68.6 O.G. ELEV. 64.4 ® 3 FSL 546 FWL 718 WELL ? Y = 5,975,869.59 LAT. 70020' X = 509,278.75 LONG. l:+9°55' PAD ELEV. 68.6 O.G. ELEV. 64. FSL 604 FWL 7]2 WELL ~ Y = 5,975,927.8.0 LAT. 7,.'.;°20' 43.616" X = 509,293.26 LONG. !.:,~,°55' · _~:.~ 64 ~,l ~ PAD ELEV. 68.5 O.G ~" ~ '. FSL 662 FWL , LOCATED IN PROTRACTED SECTION 32 TOWNSltIP 12 N, RANGE 9 E, UMIATMER. ~~i9~,t,h, .r~,., NO SCALE -. : ...... -~;, '~ NOTE' BASIS OF BEARING IS PAD PILING CONTROL-,.'.m..a-~'J',,_ .'.".'7.~'.;,~ N 1~+55, E8+30 AND N15+55, E 11+70 AND . .~. BASIS OF ELEVATION IS 2U-SAND ?_.U-4 PER LHD 8, ASSOCIATES. · . .... LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF } ~ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS -' ..Kuparuk Project.N°rth Slope Dri!ling DRILL SITE 2U CONDUCTOR AS-BUILT LOCATIONS ~t~ L .., , ~, ! ~...~SCALE: I = ; Drown By' HZ Dwg. No. NSKD.05.221dl January 16, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Imc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2U-4 ARCO Alaska, Inc. Permit No. 85-7 Sur. Loc. 400'FSL, 1052'F%~L, Sec. 32, T12N, R9E, UM. Btmho!e Loc. 1057'FSL, 1336'F~.FL, Sec. 5, TI!N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, veloc~ty 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 be contacted by the Habitat Coordinator's Office, Department 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. Mr. Jeffrey B. Kewzn Muparuk River Unit 2U-4 -2- January 16, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention 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 equi~ment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment pzeas.~ give this office adequate advance notification so that we may have a witness present. Ver~3_.tru 1~ y/~s~, ~ C. V. Chattertdn Chairman o f AlaSka Oil and Gas Conservation Commission BY ORDER OF THE CO~IM~_ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B,. t00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 8, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 2U-4 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2U-4, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment We estimate spudding this well on February 25, 1985. If you have any questions, please call me at 263-4970. Sincerely, JBK/HRE/tw PD/L22 Attachments RECEIVED JAN 1 4 ]985 A/aska 0ii & {~as Cons. C0mmiss[0ff Anchorage ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COrv~MlSSlON PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE [] STRATICc~.AP~ ~ DEVELOPMENT OIL [~X SINGLE ZONE I--I DEVELOPMENT GAS [] MULTIPLE ZONE la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 400' FSL, 1052' FWL, Sec.32, T12N, RgE, UN At top of proposed producing interval 1320' FSL, 1320' FWL, Sec. 5, TllN, R9E, UM At total depth F~L ? S%. 1057' FSL, 1336' 5,Tt~N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) / RKB 106', PAD 69' 6. Lease designation and serial no. ADL 25644 ALK 2575 9. Unit or lease name Kuparuk River Unit 10. Well number 2U-4 11. Field and pool Kuparuk River Fi eld Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8087.26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to neare~-t-pzoperty or lease line 30 mi. NW of Deadhorse miles 400' @ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures ?6~b, MAXIMUM HOLE ANGLE 45 o (see 20AAC25.035(c) (2) 3038 - 16. Proposed depth (MD & TVD) 8025' MD, 6195' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 750 feet. 21 tl 5. Distance to nearest drilling or completed U-3 well 60' (~ surface feet 18. Approximate spud date 02/25/85 psig@__80° F Surface psig@. 5930 ft. TD (TVD) Proposed Casing, Liner and Cementing Program Hole j24" SIZE Casing Weight 16" 62.5# il 2-1/4" 9-5/8" 36. O# i8-1/2" 7" 26.0# CASING AND LINER Grade Couplingl Length / H-40 Weldj J-55 BTC I HF-ERW J-55 BTC / 7991 ' I HF-ERW 22. Describe proposed program: SETTING DEPTH MD TOP TVD 80' 35' 135' 3506' 35' 135' 34' 134' MD BOTTOM TVD 115' II 115' . 3541' I 3016' I 8025' I 6195' I I QUANTITY OF CEMENT (include stage data) + 200 cf Polese~. 725 sx Permafrost "E" 830 sx Permafrost "C" 260 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8025'MD (6195'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3541'MD (3016'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (3000 psi for annular). Expected maximum surface pressure is 2644 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 3-1/2", 9.2#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certif~hat the foregoing is true and correct to the best of my knowledge SIGNED ( /~~~, ~/~ TITLE Area Dril ling Engineer CONDITIONS OF APPROVAL Samples required Mud log required I Directional Survey required [-IY ES '~].N O I--lYES /~LI~O I ~-ES [~NO Permit number Approval date APPROVED BY Form 10-401 (HRE) PD/PD22 DATE IAPl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 16, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2U-4 installed and tested upon completion of the job. 2U-4 will be the eighth well drilled on the pad. It is ±60' away from 2U-3 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6476'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x ?" annulus. The 9-5/8" x 7" annulus wi]~ be left with a non-freezing fluid during any interruptions in the disposa~ process. After the completion rig has moved off location, the well will be fracture stimulated. RECEIVED · J 4 ]985 Alaska Oil & 6as Cons. Commissior~ Anchorage i !44 000 ' ' · a l;~," a Oil & G;~S Cods. Commission 000: , I Surface ~iv· '"".. ",'* Svste~n 16"-2000 psi Tanzco Tanxco ~',uic~ co~ect essy. X 20" 200G aoapte~. 2000 ~s~ ~r~ll~n~ spool ~/10" s~Oe outlets. bell valves~ ~y~r~uiically actuateo, ,/10" ~es d~on ZOOC ~si annular ~reve~er. m m I veri'~ t~at :al' valves qeve ODe~ec · ~!ose annular .reverter arc =lo~ a t~rou~r lines every '~ hours. Close annular ~reventer ~n :me event · . ~Ow, tO surface is oetect...-~ ; necessa-v,, marius v over,Joe anc close oall valve to .o-thc :~verter · 6" Conoucter 7 4 IS 45 ~ECt3q~ O,.C~SII~ TIIw~ ~ !~5/8' ~ STACK 2 FILL BCP DI~L. ~TH ~I~ JT 3. ~ v~S 4. ~~ ~D ~~ TO 0 ~I. 5. ~N g. ~N ~TZ~ ~I~ I0. ~ ~I~ ~I. I...,,._ I ~IFCLD ~ LI,'~S AR~ gU, J. CF' I FLUI~ ~ET ~ VAI. V-r_~ IN C~ILLING ~4:~iTICI% , k. ~2. TEST 5'F~q:PIPE vALV?.~ KP~¥, KD~.Y C~ .~I,.-' 1~ ~/~ ~ ~ ~ PI~E. SAFETY vN.v~ ~ Ih~SiCE 80P TO 250 P~i ~ I ~- F~ SI~ ~ ~ TO ~!L~I~ ~RvI~. 5(C0840C ~ CHECK LIST FOR NEW WELL PERMITS Lease & Well No. /CI6Gf % ~-~ Company___~:c~ ITEM APPROVE DATE YES NO , ,, REMARKS (1) Fee , . , (2) Loc thru 8) ,., (8) (3) /:// O0 and 12)' (4) Casg ~# (13 thru (5) BOPE h<, . '- (22 thrtf 26) (6) Ad d: 1~¢'7'/~' hf/ 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... . 10. 1!. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. ~z Is a conservation order needed ...................................... Is administrative approval needed .......................... .... ~i..iz~-z-~ Is the lease number appropriate ......... .... .... · ....... Is conductor string provided ................................. Is enough cement used to circulate ;n conductor and su;face . iii ..... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ............. Will surface casing protect fresh water zones ..i... i.~i.i ..... i.ii Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ...... ...... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached .... Does BOPE have sufficient pressure rating - Test to ~z~f:P ;;i~ .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~..~ Additional Remarks: /~,7~,~/~ ~~ ~ l~l~-.~~ ~' Geology: ~ Engineering: WVA J~K.T ~~_, HJH JAL M rev: 10/29/84 6. CKLT POO.L INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. L~.S T~P,~ ViE:R/F ZC,~T[Cfl L]~ST [N~3 LVP OIO.HOZ VERIFICATION LISTING PA~ I ~, REEL HEADER ** SERVICE NAME :EOIT DATE :~5/03/i7 ORIGIN : REEL NAME : CONTINUATI2N ~ PREVIOUS REEL : COMMENTS : *~ TAPE HEADER SERVICE NA.~E :EDIT DATE : S5/03/17 ORIGIN :0000 TAPE NAME : CONTiNUATI2N ~ PREVIOUS TAPE COMMENTS : ~, FILE HEADER FILE NAME :EDIT SERVICE NAME : VERSION ~ DATE : MAXIMUM LENGTH : FI LE TYPE : PREVIO~.S FILE : INFORMATION RECORDS MN E M C O N T EN'TS CN : ARCO ALA:$K,A WN : 2U -.4 :N : K U P A R U ANG: 'TOWN: lIN SECT: 32 C:DUN: N. SLOPE STAT: ALASKA CTRY: USA MNEM C,,O:~T.E N T S PRES.: E ** COMMENTS UNIT TYPE CATE SIZE CODE OOO 000 ,0,1.5 0~5 000 000 00,4 0:'65 00,0, 00,0 0 ~7 0 ~:,5 000 000 00'2 0'6.5: 000 000 0~2, 0,65 000 000 002 055 000 000 006 06.5 000 OOO 003 065 UNIT TYPE CATE SIZE 000 000 00'1 065' LV? OI~.H02 VERIFICATION LISTING PA~E 2 SCHLUMBERGER ALASKA DIVISION COMPUTING CENTER COMPANY = ARCO ALASKA INC ~ELL = ,2 .~- ~ FIELD = KUPARUK COUNTY : N.SLOPE STATE = ALASK SECTION = 32 TOWNSHIP RANGE = 9E TAPE DENSITY : 800 SASE LOG: OiL , RUN ~ 1 DATE LOGSEO 2.~ FEB 85 BOTTOM LDG INTERVAL : 7958 FT. TOP LOG INTERVAL : 3539 .FTo CASING-LgGGER = 9.625 iN. @ 3~'.'3~ FT. ~IT SIZE = 8o~,00 IN.. TYPE H~.L~ FLUID = WTD.. PO'LYMER LVP OlO.HOZ VERIFICATION LISTING PA~E 3 DENSITY VISCDSiT¥ PH FLUID kOSS RM @ ME&S. TEMP. RMF ~ MEAS. TEMP. RMC ~ ME~S. TEMP. RM ~ 8HT MATRIX LDP: T ~ALSTEAD = i0.I0 = 35.00 = 9.50 = 3.4,BO ~ 65 F = 3.110 ~ 65 F = 2.830 & 55 F = 1.648 @ 1~5 F = SANDSTONE ** DAT~ FORMAT R~C3R~ ENTRY ~LOCKS TYPE SIZE 2EPA CODE ENTRY 2 I 6& 0 ~ 1 66 1 8 ,~ 73 60 0 i 65 0 DATUM SPECI.FICATION 5LSCKS MN~M S~R¥ICE SERVICE UNIT API API AP~ ~PI FILE SiZE SPL REPR ID ORDER # LOG TYPE CLASS MDC) DEPT FT O0 000 O0 0 SFLU OIL DHMM O0 2.20 01 0 I L 0 O I L 0 H M.M 00 1 Z 0 ~ 6 0 ILM BIL OHMM O0 110 ~ 0 SP OIL MV O0 010 01 0 GR OIL 2API O0 ~10 Ol 0 ~R FDN GAPI O0 310 O1 0 (ALI PON IN O0 280 O1 0 RMOB FON G/C3 O0 350 02 0 DRMO FON ~/C3 O0 356 O1 0 NRAT FDN O0 ,¢10 0i 0 RNRA FON O0 '000 O0 0 N P H I F O N P U 0 0 8 9'0 0 0 ,0 NCNL FDN CPS O0 330 31 0 FCNL FDN CPS O0 330 30 ~ PROCESS 'C~DE (.OCTAL) 6.8 00000000000000 68 O00000000000OO 58 O000OO000000'O0 68 0000000.0000000 6'8 OOOO000000000.~ 6,8 000000,0000000~ ~8 OOO00000000000 68 0000,0000000000 68 O000000000000O 68 0000000000000~ ~:8 000000000000~ ~8 O0000OO000000O 6.8 ,O000000O.O0000O 68 ,O0000000000OO0 68 00,00000000'0000 LVP OIO..HOZ VERIFICATION LISTING PA&E ~ OEPT 7387.0000 SFLU SP -31.0000 GR RHOB 1.9805 DRHO NPHI 39.5508 NCNL OEPT 7900..0000 SFLU SP -2&.5000 GR RHOB 2.3857 ORHO NPHI 39.3555 NCNL DEPT 7800.0000 ~FLU SP -28.0000 GR RHOB 2.3848 ORHO NPHI 34.8633 NCNL OEPT 7700.0000 SFLU SP -76.250.0 GR RHOB 2.7~Z2 ORHO NPHI 6.68'95 NCNL DEPT 7500.0000 SFLU SP -23.5000 GR RHOB 2,.41.80 ORHO NPHI 34.5680 NCNL DEPT 7500.0000 SFLU SP -~9,.0000 GR RHDB £..3730 DRHO NPHI 42..773~ NCNL DE'PT 7,600.0000 SFLU SP -35.5000 RHOB 2.3'848 NPHI '47.8.516 NCNL DEPT 7.300.0000 SFLU SiP -51.750,0 GR RHOB 2.3711 D,RHO NPHI 43.Z6~7 NCNL DEPT 7200.0000 $:FLU S'P -49.0000 GR RHDB -'ggg.o 250 0 ORHO NPHI -~93.Z500 NCNL OEPT 7100.0000 SFLU SP -4 5. 0000 GR RHOB -9',99.250.0 DRHO NPHI -9'99. 2500 NCNL 3o2~1 52.~250 GR -0.1357 NR4T 92Z.00O0 FC~L 3.3809 .10~.g375 GR 0.04'74 NR~T 1794.0000 FCNL 22.18'75 IL,3 87. I875 0.0435 NRAT 2037.0000 FCNL 55.0.5000 iLD 44.7500 GR 0.0~74 NRAT 5700.0000 FCNL 5.0273 I.LD 82.8750 GR 0.0083 NRAT 2;326.0000 FCNL 2,5215 ILO 1,27.6250 GR 0.0869 NRAT Z506.0000 FCNL 2.5,46,9 138.7500 0.1421 NRAT 1680.0000 3.1543 ILO 129.1250 GR 0.2104 NRAT 16,69..0000 FCNL,.. 3..¢570 ILD 235.0000 ~R -999.2500 N,RAT -999.2500 FCNL 5.7'617 ILO 262,.2500 GR. --999.2500 NRaT -999.2500 FCNL 2.701l 52.1250 3.3008 286-5000 3.0703 10~.9375 3.5457 57'9.0000 S.7500 87.1875. 3.0703 528.5000 67.8125 i. Z1%.8 4768.0000 5.2969 8,2. 8750 '3. i:055 749.5 O00 12.,~84,4 127.625'0 3.5234 Z'¢199 138.750'0 3.818~ ~76.'750.0 Zo ~:t 5'T 4 1Z 3.5840 4,94.2500' 2.636'7 236.00~'0 -999. Z500 -999.2500 .3. 9473 2.6,2.2.5:0:0 '-999. Z500 -g9'9. ZSO0 ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA ILM CALl RNRA I":L M CALI RNRA ILM CALl RNRA iLM CALi' RNR,A tLM RNR, A ,~LM CALI RNRA I'LM CALI RNRA 2.8477 8.5000 3.2155 3. i,.q35 9.16%1 3.09 77 3.2402 1.,[953 :3. ~531 9.3~/50 3. 1016 3.5000 Z. 5,05 3.2.734 £,.~'238 3.3'750 2..: 7852. @.789I -999,.2500 ,~. 19].4 9.5859 LVP 010.HOZ VERIFICATION LISTING P.A~E 5 OEPT SP RMOB NPHI SP RHOB NPHI DEPT SP RH08 NPMI DEPT SP NP HI DEPT SP RHDB NPHi ~EPT SP RHOB NPHI OEPT SP RHOB NPHi DEPT RHOB NP~I RHOB NPHI D,EPT $,p RHDB NPHI OEPT SP RHg5 NPHi 7000.0000 SFLU -46.2500 GR -999.2500 ORHO -999.2500 NCNL 6900.0020 SFLU -23.2500 GR -999.2500 DRHD -999.2500 NCNL 6800.0000 SFLU -36.0000 GR -999.2500 NCNL 67.00.0000 SFLU -23.5000 SR -999.2500 DRHO -999.2500 NCNL 6600.0000 SPL.U -60.2500 GR -999.2500 DRHO -999.2500 ~CNL 6500.0000 SFLU -59.0'000 GR -999.2500 DRHO -999.2500 NCNL 6~600.000~ SFLU -~7..7500 GR -999.2500 NCNL 6300.0000 SFLU -50..5000 GR -909.2500 D'RHO -999. Z500 NC. 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Z$00 -999.25'00 3.5234 13'7.6:2~0 -999.2500 3.5117 113.1875 -999.2.500 -999. 2500 4.'7578 -999,2500 -999.250'0 3.86.3,3 -99'9.2500 - 999-2500 - 999,. 25'00 3- 5566 - 9,9 '9~- 2500 -999. 2500 - 999.25,0,0 -999°2500 -~99o2500 CALI RNRA ILM .CALL RNRA ILM CALI RNRA ILM CALI R.NRA CALl RNRA ILM CALI RNRA ILM CALl RNRA ,ILM CALI RNRA CALI RNRA ILM CALl RNRA CALI RNRA 4.2'7'73 10.23~4 -999.2500 3.5008 - 999. 10.1797 -99'9.Z~00 3.8008 9,6797 -99~,.2500 -99~.1500 '- 999. 2500 '9,656.3 -999.2500 ~.8047 9.,Z051 -999'.,2500 3.,~9,4I ,-999.2500 '-999.:.,2500 3.6536 -999-2500 -999.,,2500 2.0'020 -999.2500 -999,.1500 LVP OIO.HOZ VERiFiCATigN LISTING PA&E 6 DEPT NPHI DEPT SP RHDB NPHI DEPT SP RHDB NPHI D E PT · S P RHO8 DEPT SP RHOB NPNI OEPT SP RHOB NPHI DEPT S'P RHOB NPIJI DEPT S'P RflOB NPHI DEPT SP RHgB NPHI OEPT SP NPHI DE P'T SP 5~00.00O0 SFLU -55,.Z500 GR -999. 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