The URL can be used to link to this page

Home My WebLink About185-238MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-11 KUPARUK RIV UNIT 3A-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3A-11 50-029-21458-00-00 185-238-0 W SPT 5839 1852380 1500 2650 2650 2650 2650 150 165 165 165 4YRTST P Austin McLeod 8/4/2025 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 3A-11 Inspection Date: Tubing OA Packer Depth 485 2010 1955 1940IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804190541 BBL Pumped:1.2 BBL Returned:1 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:30:47 -08'00' MEMORANDUM TO: Jim Reg,- -P c P.I. Supervisor L 3(2C�Z 1 FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3A-1 I Insp Num: mitBDB210825103250 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3A -II KUPARUK RIV UNIT 3A -I I Src: Inspector Reviewed By: P.I. Supry-� Comm API Well Number 50-029-21458-00-00 Inspector Name: Brian Bixby Permit Number: 185-238-0 Inspection Date: 8/24/2021 Thursday, August 26, 2021 Page 1 of' I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-11 Type Inj w-jTVD 5839 Tubing 2880 2880 2880 2880 - PTD 1852380 - Type Test SPT ',Test psi 1500 IA 410 2010 1960' I96o- BBL Pumped: P - 1.2 BBL Returned: - _—,_ 1.2 OA 270 420 420- 420 Interval 4YRTST P/F P _ --I Notes: Thursday, August 26, 2021 Page 1 of' I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday, February 23, 2019 11:27 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 3A-11 (PTD 185-238) Report of IA Pressure Fall -Off Attachments: 3A-11 AnnComm Surveillance 2.23.19.pdf Hi Chris, KRU injector 3A-11 (PTD# 185-238) is exhibiting IA pressure fall off while on seawater injection. This well is currently online and will be placed on a 60 -day monitor period. During this time DHD will investigate the surface jewelry, perform T & IC PO tests, and if fall-off persists, perform an MIT -IA. Attached is a 90 -day TO plot. Please let me know if you have any questions or disagree with this plan. Sincerely, Well Integrity Supervisor, WNS & CP173 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549(@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Rpgg (-NAV I DATE: Tuesday,August 22,2017 eP.I.Supervisor A1 2; 1(1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3A-11 FROM: Chuck Scheve KUPARUK RIV UNIT 3A-11 Petroleum Inspector SCAMS F4 s Src: Inspector Reviewed By: P.I.Supry S-GP- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3A-11 API Well Number 50-029-21458-00-00 Inspector Name: Chuck Scheve Permit Number: 185-238-0 Inspection Date: 8/3/2017 Insp Num: mitCS170806082712 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-11 Type Inj W 'TVD 5839 ' Tubing 2950 H 2950 • 2950 . 2950 ' PTD j 1852380 Type Test SPT Test psi: 1500 IA 1140 2000 • 1960 1960 BBL Pumped: 0 7 BBL Returned: 0 7 OA 300 400 . 400 400 , Interval 4YRTST P/F P Notes: Tuesday,August 22,2017 Page 1 of 1 of r kts • �`')., I% ��. THE STATE L'c E1_ca 3 T r Cr o r; (7 i 1,1\J sift _, 333 west Seventh Avenue GOVLRNOR SEAN PARNI:I L Anchorage, Alaska 99501-3572 Main: 907 C79 1433 0./z=LAS r i 92;.L, .-<'t2 Theresa Lee Salk° Workover Engineer p_3ConocoPhillips Alaska, Inc. Q -, P.O. Box 100360 0 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-11 Sundry Number: 314-244 Dear Ms. Lee: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. l Commissioner DATED this/ day of April, 2014. Encl. STATE OF ALASKA evrr.�*N'" ,tr.i • '' AU._..A OIL AND GAS CONSERVATION COMMI�._,ONJ,`' \,\ \`� 1,1'i APPLICATION FOR SUNDRY APPROVALS t\ 20 AAC 25.280 g 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell (w Change Apprerram r Suspend r Rug Perforations r Ft rforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 185-238 ' 3.Address: 6.API Number: Stratigraphic r Service r • P.O. Box 100360,Anchorage,Alaska 99510 50-029-21458-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 3A-11 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7350 • 6399 - 7253' 6318' 6762' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16" 106' 106' SURFACE 3179 9.625" 3209' 3121' PRODUCTION 7318 7" 7342' 6392' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6830'-6866',6950'-6970',6972'-7010' 5975-6004',6071'-6088',6089'-6120' 3.5 x 2.875 J-55 6926 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-OTIS RRH PACKER W/XO ' MD=6742 TVD=5904 PACKER-OTIS WD PACKER W/XO TO 2 7/8" ' MD=6897 TVD=6029 SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE - MD=1815 TVD=1815 12.Attachments: Description Summary of Proposal Fr., • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/13/2014 Oil r Gas r WDSPL Ir Suspended r 16.Verbal Approval: Date: WIN J (;I - GINJ r WAG E Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Theresa Lee @ 263-4837 Email: Theresa.M.Lee@conocophillips.com Printed Name Theresa Lee Title: Workover Engineer � � Signature � Phone:263-4837 Date y / y / I y Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness . k`-l.-2.!-V-{ Plug Integrity r BOP Test frMechanical Integrity Test V Location Clearance r R6DMS AY U 8 2014 Other: 6 b p f t 5 t fU 3.5U O R S/ ./-6f,/-c Iv, tnt55C /14lT/A rieT, r�virCd Cifirr .Fa b-i �/ �Gi i c /�, eackrrGeph, .-v)v5f AJC vi th/Lr � Dol/uD abo✓C '/7 pf v" /1-5=-6 3 Spacing Exception Required? Yes ❑ i.•, ❑ Subsequent Form Required: /o — 4 U 4 D b� ` -ie- r' APPROVED BY ��/ a�/� � Approved by: COMMISSIONER THE COMMISSION Date:4-7/1//C/77--- 7' VLF4 f1,7//4,Approved application is valid for 12 months trom thheeM,,,,. date of approval. Form 10-403(Revised 10/2012) 0 R I 6 I N A L(?) 411911�� Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 11,2014 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3A-11 (PTD# 185-238). Well 3A-11 was drilled and completed in 1985 then put on A-sand and C-sand injection in January 1987.3A-11 was shut in July 29th 2011 after a failed MIT-IA. The well is currently SI with a wireline retrievable plug(WRP)set just below the packer at 6,765'. The CMIT-TxIA fails due to IA pressure loss while the CMIT-T passes. The leak detect tool was not able to detect the leak,dropping 1 psi/min for the first 30 minutes then leveling out. IA DDT fails due to IA pressure gain. Tubing MIT-T and DDT passed. The proposed workover will pull the 3-1/2" tubing and re-complete the well with a new 3-1/2" stack packer completion. The new packer set depth is to be determined after the test packer run on rig, if the casing leak is too high to set a packer we will have a 7" casing patch on standby. This Sundry is intended to document the proposed work on the injection well,as well as request approval to workover the well. If you have any questions or require any further information,please contact me at 263-4837. Sincerely, --71AgebeA Theresa Lee RWO Engineer CPAI Drilling and Wells 3A-11 Kuparuk Injector Rig Workover (PTD #: 185-238) Current Status 3A-11 is currently shut-in with a wireline retrievable plug(WRP) set just below the packer at 6,765'. The CMIT- TxIA on 1/27/13 failed due to IA pressure loss.The IA DDT on 1/27/13 failed due to IA pressure gain. Tubing MIT- T and DDT passed.The leak detect tool was not able to detect the leak. Scope of Work The proposed workover will pull the 3-1/2" tubing and re-complete the well with a new 3-1/2" stack packer completion.The top packer set depth will be determined after the test packer run on rig. If the casing leak is too high to set a packer, we will have a 7"casing patch on standby. This Sundry is intended to document the proposed work on the injection well,as well as request approval to workover the well. General Well info / MPSP: 2,806 ps. sing SBHP from 3/15/14 with a 0.1 psi/ft gas gradient Reservoir pressure/TVD: 3 A asi at 6,950'MD(6,072' TVD)SBHP taken on 3/15/14 Wellhead type/pressure rating: FMC Gen III, 11"5K btm x 7-1/16"5K top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T:Passed to 2,500 psi on March 15,2014 MIT-IA: Failed on January 21,2013 MIT-OA: Passed on January 21,2013 Well Type: Injector Estimated Start Date: May 13,2014 Production Engineer: Toon Changludgdee/Suzanne Short Workover Engineer: Theresa Lee(263 -4837/Theresa.M.Lee@ conocophillips.com) Pre-Rig Work Request 1. Lock out SCSSSV. 2. Pull DV from GLM#6 and leave open. 3. Set BPV. Proposed Procedure 1. MIRU 2. Pull BPV. Load well with KWF ppg brine. Ensure well is dead. 3. Set BPV and blanking plug. ND tree. 4. NU BOPE. Pressure test BOPE including annular. Pull blanking plug and BPV. 5. MU landing joint,BOLDS,POOH laying down tubing,and spooling control line. a. If tubing will not pull free,RU E-line and cut tubing in the middle of the first full joint above the SBR. 6. RIH w/casing scraper assembly to just above the packer. 7. RIH w/test packer to determine packer/casing leak location. 8. MU FHL packer assembly and single in on 3-1/2"tubing to just above SBR. a. 7"casing patch on standby if needed. 9. Spot corrosion inhibited brine below the FHL packer. 10. Sting into the SBR until fully located, space out 1 ft. from fully located, drop ball&rod, set the FHL packer. PT the IA. Shear the PBR. 11. Space out with pups,MU hanger,load the well with corrosion inhibited brine, land the hanger,and RILDS. 12. PT the tubing and IA. Shear the SOV. 13. Install the BPV or two-way check. Pressure up on the IA to 1000 psi to test the BPV or two-way check from below. Bleed IA to 0 psi. 14. ND BOPE. NU tree. If BPV is installed,pull BPV and install tree test plug. Test tree. 15. Pull test plug/two-way check. Freeze protect well with diesel. Set BPV. 16. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull ball&rod b. Pull SOV and run GLD c. Pull RHC plug body d. Pull WRP e. RD slickline 4. Return well over to operations. KUP INJ 3A-11 ConocoPhillips a Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APUUWI Field Name Wellbore Status Incl(") MD(ftKB) Act Btm(ftKB) C[xxrorhl. 500292145800 KUPARUK RIVER UNIT INJ 3944 3,600.00 7,350.0 . .. _ ".. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-11.3/18/201410.35'.31 AM SSSV:TRDP Last WO: 35.81 11/17/1985 Vence!schematic(actual -- Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,080.0 2/6/2012 Rev Reason:RESET WRP,SET CATCHER, hipshkf 3/18/2014 _.................................................... GLV C/O HANGER;24.0 . -71 zior - -- _--- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 106.0 106.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(1...Grade Top Thread 1{� I1I SURFACE 95/8 8.921 30.7 3,209.3 3,121.1 36.00 J-55 BTC Y r! Casing Description OD(in) ID(in) Top(1[KB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade -Top Thread •• II 1e1e.PRODUCTION 7 6.276 24.0 7,342.0 6,392.2 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection s TUBING 3.5x2.875 3 1/2 2.99224.0 6,925.6 6,051.7 9.30 J-55 EUE 8RD Completion Details CONDUCTOR;31.0-106.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Corn (in) 24.0 24.0 0.04 HANGER FMC TUBING HANGER 3.500 1,815.3 1,815.3 1.36 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 SAFETY VLV;1,815.3 g 6,715.7 5,882.6 36.39 SBR OTIS SBR 3.000 1 - 6,742.3 5,904.0 36.36 PACKER OTIS RRH PACKER W/XO 2.970 GAS LIFT;2.276.4 6,817.7 5,964.7 36.31 BLAST RINGS BLAST JOINTS(OAL=18')w/RICKERT RINGS(RINGS 2.992 OAL=46') 6,888.4 6,021.7 3633 NIPPLE AVA BPL LANDING NIPPLE(Model 05B w/snap ring No 2.750 Go) 6,891.3 6,024.1 36.33 XO Reducing CROSSOVER 3.5 x 2.875,ID 2.441,#6.5,J-55,EUE 2.875 8RD 6,895.3 6,027.3 36.33 LOCATOR OTIS LOCATOR SUB 3.250 SURFACE;30.7-3.209.3- 6,897.3 6,028.9 36.33 PACKER OTIS WD PACKER w/XO TO 2 7/8" 3.250 6,915.6 6,043.7 36.28 NIPPLE CAMCO D NIPPLE NO GO 2.250 GAS LIFT:4.194.3 • 6,925.0 6,051.2 36.25 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;5,570.1I Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 6,754.7 5,914.0 36.35 CATCHER 2.70"CATCHER(oat0' =88') 3/16/2014 6,762. 5,919.9 36.34 PLUG WEATHERFORD WRP 3/15/2014 0.000 GAS LIFT;6.398.0111 6,888.4 6,021.7 36.33 SLEEVE-C AVA 2.75"BPI W/3/16"PORTS(3 EACH) 9/17/2009 2.310 aPerforations&Slots Shot GAS LIFT;6675.2 Dens Top(TVD) Bier(TVD) (shotstt Top(ftKB) Btm(ftKB) (MO) (IBCB) Zone Date t/ Type Corn \ 6,830.0 6,866.0 5,974.7 6,003.7 C-4,C-3,C-2, 1/9/1986 12.0 IPERF 5"Csg Gun,120 deg ph SBR;6.7157 C-1,3A-11 6,950.0 6,970.0 6,071.4 6,087.6 A-4,A-3,3A- 3/13/1990 8.0 IPERF 21/8"Dyna Strip,60 deg , 11 ph PACKER;6742.3 .m. r-�A( 6,972.0 7,010.0 6,089.2 6,119.9 A-2,3A-11 1/9/1986 4.0 IPERF 4"Csg Gun,90 deg ph Mandrel Inserts ( CATCHER;6,754.7 o at - - Top(TVD) Valve Latch Port Size TRO Run dAH PLUG;6,762.0 N Top(ft Ke) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn ( 2,276.4 2,275.4 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/10/1986 1. 2 4,194.3 3,884.8 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/10/1986 a 0 3 5,570.1 4,970.8 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 (/10/1986 INJECTION;6,779.7 4 6,398.0 5,628.2 MERLA TMPD 1 GAS LIFT DMY BK-2 0.000 0.0 1/10/1996 l.. 5' 6,6752 5,850.0 MERLA TPDX 1 1/2 GAS LIFT OPEN 3/16/2014 illkt/ 6 6,779.7 5,934.2 MERLA TMPD 1 INJ DMY BK 0.000 0.0 3/4/1996 Notes:General&Safety IPERF;6,830.0.6.866.0 End Date Annotation 1/9/2003 NOTE:WAIVERED WELL:Tx IA COMMUNICATION a 11/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 II SLEEVE-C;6888.4, C{" NIPPLE;6,86e.4 ,r1 I ` e \(6\ V\\ LOCATOR;6,995.3 641. 4)6 II PACKER;6,897.3 1...k./ It 1 �j U ,4) NIPPLE;6,915.6 1 V U SOS;6,9250 IPERF;6.950.0.6.970.0 IPERF;6,972.0-7,010.0- PRODUCTION:24.0.7.342.0 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission / ° � DATE: Wednesday, August 31, 2011 TO: Jim Regg�/(q `L SUBJECT: Mechanical Integrity Tests P.I. Supervisor (( ll CONOCOPHILLIPS ALASKA INC 3A -11 FROM: Bob Noble KUPARUK RIV UNIT 3A -11 Petroleum Inspector Src: Inspector NON - CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3A -11 API Well Number: 50- 029 - 21458 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN110802172010 Permit Number: 185 -238 -0 Inspection Date: 7/29/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3A-11 'Type Inj. 1 W i TVD 5904 - IA 2220 3005 .- 2745 2560 2413 'I P. T.D 1852380 - TypeTest SPT Test psi 2900 ' OA 575 555 630 610 590 Interval Required by Variance P/F Fail 1 Tubing 2980 2980 2980 2980 2980 Notes: 2 year MIT -IA. Tubing x IA communication. A O zg .o - Iscileot 4u S i i - /us > ICA, - le$4. - pre / i ,,,. 3 .Zii0. } -.P v A IO:G Wednesday, August 31, 2011 Page 1 of 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3A-11 Run Date: 1/26/2010 February 18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A-11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-21458-00 Injection Profile Log ~ ~x ~ ~~ 50-029-21458-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. ~ ~ ~- Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@1'i~ll~burton.com Date: ~~ " t~s5 - ~3~ ~ ~~I~~ ~1~ 3 Signed: ~ ~~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~1 ~~}} jjt? • ~; ~,€ `~ ~~~ ~0~5 4,~ai_2, _ ~'r,t ~~ ~~~ ~ ~ 1 ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry KV lein 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 Date 411 712 0 0 9 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 ~.~ ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • Well Job # 3~ ~~ ~~ ~ ~~ ~` 3~ 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 iG-09 12100434 INJECTION PROFILE ~ 3 ~ 11/01/08 1 1 2V-11 12061724 PRODUCTION PROFILE S- ~ 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 - j~ 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 1 G-17 11975792 LDL - 11/09/08 1 1 2U-04 12100434 INJECTION PROFILE f~- 11/10/08 1 1 2U-05 12096572 INJECTION PROFILE - ~ --- 11/12/08 1 1 iF-06 12100457 PRODUCTION PROFILE 11/13/08 1 1 iB-06 12080456 PRODUCTION PROFILE 11/13/08 1 1 1 B-05 12080457 INJECTION PROFILE ~(} 11/14/08 1 1 2U-10 12080459 PRODUCTION PROFILE ~- 11/16/08 1 1 2C-15 12100462 PRODUCTION PROFILE Z 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. • .eV 11 1L 10'71J7V) otam. Wiui-GaJGu LVLll"t - i pv;i C11V /_".V1'T rGl�'G 1 Vl J Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TAA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MAOP %1YP AA # 2C -07 7" 26 ppf K-66 4980 3000 60% AIO 213.007 2G -03 7" 26 ppf J -55 4980 3000 60% AIO 213.014 3A -06 7" 26 ppf J -55 4980 3000 60% AIO 213.006 —�3 3A -11 7" 26 ppf J -55 4980 3000 60% AIO 213.022 3A -14 7" 26 ppf J -55 4980 3000 60% AIO 213.026 3H -09 7" 26 ppf J -55 4980 3000 60% AIO 28.009 3N -12 7" 26 ppf J -55 4980 3000 60% NA 3N -13 7" 26 ppf J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TAA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 28.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TxIA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor NOV I ConocoPhillips Alaska, Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 Pager 907 - 659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4:41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 28.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 11/9/2010 L.V - v✓ `1 1L 10 T1 ✓7v) OLaIV WI 1V111 cAty .L.v 1 1 as%. L v1 ✓ • • The AIO 213.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPAI to manage the pressure differently? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 26.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907- 943 - 1720 / 1999 Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 t,v -vj kr i L 10-t i J7V) aLam wituVbbVU ivii i vri Fci city /.i3.v i-r r agv J Ui J 0 0 Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 213.014. What is CPAI using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com) Sent: Friday, May 16, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 28.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xls>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 11/9/2010 3A-l 1 OA HPP pictures Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, April 13, 2008 9:54 AM`" ~ !~ IBS- 2~ o To: DOAAOGCC Prudhoe Bay ~p -~~• ~~-z-z. Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3A-11 OA HPP pictures Attachments: 3A-11 OA HPP.JPG; 3A-11 OA HPP2.JPG; 3A-11 OA HPP3.JPG; 3A-11 OA HPP4.JPG John, Here are the pictures of the OA HPP that we have on 3A-11. Please let me know if you have any questions or need anything else. «3A-11 OA HPP.JPG» «3A-11 OA HPP2.JPG» «3A-11 OA HPP3.JPG» «3A-11 OA HPP4.JPG» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 -~ti~l~.,~~ ~~l Q~,~.. ~- ~~ ~ ~6,.~ Zz ~~~ ~iPR ~ 2D0~ 4/14/2008 Outer Annulus High Pressure Pilot - KRU 3A-11 PTD 185-238 Photos from ConocoPhillips April 13, 2008 ConocoPhillips compliance with condition 4 included in Administrative Approval AIO 2B.022: "Within 30 days of the effective date of this approval, CPAI shall install, maintain and operate automatic well shut-in equipment on the well 's outer annulus. The actuation pressure shall not exceed 1, 000 psi. Testing of the shut-in equipment shall be performed in conjunction with production well pilots and safety valves " ~. ~: - .,~'; t >.. %: OA HPP - KRU 3A-11 AIO 2B.022 ~ ' _ ~. _~~~, >' ~~ Y• `'~ ~M ~H Via, ~ ~' 9 'kti ~~~ s .3 ~,. ~~ .~~. ffi '', a ~ ~~ ~ g fir` ~ 4 `~ t: '~ ~b+.:ss ~a +~ ~'3 '~'.. ? '. 2 3A-11 (PTD 1852380) OA HPP~talled. • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.comj n Sent: Sunday, March 23, 2008 1:11 PM l~~o~ ~~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; NSK Prod Engr Tech Subject: 3A-11 (PTD 1852380) OA HPP installed. ;/ Jim, Here is an update on the OA HPP status for Kuparuk water injector 3A-11. The High pressure pilot has been installed on ~' the OA as per AIO 26.022. It was function tested and tripped at 950 psi prior to the well being returned to water injection. The well was brought on injection on 03/22/08 at 16:16. It will be added to the misc. list for April SVS testing and notice will be given to the inspectors to come over and witness the test. This is the first one of the OA HPP's that have been installed and the well returned to injection. Currently the second one that will be installed will be on 30-14. CPAI will keep you informed as the others are installed, function tested and the well returned to injection similar to this notice. Please let me know if you have any questions or would like more information. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 ~ APR ~ 2~0~ Pager (907) 659-7000 pgr. 909 3/26/2008 ~ RE~EI~JED STATE OF ALASKA NpV 2 '~ ZA07 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOa ~'~ & Gals coos. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ~ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Cevelopment ^ Exploratory ^ 185-238 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21458-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 72' r 3A-11 8. Property Designation: 10. Field/Pool(s): ADL 25631 ' ALK 2564 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7350' feet true vertical 6399' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 106' 16" 106' 106' SURF CASING 3137' 9-5/$" 3209' 3121' PROD CASING 7270' 7" 7342' 6392' ~~~ ~ ~ ~ ~ ~ ~dd~ Perforation depth: Measured depth: 6830-6866, 6950-6970, 6972-7010 true vertical depth: 5975-6004, 6071-6088, 6089-6120 Tubing (size, grade, and measured depth) 2-7/8", J-55, 6926' MD. Packers &SSSV (type & measured depth) pkr= OTIS'RRH' W/XO ; OTIS 'WD' pkr= 6742' ; 6897' SSSV= Camco TRDP 1A-SSA SSSV= 1815' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured) 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 operation N/A N/A N/A N/A N/A Subsequent to operation N/A NIA 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 Q 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: 301-344 contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 11 /23/2007 Form 10-404 Revised 0412004 ~4~ Submit 'giq;~ Q~ ~ fJ/ • • 3A-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/19107 Cancel Sundry #301-344 and replace with AIO 28.022 ~ Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, November 07, 2007 10:27 AM r~ rage i or i ~~~ ~~~ _. _._ To: 'NSK Problem Well Supv' .. ~ -° Subject: RE: Draft Admin Approval -KRU 3A-11 ok Jim Regg N~V ,~ ~ ~~~~ AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~nnnn ~~ ~LiY.Y.~L.S ~ ~~`-.t~ 1 r' V .~ ~~- - ,, u~ ~'~ Lf.: ~~~ ~ ~!- ~~ ~ r~ ~~ ,,~; Q~z~~e,~L ~~~ ~~ ~yt-~ r a,L~' ~~ti Q~ From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] f~~ I (~~l_7 Sent: Wednesday, November 07, 2007 10:14 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs Subject: ~F. nraft Admin Approval -KRU 3A-11 Jim, Gould you please give us a couple of days to review this. I am leaving the slope today and l would like Perry Klein to take a look at it as well before it is finalized. Thank you for the heads up. p`2r~t Rogers Problem Wells Supervisor ConocoPhiliips Alaska, lnc. Desk Phone (907} 659-7224 Ceii Phone (907} 943-1999 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, November 06, 2007 4:42 PM To: NSK Problem Well Supv Subject: Draft Admin Approval -KRU 3A-11 I am providing this draft to you as a courtesy since it contains some different language than what you have seen in other admin approvals. We have included a requirement for an engineered control on the OA to protect from overpressure. We do not believe monitoring alone is sufficient. The Commission has applied this approach to several wells in other fields as away to allow continued injection. Feel free to comment. I plan to final this document in the next couple days. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 11 /7/2007 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, October 16, 2007 1:14 PM ~ ~ To: Regg, James B (DOA) 1~ Subject: RE: Emailing: MIT KRU 3A-11 08-23-07.x1s~~~ Jim, The initial tubing pressure was 2700 psi at the time of the test. Perry -----Original Message----- From: Regg, James B (DOA) [mailto:jim.regg@alaska.govt Sent: Tuesday, October 16, 2007 12:40 PM To: NSK Problem Well Supv Subject: RE: Emailing: MIT KRU 3A-11 08-23-07.x1s Should initial tubing pressure be 2700psi? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~,~~ NOV ~ ~ 2041 -----Original Message----- From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, October 16, 2007 12:14 PM To: Regg, James B (DOA) Subject: Emailing: MIT KRU 3A-11 08-23-07.x1s «MIT KRU 3A-11 08-23-07.x1s» Jim, The well was on water injection at the time of the MITOA. I have changed the form. Please delete the previous test form. Thanks Enclosed is the MITOA for 3A-11.PTD # 185-238. Let me know if you need anything else. Perry Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617Qconocophillips.com 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU / 3A-11 08/23/07 Greenwood ~ ~ ~~I~1~~~ 3~ ~ ~. ~- Packer Depth Pretest Initial 15 Min. 30 Min. Well 3A-11 Type In'. W TVD Tubin 2700 2700 2700 2700 Interval p P.T.D. 1852380 Ty e test P Test psi 1500 Casing 250 2550 2550 2550 P/F P Notes: MITOA -not state witnesed OA 500 800 1740 1720 ~~~~ i Well Type Inj. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. Ty e test Test si Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 2007-0823_MIT_KRU_3A-11.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~é'?1 fA~/D7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPI-llLLIPS ALASKA INC 3A-ll KUP ARUK RIV UNIT 3A- I I FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv rTß,e.... Comm NON-CONFIDENTIAL Well Name: KUPARUKRNUNIT3A-II API Well Number: 50-029-21458-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820161017 Permit Number: 185-238-0 Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3A-ll Type Inj. w TVD 5904 IA 2500 3080 3060 3060 P.T. Lð~¿~ðU TypeTest :SYJ Test psi 1500 OA 500 520 520 520 Interval REQVAR PIF P ,,/" Tubing 2700 2700 2700 2700 Notes: Well has known tubing x lA communication. Pretest pressures were observed and found stable. 3000 psi MIT required every 2 years. ......-- 3 0t1\C\¡J 30 1- 344- ~iÆdeç 7.- ~ R- :~-.::tA SCANNED SEP 1 0 Z007 Wednesday, August 22, 2007 Page 1 of 1 Î) ) MEMORANDUM f7R1J(. TO: Jim Regg ); t ( /' P.I. Supervisor q( I z"ID'" State of Alaska Alaska Oil and Gas Conservation Commission FROM: Jeff Jones Petroleum Inspector DATE: Monday, September 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-ll KUPARUK RIV UN1T 3A-l1 ~'ò r;f~ \ct Src: Inspector Reviewed By: P.I. Suprv:JPß- Comm NON-CONFIDENTIAL Well Name: KUPARUK RlV UNIT 3A-ll Insp Num: mitJJ050909121751 Rei Insp Num API Well Number 50-029-21458-00-00 Permit Number: 185-238-0 Inspector Name: Jeff Jones Inspection Date: 8/30/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. w i TVD - 590d------l_ IA ---- I Well 3A-ll Type Inj. 2725 3240 3230 3210 3210 SPT! Test psi P.T. 1852380 ! TypeTest 1476 I OA 100 100 100 100 100 i --- Tubi;;i! ·----··----1···----- Interval 4YRTST P/F P 2430 2430 2430 2430 2430 .------ I Notes 0.5 BBLS diesel pumped. 1 well house inspected; no exceptions noted. This well has a Sundry: #301-344 for T x IA communicßtion. Test was held an additional 15 minutes to further demonstrate integrity. V ôl:J·Ü\~ ~~EU, 2~ 0 2.0œ] Monday, September 12,2005 Page I of I Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well 19r¡~éJ7z-1D-11 I ~~"';¿513A-11 I ~ Of l' 2U-06 Llf$z~ ~ 3A-15 rK5 -0 if(' 3C-12 7rZ -ðJ? 1A-15 , q "Zd 1 L-09 t I!>" e vJ Job# 10922472 10922478 10922477 10922479 10922482 10922481 10802915 Log Description INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PROD PROFILEIDEFT (REDO-WELL SKETCH) -. .~hættXANNEDDEC 2 82004 Date 10/11/04 10/16/04 10/15/04 10/16/04 1 0/19/04 10/18/04 07/26/04 NO. 3241 \'65-)",33 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: BL DATE: Kuparuk Color CD 1 1 1 1 1 1 1 /o/¿ffif. Please sign and return 0 e opy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 0/22/04 ~7 ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 72 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 ~. r /' service__x Kuparuk Unit 4. Location of well at surface ~/ ../' ',,/ 8. Well number 4509' FNL, 812' FEL, Sec. 7, T12N, R9E, UM (asp's 507634, 5997150) 3A-11 At top of productive interval 9. Permit numbe,r~,~pproval number 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM 185-238" At effective depth 10. APl number 1196' FSL, 3629' FEL, Sec. 7, T12N, R9E, UM 50-029-21458 v'/' At total depth 11. Field / Pool 4069' FNL, 3680' FEL, Sec. 7, T12N, R9E, UM (asp's 5~ 04764, 5997587) Kuparuk Oil Pool 12. Present well condition summer Total depth: measured 7350 feet //Plugs (measured) true vertical 6399 feet Effective depth: measured 7253 feet Junk (measured) true vertical 6318 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 106' 16" 185 sx AS II 106' 106' SURF CASING 3137' 9-5/8" lO5O Sx AS II & 300 Sx Class G 3209' 3121' PROD CASING 7270' 7" 5o0 Sx Class G & 175 Sx AS ~ 7342' 6392' Perforation depth: measured 6830-6886', 6950-6970', 6972-7010' RECEIVED true vertical 5975-6004', 6071-6088', 6089-6120' 2 OOl Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55 Tbg @ 6897' MD; 2-7/8",6.5#, J-55 Tbg @ 6926' MD. /llaska0il & 6as Cons. ~. [Packers & SSSV (type & measured depth) OTIS 'RRH' W/XO @ 6742' MD; OTIS 'WD' @ 6897' MD; CAMCO 'TRDP-1A-SSA' @ 1815' MD. 13. Attachments Description summary of proposal .__X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: December 1, 2001 16. If proposal was verbally approved Oil__ Gas __ Suspended __ Name of approver Date approved Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jerry Dethlefs 659-7224 Signed ~'~"'~--'~~ ~-~ ~--~~ Title: ProblemWellSuperviso, Date JeWel Dethlefs FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~ ~:N~ ~~ ~,~..",~ I Approval_no. Plug integrity __ BOP Test__ Localion clearance --I .Mechanical Integrity Test'~_ ~ ~,"~" ~, j~ Subsequent form required 10- ~,0~-~,,,0'_ '",~\3¢~3 ~"~.~'-.C,~(~'~__~:X:~~,,..,.~ Approved by order of the Commission (..~,~,~.//~~,~ ~ Commissioner Date ~/~'/r2,. Form 10-403 Rev 06/15/88 · O IG1NAL Please return to NSK-69 Approved Copy / ~ P,~turned '~ ~ " SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3A-11 SUNDRY NOTICE 10-403 VARIANCE REQUEST 12/09/01 The purpose of this Sundry Notice variance request is to modify alternative MIT requirements detailed in Sundry Notice 92-012. That Notice specifies RA tracer surveys to be done as the alternative MIT every 2-years. Phillips requests that standard MIT pressure surveys replace the RA tracer surveys to satisfy mechanical integrity requirements. Supporting this request is a successful RA tracer survey completed 3/16/92, and subsequent passing MIT-tubing (against a tubing plug) on 3/4/96, MIT-IA 7/19/98 (State witnessed), and MIT-IA 7/21/01 (State witnessed). A diagnostic MIT-IA by Phillips passed on 8/15/01 @ 3000 psi. The casing and tubing appear to have a one-way type communication; the annulus will MIT OK but slowly pressures up to injection pressure. Whatever leak that may be present is too small to measure. The well will be limited to water-only injection. Phillips proposes the following action plan: ACTION PLAN Well 3A-11 will be subject to the following requirements: 1. 2. o . The well is limited to water-only injection (gas injection is not allowed); Perform an MIl-IA every 2-years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); Should the MITIA fail a tubing plug will be set and an MIT-tubing test performed to show injection is into the approved zones; Shut-in the well and notify the AOGCC should Mil's or injection rates and pressures indicate further communication problems. NSK Problem Well Supervisor 12/09/01 'PHILLIPS Alaska'' Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3A-11 SSSV (1815-1816, -- OD:3.500) SBR (6718-6719, OD:3.500) PKR (6742-6743, OD:6.151) Perf (6830-6866) SLEEVE (6888-6889, OD:2.750) TUBING (0-6897, OD:3.500, ID:2.992) TUBING (6897-6926, OD:2.875, ID:2.441) SOS (6925-6926, OD:2.875) TTL (6926-6927, OD:2.875) Peal' (6950-6970) Perf (6972-7010) KF U 3A-11 · . APl: 500292145800 SSSV Type: Camco TRDP-1A-SSA Reference Loc Well Type: Odg Compltn: Annular Fluid: Last W/O: Ref Log Date: Last Tac 7134 TD 1/2/01 Last Tag Date: Max Hole Angle: INJ 11/17/85 7350 ftKB : 39 deg @ 3600 Angle @ TS: 36 deg @ 6829 Angle @ TD: 35 deg @ 7350 Rev Reason: Update Tag; JWP. Last Update: 1/8/01 ICasing Strings -All:: : Description Size Top Bottom I TVD I wt I Gradel Thread I ICONDUCTOR 16.000 0 I ISURF CASING 9.625 0 I IPROD CASING 7.000 0 73421 6392] 26.00 I J-55 I ITubing Strings - All Description Size Top I Bottom TVo Wt Grade Thread TUBING 3.500 0 6897 6029 9.30 J-55 8RD TUBING 2.875 6897 69261 60521 6.50 I J-55 18RD Perforations Summary Interval TVD ~ Zone ! Status Ft SPF Date. I Type Comment 6830-6866 5975-6004 ~,C-3,C-2,q 136112l 1/9/86 IIPERF15"Cs§Gun, 120degph I 6950- 6970 6071 - 6088 / A-4,A-3~ I 20 I 8 I 3/13/90 I'PERF I;hl/8" Dyna Strip, 60 deg ] 6972- 7010 I 6089- 6120 / A-2 ! I 38 I 4 'l 1/9/86 I IPERFI4" csg Gun, 90 deg ph IGas Lift MandrelsNalves St MD TVD Man Man VMfr VType VOD Latch Port TRO Date I Vlv Mfr Type I Run Cmnt 1 2276 2275 Merla TMPD I DMY 1.0 BK-2 I 0.000 0 1/10/86 2 4194 3885 Merla TMPD i DMY 1.0 BK-2 I 0.000 0 1/10/86 3 I 55701 4971 Uerla TMPD I DMY 1.0 BE-2 t0.000 0 1/10/86 4 6398 5628 Merla TMPD I DMY 1.0 BK-2 I 0.000 I 0 1/10/86 5 6675 5850 Merla TPDX DMY 1.5 T-2 I 0.000 I 0 10/18/96 Injection M andrelsNalves St MD TVD Man Man I V Mfr I V Type I V OD J LatchI Port I TRO I Date I Vlv Mfr Type Run Cmnt 6 6780 5934 Merla TMPD DMY 1.0 BK 0.000 0 3/4/96 Other (plugs, equiP;i, etC.) - JEWELRY Depth TVD Type 1815 118151 sssv 6718 158~41 SBR Otis 6742 I 5904'1 PKR Otis 'RRH' w/XO 6888 16o21 I N~P 6888 16021} SLEEVE 6897 16029 I PER Otis 'WD' 6916 16044 I NIP 6925 60511 SOS 6926 6052 TTL Description Camco 'TRDP-1A-SSA' AVA 'BPL' Landing Nipple AVA 2.78" BPC set 6/17/99 Camco 'D' Nipple NO GO Camco 2.1~2 3.000 2.970 I 2.750 I 2.310 I 3.250 I 2.250 I 2.441 12.441 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 10, 2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice for Phillips Alaska, Inc., well 3A-11. The Sundry regards a proposal to change the approved program for the well. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachments DEC 1 2 2001 OR!GI AL MEMORANDUM , TO: Julie Heusser /,,)' ~'¥' Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 21, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~~rY~~ PhiilipsAiaska P.I. Supervisor 3A Pad ~ ~\-,~'~ 't3 ,,~'(:::~r''~\ 3A-11,14,15 FROM: John Crisp GKA Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. . W~,I ~,, I T~pe'nj-Is'l ~-v-°-'! ~ I~u~"~l ~°l ~°i ~°'! ~o i,~,! 4' . P.T.D.I '1852380 IT~petestl , P, IT,~PS!l 1,~7,'6 I C;.a.gl 2S00'.I. 3O0O I 30~0 1,,30~.. I'P~F i P_ Notes: ' w~,! ~^-,~ IT~"~"ni-.I s '1 ~.v.o. I~o~..ITu.~.~I. ~.~,1 ~0 i~ '1 ~0, li~e,,=,l ~, _ P.T;D.I 1852e20 ITypetestI .......... [P ITestpsiI 150~ , I C~.gI~. ~S25, I 2425 ! 240O I 24OO I P/F I E . ! w~il '~*-~ I~x"e.'nJ-!'''" I T.V.O. I ~"1To~I ~00 'i'~00 I' ~.~"i ~.~00 !,..~,! '4' 1852s,3o ITypetestl . P I Testpsil 1476 I Casingi ~0 I 2150 ! 2125 I 21!0 ! P/F I P_ I '.".' W,~I P.T.D. Notes: . Well~ P~T.D.I ITy..e'ni-I" i T.V.O. I .... ! ~"~J'l I ' i 'i' I"~nte~q' I.T~t.eSt'l I~.t~!l ", I C~"~I ' ! .... I. ' I" . ! "~: I" I T,l(l:)e Ini-J' '1 T.V.o. I 'i ~r~,~n~ I I I ' '! ..... I"n~e~l .... Typetestl I'Testpsil .... ."1 C~ng.! .' .I . ! , .Ii .P~ I ' Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. 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) Te~t's Details 3 MIT's performed, no failures. Annulus pressures were high on the injecting wells. The wells were bled down thc day before State testing. Passed the Standard Annular Pressure tests. M.I.T.'s performed: 3 Attachments: Number of Failures: Total Time during tests: 2 HRS. CC: MIT report form 5/12/00 L.G. MIT KRU 3Ab 7~21-01jc.xls 7/23/01 r,. -/ The following sepia logs were requested to be sent to AOGCC' '~¢' 3A-02 ,,~ RA TRACER SURVEY 3-12-92 ~o ~'.-2,~ ¢~ 3A-11 RA TRACER SURVEY 3-15-92 If you have any questions please contact me at 265-6835. Maria Trevithick Kuparuk Records Clerk ARCO, Alaska Inc. JUN 0 8 ~99~. Alaska 0it & Gas Cons. Commission Anchorage 1. Operations Performed: Operation Shutdown__ Stimulate __ Puli tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: Development ARCO Alaska. Inc, Exploratory _ 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service STATE OF ALASKA ~ OIL AND G/~ CONSERVATION COMMI~QN REPORT OF SUNDRY WELL OPERATIONS Plugging Perforate _ Other ;~ 6. Datum elevation (DF or KB) 4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, RgE, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec.7, T12N, R9E, UM At total depth 1208' FSLr 3684' FWLr Sec. 7r T12Nr R9Er UM 12. Present well condition summary Total Depth: measured 7350' feet Plugs (measured) 6398' feet None RKB 72 7. Unit or Property name Kuparuk River Unit Effective depth: feet Junk (measured) feet None 6972'-7010' 6089'-6120' 8. Well number 3A-11 13. 9. Permit number 85-238 10. APl number so-029-21 458 11. Field/Pool Kuparuk River Field Ku@aruk River Oil Pool true vertical measured 72 5 3' true vertical 631 8' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 06' 1 6" 185 Sx AS II 1 0 6' 1 0 6' Surface 3209' 9 5/8" 1050 Sx AS II & 3209' 3121" Intermediate 300 Sx Class G Production 7342' 7" 500 Sx Class G & 7342' 6392" Liner 175 Sx AS I Perforation depth: measured R CEIVED true vertical 5975'-6004', Aiaska 0ii & Gas Cons. c0mmiss[0n Anchora~(~ Otis RRH ~ 6734'~ Otis WD ~ 6889'~ Cam~ TRDP-1A-SSA SSSV ~ 180~ Stimulation or ~ment squeeze summary Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 6917' Packers and SSSV (type and measured depth) Intervals treated (measured) 14. Treatment description including volumes used and final pressure Tubing Pressure Prior to well operation Re0resentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Subsequent to operation 2000 2100 1700 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1700 2000 1650 16. Status of well classification as: Water Injector X Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUBMIT IN DUPLICATE Form 10-404 Rev 09/12/90 R~....~,rt of Sundry Well Opei..._~ons Kuparuk River Unit Well 3A-11 April 9, 1992 A waiver to run a radioactive tracer type alternative MIT was approved for Kuparuk Well 3A-11 on 12/12/89 (approval number 9-1062). Injection was allowed to continue, under the condition that a radioactive tracer survey would be repeated every two years to confirm that injection is still being maintained within the Kuparuk interval. On January 24, 1992, an Application For Sundry Approval (Form 10-403) was filed notifying you of ARCO Alaska, Inc.'s intent to run a follow-up alternative MIT on Well 3A-11. The survey was performed on March 15, 1992. The AOGCC was notified 24 hours prior, but did not witness the survey. Results from the radioactive tracer survey indicate that all water is entering the A and C Sands. Both the tracer log and a detailed evaluation are attached. Changes in the velocity profile through the tubing are insignificant, and are within tool accuracy. Hot spots shown in secondary runs are indicative of tracer hold-up above doglegs, in mandrels, or adhering to scale. The speed of secondary indications from tracer movement after shots were fired indicates gamma movement must be within tubing, while no movement was detected behind pipe. All tracer measurements and previous leak detection diagnostics indicate the well has casing integrity with no indication of injected water going anywhere except into A and C Sands as intended. / l~)/~ As per the Administrative Approval, Area Injection Order No. 2~4 (December 20, 1~,~992'), this survey will be repeated every two years to confirm that injection is still being maintained within the Kuparuk interval. R CEIVED APR '~ ~ '~aa~ AJaska Oil & Gas Cons. Corarnlss:o Anchorage KUPARUK WELL 3A-11 APl #: SPUD DATE: ORIGINAL RKB: 500292145800 ADL LEASE: 25631 PERMIT #: 11/11/85 COMPLETION DATE: 01/10/86 WORKOVER SURFACE LOCATION: 768'FSL,813'FEL,SEC7,T12N,R9E TOP OF KUPARUK: 1160'FSL,3385'FEL, SEC7,T12N,RgE TD LOCATION: 1208'FSL,3684'FEL, SEC7,T12N,R9E Ail depths are MD-RKB to top of equipment unless olhem,'ise noted 72 TUBING SPOOL: 24 WELLTYPE: WATER INJECTOR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5# H-40 106 9.625' 36# J-55 3209 7' 26# J-55 7342 3.5' 9.3~ J-55 EUE 6917 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1A-SSA 2.812' 1810 SBR OTIS SBR 6713 PKR OTIS RRH 6737 AVA AVA 'BPL' NIPPLE 6883 PKR OTIS WD 6889 NOGO CAMCO 'D' NIPPLE 2.25' 6907 SHROUT CAMCO 6916 STN 1 2 3 4 5 6 INTERVAL 6950-6970 6972-701 o DATE: PAD ELEVATION: 41 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 2271 MERLA TM PD 1' 4189 MERLA TMPD 1' 5565 MERLA TMPD 1" 6393 MERLA TM PO 1' 6670 MERLA TPDX 1.5' 6775 MERLA TMPD 1' PERFORATION DATA ZONE FT SPF PHASE C3 36 12 120 A3 20 8 60V A2 38 4 90 85-238 PORT SIZE .DV .DV .DV .DV .DV .DV COMMENTS SOS 5' CSG GUN ATLAS 2-1/8' 'Ir sos 5" CSG GUN MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 2000 MAX HOLE ANGLE: 39 deg 4600 HOLE ANGLETHRU KUP: 36 (leg LAST TAG DATE: ~ll[,,{ RATHOLE: 129 ft FISH/OBSTRUCTION: PBTD: 7253 PBTDSS: 6246 RECEIVE Alaska Oil .& Gas,,~:,o,r'*-':*'- Co[~,,missio¢ REVISION DATE: 02/05/90 REASON: UPDATE 3A-11 Radioactive Tracer Survey Evaluation and Summary March 15, 1992 1. RA Tracer Inlection Velocity check thrOUah entire tubina: Velocity profile measured peak-to-peak is: From Time To Time Velocity KDGS Rate (bw_ud) 200' 12:27:30 2000' 12:48:12 1.48 fi/sec 1055 2000' 12:48:12 4000' 13:10:47 1.48 fi/sec 1051 4000' 13:10:47 6000' 13:33:28 1.47 fi/sec 1048 6000' 13:33:28 6865' 13:43:39 1.41 fi/sec 1045 Result: Velocity Ranges are within +/- 4%. No Leakage detected. Note: At 6865', just above AVA, received indication that tracer was moving into C sand perfs. Time between detectors is 30 second which corresponds to a annular capacity three times the tubular. 2. Baseline Vs. Secondary_ Gamma Ray Log The secondary gamma ray log shows four new hot spots in the tubing which are washed away by the time of the third GR log. Hot SDOt TOD Hot Soot Bo~om Dogleg 5540' 5590 None 5940' 6030' @5800' 6320' 6450' @6500 6730' 6745' @6800 Hot spots are an indication of either tracer adhering to scale build-up in tubing, tracer hold-up in mandrels, or tracer settling above severe doglegs in tubing. This is supported by the hot areas having a uniform front with no point of intensity. There are severe doglegs as detected in the Gyro survey occurring at the lower three hot spots which make it possible for the tracer material to settle out. 3. Ra Tracer Injection velocity checks at various ooints To check for fluid loss at the top three hot spots, additional Ra slugs were injected to measure time between top and bottom detector as an indication of velocity. Detectors are 15.9 feet apart. De~h Time between detemors Vel0cify Rme 5380' 7.5-8 sec 2.1ft/sec 1051bwpd 5930' 7.5- 8 sec 2.1f t/sec 1047 bwpd 6080' 8 sec 2.0fl/sec 1042 bwpd Result: Velocity ranges are within +/- 4%. Confirms no leakage detected. RECEIVED AIaska Oil & Gas Co~,s. Comm[ssio~ ~nch0re-§~ 4. Check for movement below ToD Packer: Procedure: Inject Ra tracer slug at 6770' (below upper packer) and monitor flow down tubing and wait for secondary kick to indicate movement up behind pipe. Result: Kick passes detectors and no secondary kick detected indicating no movement up behind pipe. . Check for Leakaqe above U_o_Der Packer: Procedure: Inject Ra tracer slug at 6660' (above upper packer) and monitor flow down tubing and wait for secondary kick to indicate movement up behind pipe. Result: Kick moves down tubing and passes detectors, then is detected 26.5 minutes later. The top detector is receiving the RA signal prior to the bottom detector which indicates the tracer is moving down relative to the detector. The time between detectors is 25 sec and if the tracer is in the annulus this means it is going 0.636 ft/sec which corresponds to an annular velocity of 1450 bwpd. This is impossible because the well is only injecting 1050 bwpd, therefore the tracer can not be coming down annulus. The second detection may be break away tracer that had been held up in the tubing. Velocity indicates it must be in the tubing. Therefore, no movement behind pipe. 6. Check for Leakaae across Uooer Packer: Procedure: Inject Ra tracer slug at 6715' (straddling upper packer) and monitor flow down tubing and wait for secondary kick to indicate movement up behind pipe. Result: Slug passes detectors down tubing with no increase in gamma observed after waiting 32 minutes. The ejector and first detector are above the packer while the second detector is below the packer. Indicates no movement across packer. 7, Fin;~l Gamma Ray Log A third gamma ray Icg was run after all shots were taken which showed that all of the above hot spots were gone except for the following: 6735'-6745' 6890'-6920' 6970'-7010' At Upper Packer Below lower PKR and at TBG tail At Lower A Sand Perfs Result: Previous leak detection diagnostics indicates that there may be a minor leak across the upper packer. The tracer log and leak detection diagnostics show that there is casing integrity above that point. Summary_ No indication of injected water going anywhere except into C and A Sands as intended. Alaska Oil & Gas Cons. Commission Anch0ta~ ARCO Alaska, Inc. Post Office B~'x'~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk well. Well Action 3A- 11 Alt. MIT 3G-23 Cony to Wtr. Inj. Anticipated Start Date February, 1992 February, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) (w/o attachments) RECEIVED JAN 2 1 ~992 Alaska Oil & Gas Cons. Commissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE Of ALASKA A~ OIL AND GAS CONSERVATION COMMI~iON APPLICATION FOR SUNDRY APPROVALS I1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown Re-enter suspended well Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other _~_ 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec.7, T12N, R9E, UM At total depth 1208' FSL~ 3684' FWL~ Sec. 7~ T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit Jeer 8. Well number 3A-11 9. Permit number 85-2:~8 10. APl number 5o-029-21458 11. Field/Pool Kuparuk River Field River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 0 6' Surface 3 2 0 9' Intermediate Production 73 4 2' Liner Perforation depth: measured 6830'-6886', true vertical 5975'-6004', Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 6917' 13. 7350' 6398' 7253' 6318' Size 16" 9 5/8" 7" Packers and SSSV (type and measured depth) Otis RRH Attachments feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 185 Sx AS II 1 06' 1 06' 1050 Sx AS II & 3209' 31 21' 300 Sx Class G 500 Sx Class G & 7 3 4 2' 6 3 9 2' R' ¢EIV D 6972'-7010' 6089'-6120" JAN 2' 1 ' 992 0ii & Gas O0r~s. C0mrnissi0~ Anchorage 6734', Otis WD @ 6889', Camco TRDP-1A-SSA SSSV @ 1807' Description summary of proposal X Detailed operation program BOP sketch 14. Estimated date for commencing operation 2/1/92 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as' Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C~- ~,)- ~ Title Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ --BOP Test Mechanical Integrity Test '~' /, Approved by order of the Commission Form 10-403 Rev 09/12/90 Location clearance m Subsequent form require 10- ORIGINAL SIGNED BY / - LONNIE C, Commissioner Dale SUBMIT IN TRIPLICATE Kuparuk Well 3A-11 Per your request during a phone conversation on 1/14/92 (C. Strickland with L. Smith), ARCO Alaska is notifying you that we are preparing to run a follow up alternative MIT test on Kuparuk injection Well 3A-11 per the attached procedure. This work is being done per approval number 9-1062 approved on 12/12/89. Scheduling of the job will be reported to you via the weekly well work summary forwarded to you each week as part of Conservation Order #261. ARCO will also notify you at least 24 hours in advance of performing this work so that you may choose to witness the work. RECEIVED JAN 2 1 1992 Alaska OiJ & Gas Cons. Commission ;Anchorage Radioactive Tracer Survey Water Injection Well 3A-11 Cost Code 230DS36AL Summary The C Sand will be reopened prior to starting the Radioactive Tracer (RAT) survey. This is necessary to ensure that we meet state requirements and will provide the opportunity to perform the A/C split work in the second half of the procedure. After opening the C Sand, the alternative MIT will be done to verify that all of the injected water is entering the Kuparuk formation. After performing this, we will do a step rate test with the RA tool placed immediately above the top A Sand perf. We will use the RA tool to measure A Sand rates during the step rate test. This data will then be combined with the total well injection rates (from KDGS) to provide A/C split data. Both the A and C Sand Injectivity Indexes (lis) will be calculated. The C Sand will then be shut in and injection returned to the maximum rate possible. . . . Slickline Work RIH and Tag fill. Last tag was at 7139' MD on 5/25/87. Replace blanking sleeve @ 6883' MD with commingling sleeve. Establish injection rate of 2000 BWPD. If 7" casing pressure exceeds field operating guidelines (2000 psi), inject max. possible. Electric Line Work Note: Ensure that enough RA Tracer material (Iodine 131) is loaded in tool to complete both the alternative MIT work and A/C split data gathering work prior to RIH. Alternative MIT Steps 4-11 are done to verify tubing integrity: . Notify the State at least 24 hours in advance of starting the alternative MIT so that they can witness if desired. . Prior to the test, verify that the injection rate has been stable around 2000 BWPD (or rate established in Step 3) for several days. Pertinent PVID numbers are: 14703 (pressure) and 14705 (rate). . Print out injection rate and pressure every minute during the Radioactive Tracer Survey. Submit the KDGS data with the survey results. , MIRU EL unit. RIH with HP/GR/CCL/RA tracer tools to TD. Tie in to SOS CET dated 12/15/85. Run baseline GR/CCL from TD to surface. Do not eject any RA tracer material prior to running baseline GR/CCL log. RIH to 200' and park tools. R E 6 ~ j V E ~) JAN 2' I '~992 Alaska OJJ & Gas Cons. Oommission Ar~chorage Radioactive Tracer Survey Water Injection Well 3A-11 (page 2) . Eject RA tracer slug @ 200', record time. RIH to 2000' as quickly as possible. Monitor and record time when "hot" GR kick indicates passage of RA tracer material. Repeat these "timed-run" detector stops at 4000', 6000', and 6865' (immediately above AVA). All these stops will be detecting the same ejected RA tracer slug and will be used to verify that the water velocity is constant in the tubing (indicating no leakage). 10. If results from step 9 indicate that fluid loss is occurring within the tubing, repeat step 9 for confirmation. 11. Allow RA tracer slug to exit the wellbore. Run secondary GR/CCL Icg from TD to surface to check for any "hot" spots that differ from the baseline Icg that may indicate fluid loss from the tubing. Steps 12-14 are done to check jewelry: 12. RIH to 6690' (above SBR). Eject RA tracer slug. Stay at 6690' for 30 minutes and monitor for a secondary "hot kick" which would indicate behind pipe fluid movement upward. 13. RIH to 6800' (just above upper C Sand perf). Eject RA tracer slug. Stay at 6800' for 30 minutes and monitor for a secondary "hot kick" which would indicate behind pipe fluid movement from the C Sand area upward past the upper packer into the 7" annulus. 14. If any of the above steps show any signs of fluid movement behind pipe, conduct additional tracer shots and Icg monitoring to determine potential leak location in the 7" casing. Step Rate Test 15. Continue printing out injection rate and pressure every minute during the step rate test. 1 6. RIH to 6935' (between tubing tail and top A Sand perf). 17. Inject RA Tracer slug and monitor time required to travel past detector. Repeat enough to verify consistency. Record bottom hole pressure. 18. Calculate A Sand injection rate. Compare to values on KDGS. Calculate NC split. Start plotting rate vs. bottom hole pressure data to calculate injectivity index for each sand. Note: Flow Rate (BWPD) = Velocity (ft/min) * 55.15 19. Increase injection pressure and let stabilize. Increase injection pressure enough so that five NC splits are measured between original WHP (that during the alternative MIT) and the maximum possible injection pressure (2500 psi). Monitor KDGS to determine appropriate stabilization time required with each increase. RECEIVED JAN AJaska 0il & Gas Cons. Commission 20. 21. 22. 23. 24. Radioactive Tracer Survey Water Injection Well 3A-11 (page 3) Repeat steps 17-19 until max injection pressure is obtained. Eject all excess RAT. POOH. Reduce injection rate to meet field operating guidelines (2000 psi 7" pressure) until Step 23 performed. $1ickline Work Replace commingling sleeve @ 6883' MD with blanking sleeve. Return well to maximum injection rate possible. RECEIVED ~'1 J,~.N 2 1 t992 0ii & Sas Cons. Gomrr~[$$Jon Anchorage ARCO Alaska, Inc. Post Office '~'"~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the First Quarter, 1990. The data is provided in the form of separate zone surveys or as spinner logs listed in Attachment 1. Injection rates determined by separate zone surveys are also listed in Attachment 1. The blue line and sepia-copies of the spinner logs are also included. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, S. E. Schmidt Operations Engineer SES:LLP Attachment ARCO Alaska. Inc, is a Subsidiary of AtlanticRich-~Je~dComp~ny ATTACHMENT 1 WELL APl NUMBER NUMBER 50- KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES FIRST QUARTER 1990 SUBMITTAL DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY SURVEY 1F-10 02920984 10/28/85 ' IF-15 02921025 08/16/84 ,, 1G-02 02920813 10/11/85 18-03 02920824 10/25/85 10-09 02921001 09/15/84 10-16 02921031 08/24/84 19-03 02921406 11/19/85 19-15-, 02921387 11/10/8~ 2B-07 02921080 07/12/86 ~,)2B-08 02921079 11/07/85 2B-lO 02921084 11/09/86 2U-05 02921269 2U-lq 02921262 2U-16 02921264 ~ 3A-02 02921431 03/31/90 SEP ZONE FOLLOWUP 03/31/90 SEP ZONE FOLLOWUP 03/16/90 SEP ZONE FOLLOWUP ~3A-1~ 02921458 03/30/90 SEP ZONE FOLLOWUP 02/06/89 SEP ZONE FOLLOWUP 03/30/90 SEP ZONE FOLLOWUP 03/04/90 SEP ZONE FOLLOWUP 03/07/90 SEP ZONE FOLLOWUP 03/06/90 SEP ZONE FOLLOWUP 03/25/90 SPINNER FOLLOWUP 07/02/89 SEP ZONE FOLLOWUP 11/19/85 03/29/90 SEP ZONE FOLLOWUP 04/09/90 SEP ZONE FOLLOWUP 11/14/85 03/29/90 SEP ZONE FOLLOWUP 03/14/90 SEP ZONE FOLLOWUP 01/14/86 03/25/90 SEP ZONE FOLLOWUP 03/18/90 SEP ZONE FOLLOWUP 01/27/87 03/10/90 SPINNER FOLLOWUP 01/21/87 01/14/90 SPINNER FOLLOWUP WELL COMPLETION A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS ZONES TAKING WATER A C A C A C A C A C A C C C C C C ¢ C INJECTION BWPD 4.08 MMSCFD 2.00 MMSCFD 3.44 MMSCFD 1.55 MMSCFD 8OO 5000 800 3600 1000 3000 '120 5400 2250 1775 2150 1650 2500 2800 1150 2350 1500 2200 3150 2200 4200 2000~ --" ~. 1375 i652 1374 235 5665 45O 00010000 00020000 00030000 00040000 00050000 00060000 00070000 0OO8OO0O 00090000 00100000 OO110OO0 00120000 00130000 00140000 00141000 00142000 00142100 00142200 00142300 00143000 00150000 00160000 00170000 00180000 00190000 0020O000 002100O0 00220000 00230000 00240000 00250000 00260000 00260102 00260202 00260302 00260403 00260503 00260604 00260704 ' 00260804 0026O903 00261004 00261104 00261204 00261304 00261404 00261504 00261600 00261700 00261800 00261900 00262000 00262100 00262200 00262301 00262401 00262501 00262601 00262700 00262800 00263000 00264000 00265000 ARCO Alaska, Inc. _ Post Office B~'~'x 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 April 11, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTION 3A-11 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlaniicRichfieldComNany -.._~, STATEOF~ ALASKA OiL AND CAS CONSeRV^TION coMM ioN REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutd(~wn ~ Stimulate __ Plugging m Perforate _~_ Pull tubing __ Alter casing __ Repair well __ Pull tubing m Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec. 7, T12N, R9E, UM At total depth 1208 FSL, 3684' FEL~ Sec. 7~ T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7 3 5 0' true vertical 6398' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 72' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-11 9. Permit number/Approval number 85-238/90-104 10. APl number 5o-029-21458 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7253' true vertical 6318' feet Junk (measured) feet Casing Length Size Cemented Measured depth True vertical depth Conductor 1 06' I 6" Surface 3209' 9 5/8" Production 7342' 7" Perforation depth: measured 185 Sxs AS II 106' 106' 1050SxsASII & 3209' 3121' 300 Sxs Class G 100 Sxs ASI Top Job 500 Sxs Class G 7 3 4 2' 6 3 9 2' 175 Sxs AS I 6830'-6886', 6972'-7010' 6950-6970' true vertical 5975'-6020', 6089'-6120' 6071 -6087' Tubing (size, grade, and measured depth) ~~7~'~"~'~ '~ ~~. 3 1/2", J-55, 9.3#, TT @ 6917' Packers and SSSV (type and measured depth) Otis RRH packer ~ 6734'/Otis WE packer@6889'/Camco TRDP-1A-SSA SSSV@18 .~ ]_ · 13. Stimulation or cement squeeze summary . Attached report details perforating work. ~4o~o~,~ Intervals treated (measured) Treatment description includin~l volumes used and final pressure '~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pre~e Prior to well operation Subsequent to operation 3500 24OO 2OOO 3800 2400 2000 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended __Service WATER INJECTOR 117. , ~~ t.~h: foregoing is true and correct to the best of my knowledge.~/ ~ I Signed Title Sr. Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CONTRACT, OR ~ / AT REPORT TIME MARKS WELL SERVICE REPORT IDAYS ~DATE-~_ / / / I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather TemP.Report ~F [ch'Il Factor I vlslbility"FI miles Iwind vel' 1. Type of Request: 2. Name of Operator OIL AND GAS CONSERVA APPLICATION FOR SUNDRY APPROVALS ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 i4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, RgE, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec. 7, T12N, R9E, UM At total depth 1208 FSLr 3684' FELt Sec. 7~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 7 3 5 0' true vertical 6 39 8' Operation Shutdown m Stimulate __ Pull tublnl~_ Alter casing m 5. Type of Well: Development Exploratory ._ Stratigraphic - s ce feet feet Effective depth: measured 7253' feet true vertical 6318' feet Casing Length Size Conductor Surface Plugs (measured) Production Plugging __ Perforate X Repair well ..._ Pull tubing ~ Other Junk (measured) 6. Datum elevation (DF or KB) 106' 1 6" 185 Sxs AS II 106' 3209' 9 5/8" 1050 Sxs AS II & i 3209' 300 Sxs Class G 100 Sxs ASI Top Job 7342' 7" 500 Sxs Class G 7342' 175 Sxs AS I Perforation depth: measured 6830'-6886', 6972'-701 0' true vertical 5975'-6004', 6089'-6120' Tubing (size, grade, and measured depth) 3 1/2", J-55, 9.3#, TT @ 6917' Packers and SSSV (type and measured depth) Otis RRH [3acker ~ 6734' Otis WD @acker~6889' Camco TRDP-1A-SSA SSSV~1807' 13. Attachments Description summary of proposal X Detailed operation program _ ..ADD 20' OF PERFORATIONS TO A-3 SAND LOBE feet RKB 72' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-11 9. Permit number 85-238 10. APl number .so-029-2145~ 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool True vertical depth 106' 3121' 6392' :EB 1 6 Anch0ra BOP sketch 14. Estimated date for commencing operation 15. Status of well classlfi~ation as: FEBRUARY 1. 1990 Oil m Gas 16. If proposal was verbally approved o,-/ / Name of approver L, --~ ~ / / ~ Date approved Service W~,T E R ~ I NJ ECTO R 17. I hereby certify that the foregoing is true and correct to/~ best of my knowledge. Signed 2/~ L.~ ' .,c~,'~''~' Title ."~.. ~'' ~ - - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form require 10- ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH Commissioner Approved Copy F~etur0ed- Suspended IIAppr°val No/(~_ Date .~-'/.~)/~0 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kupaxuk River Unit Well 3A-11 Additional Perforations Well 3A-11 is currently perforated in the A-2 Sand Lobe, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to add 20' of perforations in the A-3 Sand Lobe in this water injection well. A Wireline BOPE will be used during the perforating procedure. Static Bottom-Hole Pressure is expected to be 3300 psi in this well. No workover fluid will be used during the perforating procedure. 1. Type of Request: 2. Name of Operator ARGO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec. 7, T12N, R9E, UM At total depth 1208.FSL~ 3684' FEL~ Sec. 7~ T12N~ R9E~ UM ~ OIL AND GAS OONSEF~A~ REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown._ Stimulate .... Pull tubin~i __ Alter casing _._ 5. Type of Well: Development _. Exploratory _.. Stratigraphic _. 99510 Service 7350' 6398' 12. Present well condition summary Total Depth: measured true vertical Plugging m Pedorate _ Repair well ~ Pull tubing ~ Other X 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-11 g. Permit number 85-238/9-1062 10. APl number so-029-21450 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet feet Plugs (measured) Effective depth: measured 7253' true vertical 6 31 8' feet feet Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Conductor Surface 1 0 6' 1 6" 185 Sxs AS II 3209' 9 5/8" 1050 Sxs AS II & 300 Sxs Class G 100 Sxs ASI Top Job 7342' 7" 500 Sxs Class G 175 Sxs AS I Production Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 6830'-6886', 6972'-7010' 5975'-6004', 6089'-6120' 3 1/2", J-55, 9.3#, TT @ 6917' Packers and SSSV (type and measured depth) 106' 3209' 7342' 106' 3121' Otis RRH packer ~ 6734'/Otis WD packer@6889'/Camco TRDP-1A-SSA SSSV@1807' 13. Stimulation or cement squeeze summary Attached report details Radioactive Tracer Survery Alternative MIT Results & Conclusions Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1880 2050 1550 '3500 2400 2000 16. Status of well classification as: Oil Gas Suspended __Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~nedForm 10-4~04~ ~061'5/~88 ~'l/~/~'''~'/v / Title Sr. Operations Enc~ineer SUBMIT IN bUPLI~ATE ATTACHMENTS REPORT OF SUNDRY WELL OPERATIONS KUPARUK RIVER UNIT WELL 3A-11 An Application for Sundry Approval (#9-1062) was filed with the State on December 7, 1989 for Kuparuk River Unit Well 3A-11. The Application detailed a procedure for running a Radioactive Tracer Survey Alternative MIT on water injection well 3A-11. As detailed in that Application, the purpose of the Survey was to prove that no "out-of- zone" water injection is taking place in this well. The Application also stated Arco's request that water injection be allowed to continue if no out-of-zone injection was detected. As listed in the State rules, a radioactive tracer survey will be repeated every two years to confirm that injection is still being maintained within the Kuparuk Interval. This Report of Sundry Well Operations details the Radioactive Tracer Survey Alternative MIT which was conducted on January 14, 1990 on Well 3A-11. The attached Evaluation sheet summarizes the steps taken during the logging, and their results. Also attached is a copy of the actual Service Company log and a sequence of events. In summary, all portions of the test indicated that no out-of-zone injection was taking place, and that the well passed the conditions of the Radioactive Tracer Survey Alternative MIT. As discussed verbally with the Commissioners, this RTS was conducted at a 2000 bwpd injection rate, the maximum injection rate at which the radioactive tracer tools could be accurately run in this mechanical tubing configuration. The Commissioners verbally agreed that as 2000 bwpd was a mechanical testing limit, a successful test at 2000 bwpd would not limit actual injection to 2000 bwpd, and injection at higher than 2000 bwpd would be allowed. Therefore Arco intends, with the approval by the State of this Report of Sundry Well Operations, to maintain water injection at rates of 2000 bwpd or greater into this well as proposed in the Application for Sundry Approval #9-1062. 3A-11 RADIOACTIVE TRACER SURVEY EVALUATION & SUMMARY 1/14/90 I · 7 . 1 Beseline GR Loa vs follow-up GR Logs: No "hot spots" in GR log, no indication of leakage. Ra Tracer In!ection Velocity check through entire tubing- TRAVEL TOTAL VELOCITY EVENT DEPTH TIME FROM INJ POINT a) Eject Tracer Shot 200' Detect 1 9 0 0 b ) Eject Tracer Shot 1 9 0 0 Detect 3 6 0 0 c ) Eject Tracer Shot 3 6 0 0 Detect 5 2 0 0 d) Eject Tracer Shot 5200 Detect 6 8 0 0 640 sec 159.4 FPM 644 sec 158.4 FPM 610 sec 157.4 FPM 615 sec 156.1 FPM Result: Velocity ranges are within +/- 2%. No leakage detected. * Multiple shots necessary because turbulence dissipated single shot Che~k for Leakage across PBR/Upper Packer: A) Procedure' B) Result: Inject Ra tracer slug @ 6719' (just above upper packer), leave detector at 6719' for 30 minutes to look for behind pipe fluid movement from the C Sand area upward past the upper packer into the 7" annulus. Do not see subsequent GR kick indicating PBR/Upper Packer leak. Check for Leakaoe from C Sds to 7" annulus: A) Procedure: B) Result: Inject Ra tracer slug @ 6800' (below upper packer, above AVA sleeve and C Sand perfs), leave detector at 6800' for 30 minutes to look for behind pipe fluid movement from the C Sand area upward past the C Sand perfs toward the upper packer into the 7" annulus. Do not see subsequent GR kick indicating PBR/Upper Packer leak. SUMMARY: No indication of injected water going anywhere except into the A and C Sands as intended. ARCO Alaska, Inc. ~ WELL SERVICE REPORT Subsidiary of Atlantic Richfield Compare, ~ .~.~.~o. ~x~~~.~,~~ I°~"''°"~"~"~'"~ ~~~~ :ow..- ~P~-'~ ~/z__ s~-:x¢ I,¢'5¢' / [~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [ Temp. [ Chill Factor Visibility {Wind Vel.Report ' 'F "F miles · REMARKS CONTINUED: Do~ ~ - 70'ZZo I DESCRIPTION CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS j DAi~,)~ LiOO ACCUM. TOTAL DOWELL I HALLIBURTON ARCTIC COIL TUBING j " I FRACMASTER B. J. HUGHES Roustabouts Methanol- Supervision Pre-Job Safety Meeting AFE I TOTAL FIELD ESTIMATE ARCO Alaska, Inc. ~ Post Office B~,, 100360 Anchorage, Alaska 99510-0360 Telephone 907' 276 1215 December 7, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton. Attached are two Sundry Notices for well 3A-11 The first is a Report of Sundry Well Operations detailing diagnostic work completed t~) determine the location of a tubing to casing communication. The second sundry is an ApPlication for Sundry Approval to perform a Radioactive Tracer type alternative attached in duplicate and the ApPlication Sundry MIT. As usual the Report Sundry is is attached in triplicate. If you have any questions, Please call me at 265-6840. Sincerely, G. B. S~/~Wood Senior Operations Engineer CC: J. Gruber J. R, Brandstetter ATO 1478 L. Perini ATO 1120 · KOE1.4-9 ATO 1130 RECEIVED DEC 1 1 Alasl~ 011 & Gas Cons. commbslo~ Anchorage w/o attachments ARCO Alaska, Inc. is a Subsidiary of AllanticRich[ieJdCompar)y STATE OF ALASKA ~ AI_A,.~ OIL AND GAS CONSERVATION COMMISSION 0 REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging __ Perforate _ Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec. 7, T12N, R9E, UM At total depth 1208 FSL, 3684' FEL, Sec. 7, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7 3 5 0' feet 6398' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 72' feet 7. Unit or Property name Kuparuk .River Unit 8. Well number 3A-11 9. Permit number/approval number 85-23~/7-;~44 10. APl number 50-029-21458 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7253' feet true vertical 6318' feet Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 1 0 6' I 6" 185 Sxs AS II Surface 3209' 9 5/8" 1050 Sxs AS II & 300 Sxs Class G 100 Sxs ASI Top Job Production 7342' 7" 500 Sxs Class G 175 Sxs AS I Perforation depth: measured true vertical 6830'-6886', 6972'-7010' 5975'-6004', 6089'-6120' Tubing (size, grade, and measured depth) 3 1/2", J-55, 9.3#, TT @ 6917' Packers and SSSV (type and measured depth) 106' 106' 3209' 3121' 7342' 6392' Otis RRH packer ~ 6734' Otis WD packer@6889' Camco TRDP-1A-SSA SSSV@1807' 13. Stimulation or cement squeeze summary Attached report details investigative work to determine TBG/CSG Pressure communication location Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure - 1250 1840 - 0 1000 Tubing Pressure 1570 0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 I~ev "06/T5~88 Title Sr. Operations En~lineer SUBMIT IN DUPLICATE REPORT OF SUNDRY ATTACHMENTS KUPARUK RIVER UNIT WELL 3A-11 Attached is a 3 page sequence of events detailing work done to date to determine the location of suspected tubing to annulus pressure communication in Kuparuk River Unit Well 3A-11. This sequence of events Icg is intended to serve as the Daily Report of Well Operations, as requested on the Report of Sundry Form. Although the 3 page sequence of events details the entire history of the well, the pertinent information relating to the investigative work spans the time period from August 30, 1989 (when the well failed a State Witnessed Pressure Type MIT) to November 30, 1989, when the investigative work to identify the pressure communication location was complete. MINI WELL HISTORY: , Well 3A-11 converted to Water Injection Service in January 1987. Passed State Witnessed Pressure Type MIT on 1/16/87. . Indications of minor tubing to annulus pressure communication were first seen on Well 3A-11 in May 1987. . Application of Sundry (Approval #7-344) filed with State on May 22, 1987. Application states that tubing to annulus pressure communication is suspected and will be investigated, but is not yet a major problem. Well has passed MIT. . Various investigative work and corrective action takes place in 1987- 1988 time frame. None of this work successfully located the pressure communication location. . Water Injection Well 3A-11 failed a State Witnessed Pressure Type MIT on 8/30/89. . Investigative Plan of Action developed, investigative work begins. During investigative work, well remains shut-in except when needed on injection to complete testing procedures. By end of November 1989, investigative work is complete. RESULTS OF INVESTIGATION: , Pressure communication location is a top packer of selective single completion. . Top packer "leak" location is very small. Prevents well from passing Pressure Type MIT, but does not appear to be large enough to pass a significant volume of fluid. CURRENT PLANS: . Complete Application of Sundry to use Alternative Type MIT (radioactive tracer survey) to prove well has casing integrity. If well passes Alternative Type MIT, return well to water injection serviceR E (~ I V'!~'D Oil & Gas ~.0~1~. 3A-11 PROBLEM WELL ANALYSIS LOG OF EVENTS 1/10/86 1/1 6/87 1/20/87 5/14/87 8/30/89 9/24/89 9/29/89 1 1/05/89 Initial Completion. NO RECORD OR INDICATION OF TBG/ANN PRESSURE COMMUNICATION PROBLEMS WHILE WELL WAS A PRODUCER. State witnessed MIT (passed). a) Bleed 7" annulus from 2100 to 1200 psi. b) SITP = 500 psi, Start pumping diesel down 7" annulus. Pump 29 bbls c) SITP = 500 psi, 7" P = 2150 psi. Both hold constant for 30 minutes. Convert to WI Sundry Application filed to investigate suspected Tbg/Ann communication Completed State witnessed MIT. While actively injecting at WHP = 1600 psi, 7" annulus pressure was increased to 2380 psi. 7" pressure bled off from 2380 psi to 2280 psi in 15 minutes, then to 2120 psi after 30 minutes. WELL FAILED STATE WITNESSED PRESSURE TYPE MIT. RU pump to 7" annulus, attempt to establish sufficient diesel injection rate into 7" annulus to enable EL Spinner type leak detection log to be run in tubing. Leak apparently not large enough to maintain sufficient inj rate for EL leak detection log. Pumped approximately 70 gallons fluid in 1 hour, 45 minutes. COMMENT: COMPLETED STEP I OF LEAK DETECTION PLAN OF ACTION (DATED 9/21/89). PROVED THAT LEAK IS TOO SMALL TO IDENTIFY WITH E-LINE SURVEY. Displaced tubing with 64 bbls of 60/40 MeOH in preparation for step 2b of Leak Detection Plan of Action (dated 9/21/89). Well pickled and SI to water injection. Set tubing test plug at 6690' WLM (top of SBR). Tbg P = 1050 psi, 7" P -- 915 psi. Increase Tbg P to 2000 psi, hold for > 45 minutes. Increase Tbg P to 2800 psi, hold for over 1 hour, 7" pressure holding at 915 psi. Appears to show good pressure test, but lines on chart recorder freeze off, preventing recorded documentation. PRESSURE TEST WITH TEST PLUG @ 6690' INDICATES NO LEAK PRESENT IN TUBING BETWEEN SURFACE AND 6690' (INDICATES ALL DV'SIN GLM'S HOLDING). RECEIVED DEC ]., 1_ OiL & Gas _C onm 11 ~05~89 (cont) 1 1/1 2/89 11/1 3/89 11/1 4/89 11/1 5/89 Set test plug @ 6752' WLM (top of 1" C Sd GLM). Tbg P = 1000 psi, 7" P = 920 psi. Increased Tbg P to 2000 psi, Tbg P fell to 1920 psi, 7" P rose to 950 psi in 25 minutes. Attempt to increase Tbg Pressure again, Test plug slipped and pressure bled off. No confirmation on integrity from test @ 6752' WLM. RDFN. PRESSURE TEST WITH TEST PLUG @ 6752' FAILED DUE TO POOR SET. CANNOT DETERMINE IF SBR HAS INTEGRITY FROM THIS TEST. NO INFORMATION. Set AVA "BIP" Blanking Sleeve/Isolation Plug. This tool is designed to isolate both the A and C Sands from injection. Tubing pickled with diesel, both 7" and tubing are diesel filled. Allow pressures and temperatures to stabilize. 7" annulus pressure, tubing pressure stabilized at 1000 psi. Pressure up on tubing to 2400 psi, hold for 12 hours. After 12 hours, Tubing pressure = 2400 psi, 7" annulus pressure -- 1000 psi. GOOD PRESSURE TEST INDICATES TUBING INTEGRITY (ie, NO LEAKS PRESENT AT GLM'S OR SBR). THIS TEST (IN COMBINATION WITH PREVIOUS TESTS) INDICATES NO TBG LEAK PRESENT, AND THAT LEAK IS MOST LIKELY A TOP PACKER LEAK ONLY OR A BEHIND PIPE CHANNEL AROUND PACKER CONNECTED TO A 7" CASING LEAK. Tbg pressure = 2400 psi, 7" ann pressure = 980 psi. Pump up on 7", increasing 7" pressure to 2500 psi. Tbg pressure increases to 2480 psi. After 6 hours, tubing pressure = 2400 psi, 7" annulus pressure = 1420 psi. ASSUME SMALL TBG PRESSURE INCREASE/DECREASE DUE TO "COMPRESSION EFFECT" CAUSED BY INCREASING 7" ANNULUS PRESSURE. DECLINE IN 7" PRESSURE INDICATES LACK OF INTEGRITY IN 7" ANNULUS ABOVE TOP PACKER (COULD BE 7" CSG LEAK OR TOP PACKER LEAK). NO INDICATIONS OF 7" TO TBG LEAK. Repeat 11/14/89 Test: Tbg pressure = 2450 psi, 7" ann pressure = 1000 psi. Pump up on 7", increasing 7" pressure to 2500 psi. After 12 hours , tubing pressure -- 2450 psi, 7" annulus pressure = 1000 psi. DECLINE IN 7" PRESSURE INDICATES LACK OF INTEGRITY IN 7" ANNULUS ABOVE TOP PACKER (COULD BE 7" CSG LEAK OR TOP PACKER LEAK). NO INDICATIONS OF 7" TO TBG LEAK. ONCE AGAIN, 7" DECREASES TO 1000 PSI, THEN STABILIZES. 1000 PSI ON 7" ANNULUS EVIDENTLY INDICATES "BALANCE POINT" WITH SOME OTHER PRESSURE AT LEAK LOCATION RECEIVED DEC [ Nasla 0il & Gas Cons, ctiorage 1 1/1 6/89 1 1/1 7/89 1 1/30/89 Tbg pressure = 2400 psi, 7" ann pressure = 1000 psi. Pump up on 7", increasing 7" pressure to 2500 psi. Monitor pressures for 3 hours to establish trend at which 7" annulus pressure is declining (Tbg pressure still constant at 2400 psi). Bleed tubing pressure to 1000 psi.. 7" annulus pressure continues to decline at the same rate, tubing pressure remains constant at 1000 psi. 7" annulus pressure eventually declines to 1000 psi, then stabilizes. DECLINE IN 7" PRESSURE INDICATES LACK OF INTEGRITY IN 7" ANNULUS ABOVE TOP PACKER (COULD BE 7" CSG LEAK OR TOP PACKER LEAK). LACK OF CHANGE IN 7" PRESSURE DECLINE RATE AFTER TUBING PRESSURE IS BLED OFF INDICATES NO 7" TO TBG LEAK. ONCE AGAIN, 7" DECREASES TO 1000 PSI, THEN STABILIZES. 1000 PSI ON 7" ANNULUS EVIDENTLY INDICATES "BALANCE POINT" WITH SOME OTHER PRESSURE AT LEAK LOCATION Tbg pressure = 1000 psi, 7" ann pressure - 1000 psi. Bleed Tbg pressure down to 150 psi. Monitor pressures for 24 hours. After 24 hours, 7" annulus pressure remains at 1000 psi, Tbg pressure remains at 150 psi. LACK OF CHANGE IN 7" PRESSURE AFTER TUBING PRESSURE IS BLED OFF INDICATES NO 7" TO TBG LEAK. ONCE AGAIN, 7" PRESSURE REMAINS STABILIZED AT 1000 PSI, EVIDENTLY INDICATING "BALANCE POINT" WITH "SOME OTHER PRESSURE" AT LEAK LOCATION Tbg pressure = 250 psi, 7" ann pressure = 960 psi. Bleed 7" pressure down to 750 psi. After 1 hour, 7" annulus pressure had increased back to 960 psi, Tbg pressure remains at 250 psi. INCREASE IN 7" PRESSURE AFTER BI~EED DOWN INDICATES THAT 7" LEAK COMMUNICATES IN BOTH DIRECTIONS. ALL NOVEMBER 1989 TESTS COMBINE TO PROVIDE THE FOLLOWING CONCLUSIONS: 1. UNDER STATIC CONDITIONS, NO "TUBING LEAK" (ie, GLM'S, SBR, C SD DV, C SD AVA PORTS, AND AVA BLANKING PLUG) EXISTS. 2. UNDER STATIC CONDITIONS, TESTS INDICATE EXISTENCE OF EITHER A TOP PACKER LEAK, OR A 7" CASING LEAK. 3. UNDER STATIC CONDITIONS, 7" ANNULUS PRESSURE WILL EVENTUALLY STABILIZE AT APPROXIMATELY 1000 PSI. THIS PRESSURE, IN COMBINATION WITH A DIESEL ANNULAR GRADIENT, WOULD INDICATE A 3100 PSI PRESSURE AT THE PACKER DEPTH OF 5900' TVD. 4. UNDER DYNAMIC INJECTION CONDITIONS, 7" ANNULUS PRESSURE WILL PRESSURE UP TO A PRESSURE GREATER THAN 1000 PSI, WHICH DIRECTLY CORRELATES TO INCREASES/DECREASES IN TUBING INJECTION PRESSURES. THIS INDICATES THAT THE 7" ANNULUS IS IN DIRECT COMMUNICATION WITH THE R EC IV DEC [ 11989 _Nas 0ii & Gas Cons ARCO Alaska, Inc. Post Office Bo~-'~rO0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 7, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are two Sundry Notices for well 3A-11. The first is a Report of Sundry Well Operations detailing diagnostic work completed Io determine the location of a tubing to casing communication. The second sundry is an Application for Sundry Approval to perform a Radioactive Tracer type alternative MIT. As usual the Report Sundry is attached in duplicate and the Application Sundry is attached in triplicate. If you have any questions, please call me at 265-6840. Sincerely, G. B. Sml~llwood Senior Operations Engineer CC: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 .KOE1.4-9 ,,,,,oE. E j V E D : DEC 1,1 Aias~ [1il & Gas .C00~.¢,~sI[0~ ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA AI_~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging __ Perforate Pull tubing __ Alter casing __ Repair well ~ Pull tubing Other X 2. Name of Operator ARCO Alaska. In6, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At effective depth 1196' FSL, 3629' FEL, Sec. 7, T12N, R9E, UM At total depth 1208 FSL, 3684' FEL, Sec. 7, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7350' feet 6398' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 72' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-11 9. Permit number 85-238 10. APl number $0-029-21458 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7 2 5 3' feet true vertical 631 8' feet Junk (measured) 13. Casing Length Size Cemented Measured depth True vertical depth Conductor 1 0 6' 1 6" 185 Sxs AS II Surface 3209' 9 5/8" 1050 Sxs AS II & 300 Sxs Class G 100 Sxs ASl Top Job Production 7342' 7" 500 Sxs Class G 175 Sxs AS l Perforation depth: measured true vertical 6830'-6886', 6972'-7010' 106' 106' 32O9' 3121' 7342' 6392' RECEIVEB 5975'-6004', 6089'-6120' Tubing (size, grade, and measured depth) 3 1/2", J-55, 9.3#, TT @ 6917' Packers and SSSV (type and measured depth) Otis RRH packer @ 6734' Otis WD packer~6889' Camco TRDP-1A-SSA SSSV~1807' Attachments Description summary of proposal X Detailed operation program _ DEC :[ 1_ 1-989 Al ,sl' 0il & Gas Cons. G m issl¢"- ctiora.ge BOP sketch 14. Estimated date for commencing operation December 15, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service WATER INJECTOR 17. I hereby certify that the f..oregoing is true and._.correct to tt',~ best of my knowledge. Signed ~ 4:~ ~~~ Title , OlConditi-ns of FOR COMUlSSlOCfUSE ONLY approval: Notify Commission so representative may witness Date Plug integrity_ Mechanical Integrity Test BOP Test Location clearance __ Subsequent form require lO-Z/~ IApproval No. I /¢-/~ ~'~-- Approved by the order of the Commission Ui:IIGINAL SIGNED ZY LONNIE C. SMITH Commissioner Date /.2 .- .,' ~--~? Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVAL ATTACHMENTS KUPARUK RIVER UNIT WELL 3A-11 An Application of Sundry Approval (#7-344) was filed with the State on May 22, 1987 for Kuparuk River Unit Well 3A-11. The application stated that tubing to annulus pressure communication was suspected and would be investigated, but was not yet a major problem as the well had successfully passed a pressure type MIT in January 1987. Well 3A-11, however, failed a State Witnessed Pressure Type MIT on August 30, 1989. Subsequent leak detection work identified the pressure communication point to be at the top packer in this selective single completion well. The results of this investigative work is detailed in the Report of Sundry filed December 6, 1989. The investigative work indicated that although the "leak" prevented the well from passing a Pressure Type MIT, it does not appear to be large enough to pass a significant volume of fluid. Due to the small size of the leak, it is felt that there is no significant amount of fluid movement present, and that no "out-of-zone" injection is taking place. To prove this, Arco Alaska, Inc. requests that well 3A-11 be allowed to return to combined zone A + C Sand water injection to allow the well to be stabilized prior to performing a Radioactive Tracer Type Alternative MIT (see attached outline of procedure). The proposed Radioactive Tracer Type Alternative MIT is designed to verify that all of the injected fluid is entering the approved Kuparuk interval (per amended Rule 6 of AOGCC Area Injection Order #2). If out-of-zone injection is detected-with this survey, the well will be shut-in, and appropriate remedial action will be taken.' If no out-of-zone injection is detected, Arco Alaska, Inc. requests that water injection be allowed to continue, under the condition that a radioactive tracer survey will be repeated every two years to confirm that injection is still being maintained within the Kuparuk interval. A similar type Application for Sundry Approval was granted for Kuparuk Well 3A-15 in 1988. RECEIVED Alaska 011 & Gas Cons. CommissloF Anchorage KUPARUK RIVER UNIT WELL 3A-11 RADIOACTIVE TRACER TYPE ALTERNATIVE MIT GENERAL PROCEDURE OUTUNE Revised 12/13/89 Pre-Job: Stabilize Well for 7-10 days at injection rate that the well is intended to be operated at in the future. Monitor injection rates and pressures continuously throughout the actual Radioactive Tracer Survey/Alternative MIT Test. Notify State at least 24 hours in advance of Survey to allow representative to witness, if desired. o , . . 5a. 5b. , . o Run baseline GR/CCL log from TD to surface. Eject RA tracer slug @ 200'. RIH to 2000' as quickly as possible, Monitor and record time when "hot" GR kick indicates passage of RA tracer material. Repeat these "timed-run" detector stops at 4500', 6500', 6725', and 6900'. If results from Step #2 Timed-run survey indicate fluid loss within the tubing, repeat step #2 for confirmation. Run secondary GR/CCL log from TD to surface to check for any "hot" spots from the baseline GR log that may indicate fluid loss from the tubing. RIH to 6700' (above SBR). Eject RA tracer slug. RIH to 6800' (below top packer, above AVA sleeve) and monitor for a secondary "hot" kick which would indicate fluid loss downward past the PBR/upper packer. RIH to 6720' (just above upper packer). Eject RA tracer slug. Stay at 6720' and monitor for a secondary "hot" kick which would indicate fluid movement from the C Sd area upward past the upper packer into the 7" annulus. RIH to 6800' '(below top packer, above AVA sleeve) and eject RA tracer slug. Stay at location and monitor for a secondary "hot" kick which would indicate fluid movement behind the tubing upward past the C Sand perfs toward the upper packer. If either Step #5 or Step #6 shows any Signs of fluid movement behind pipe, conduct additional tracer shots and log monitoring to determine :)otential leak location in 7" casing. POOH and RD EL unit. RECEIVED DEc 1 1989 Aiaska Oil & 6as Cons. Commlssio~;:~ Anchorage KUPARUK WELL 3A-11 APl #: SPUD DATE: ORIGINAL RKB: 500292145800 ADL LEASE: 25631 PERMIT #: 11/11/85 COMPLETION DATE: 01/10/86 WORKOVER DATE: SURFACE LOCATION: 768'FSL,813'FEL,SEC7,T12N,R9E TOP OF KUPARUK: 1160'FSL,3385'FEL, SEC7,T12N,R9E TD LOCATION: 1208'FSL,3684'FEL, SEC7,T12N, RgE All depths are MD-RKB to top of equipment unless olfmrwise noted 72 TUBING SPOOL: 24 PAD ELEVATION: WELLTYPE: WATER INJECTOR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5# H-40 106 9.625' 36# J-55 3209 7' 26# J-55 7342 3.5' 9.3# J-55 EUE 6917 ITEM LINER DETAILS SIZE WEIGHT GRADE TOP TUBING JEWELRY TYPE ID 2.25' SBR OTIS SBR PKR OTIS RRH AVA AVA 'BPL' NIPPLE PKR OTIS WD NOGO CAMCO 'D SHROUT CAMCO BTM DEPTH 6713 6737 6883 6889 6907 6916 41 GAS UFT and FLOW INFORMATION VALVE STN DEPTH MANDREL SIZE 1 2271 MERLA TMPD 1' 2 4189 MERLATMPD 1' 3 5565 MERLA TMPD 1" 4 6393 MERLA TMPD 1" 5 6670 MERLA TPDX 1.5" 6 6775 MERLA TM PD 1" PERFORATION DATA INTERVAL ZONE FT SPF PHASE 6830-6866 C3 36 12 120 6972-7010 A2 38 4 90 85-238 PORT SIZE .DV .DV .DV .DV .DY COMMENTS SOS 5' CSG GUN SOS 5" CSG GUN MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 39 HOLE ANGLE THRU KUP: 36 LAST TAG DATE: RATHOLE: FISH/OBSTRUCTION: PBTD: PBTDSS: deg deg DEPTH 2000 4600 7253 6246 REVISION DATE: 05/12/89 REASON: UPDATE ARCO Alaska, Inc~._,.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 12, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject' Kuparuk River Field Water Injection Surveys Reference is made to our correspondence on the above subject dated July 30 and specifically to Attachment 1, page 2. Attachment I referenced Well 3A-11 for which your office is missing the Sepia. We are forwarding this item to your office with this letter. Thank you for bringing this matter to our attention. Sincerely, 'B. B. Berg ~ Operati ons q~ngi neer BBB/SPT'pg'0102 Enclosure AAUG 1 laska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER INITIAL 50-029 INJECTION 2B-11 21089 11/19/85 2H-O1 20033 03/15/86 2H-04 20027 03/15/86 50-103 2T-04 20074 03/30/87 2T-09 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 50-029 3A-02 21431 01/21/87 3A-04 21433 01/21/87 3A-10 21457 01/21/87 ~458 01/21/87 04/1~/87 .,,/~'/ 3A- 14 21490 k DATE OF DATA TYPE REASON FOR WELL ZONES PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING SURVEY SURVEY SURVEY WATER INJECTION BWPD 06/16/87 SPINNER FOLLOWUP A&C S A&C 06/05/87 SPINNER FOLLOWUP A&C S A&C 06/07/87 SPINNER FOLLOWUP A&C S A&C 06/13/87 SPINNER INITIAL A&C SS A&C 06/16/87 SURVEY INITIAL A S A 06/21/87 SPINNER INITIAL A&C SS A&C 06/16/87 SURVEY INITIAL A&C SS A 06/16/87 SURVEY INITIAL A&C SS A 05/25/87 SPINNER INITIAL A&C SS A&C 05/87 SURVEY INITIAL A&C SS A 05/87 SURVEY INITIAL A S A 05/27/87 ~ INITIAL A&C SS A&C 05/87 SURVEY INITIAL A S A 3485 1833 590 2500 1200 1650 AUG Alaska Oil & Gas Cons. Commission Anchorage .RECEIVED AUG 1 Alaska Oil & Gas Cons. Commission Anchomg~ · , 1 STATE OF ALASKA ALAS-,,,,~ OIL AND GAS CONSERVATION COM~m'rSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 5. Datum elevation (DF or KB) 3. Address PO Box 100360, Anchoraqe, AK 4. Location of well at surface 99510 768' FSL, 813' FEL, Sec. 7, T12N, R9E, UM At top of productive intervar 1160' FSL, 3385' FEL, Sec. 7, T12N, R9E, UM At ¢~jfo~tive depth FSL, 3629' FEL, Sec. 7, T12N, R9E, UM At total depth 1208' FSL, 3684' FEL, Sec. 7, T12N, RgE, UM 11. Present well condition summary Total depth: RKB 72 measured 7350' MD true vertical 6398' MD feet feet 6. Unit or Property name Kuoaruk Riw. r Unit 7. Well number 3A-11 8. Permit number Permit #85-238 9. APl number 5O-- 029-21458 10. Pool KiJnarEJk River (lil Pnnl , Plugs (measured) None Effective depth: Casing Structural Conductor Surface X X Xl~l~'~texl~e Production measured 7253' HD feet Junk (measured) None true vertical 6318' FiD feet Length Cemented 106' 185 SX ASII 3209' 1050 SX ASII 7342' Size Measured depth 16" 106' MD 106' 9-5/8" 3209' MD 3121' & 300 SX Class G, Top Job w/lO0 SX AS1 7" 500 SX Class G 7342' MD 6392' & 125 SX PFC 6830'-6866' MD, 6972'-7010' MD XXXL~,~rx XXXX Perforation depth: measured true vertical 5975'-6004' TVD, 6089'-6120' TVD ~bing (size, grade and measured depth) 3½" J-55 9 2 lb/ft Tail @ 6917' MD Packers and SSSV(type and measured depth) Otis RRH @ 6734'; Otis wB 0 ~RR9'; camco TRDP-!A-SSA @ !807' 12.Attachments Description summary of proposal ~ Locate tubin§ to casinq communication True Vertical depth TVD TVD TVD Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May 17, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certif_y that the foregoing is true and correct to the best of my knowledge Signed ¢~¢¢f~ ¢~_ . ¢"'~~ Title Operations Engirleer Commission Use Only Dat&/14/87 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by ~' Form 10-403 Rev 12-1-85 by order of the commiss~ate ,~~:~-~)~ ..Submit in triplicate ' ~r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM._.SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other I~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage~ AK 99510 4. Location of well at surface 768' FSL, 813' FEL, Sec. 7, T12N, RgE, UM 5. Datum elevation (DF or KB) RKB 72' Feet¢ At top of productive interval 1160' FSL, 3385' FEL, Sec. 7 At effective depth 1196' FSL, 3629' FEL, Sec. 7 At total depth 1208' FSL, 3684' FEL, Sec. 7 , T12N, R9E, UM , T12N, R9E, UM , T12N, R9E, UM 6. Unit or Property name Kunarljk RivPr lln-it 7. Well number 3A-11 8. Approval number #85-238 9. APl number 50-- 029-21458 11. Present well condition summarYTqc;R Total depth: measured .... ' MD true vertical 6398' TVD feet feet 10. Pool Kuparuk River Oil Pool Effective depth: measured 7253' MD true vertical 6318' TVD feet feet Plugs (measured)NOne Casing Structural Conductor Surface X X x;kr~R~r~te Production xxx ,xxxx Perforation depth: Length Size 106' 16" 3209' 9-5/8" 7342' 7" measured Junk (measured) None Cemented Measured depth True Vertical depth 185 SX ASII 106' MD 106' TVD 1050SX ASII 3209' MD 3121' TVD & 300 SX Class G, Top Job w/lO0 SX AS1 500SX Class G 7342' MD 6392' TVD & 125 SX PFC 6830'-6866' MD, 6972'-7010' MD true vertical 5975'-6004' TVD, 6089'-6120' TVD ~bing(size, grade and measured depth) 3½" J-55 9 2 lb/ft Tail @ 6917' MD , , · , _Packers and SSSV (type and measured depth) I I Otis RRH @ 6734 ; Otis WD @ 6889 ; Camco TRDP-1A-SSA @ 1807 12. Stimulation or cement squeeze summary Intervals treated (measured) 13. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Tubing Pressure OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 370 0 910 200 Rates shown are 1/31/87) 833 1125 1140 Prior to well operation 367 (In3ection started on 1/21/87. Subsequent to operation Copies of Logs and Surveys Run [] 14. Attachments Daily Report of Well Operations [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev.-l-85. Title Sr. Operations Engineer Submit in Duplicate ARCO Alaska. Inc. DRILLSITE STATUS REPORT DATE: .. WELL T ~ PRODUCTION WELL STATUS GAS LIFT STATUS NO. A T N - U E FTP TEMP CHOKE 7" CSG 10" CSG GAS INJ METER WELL S P,SI F BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARK ~ ~ ~ q~ I~oo 600 /b~ ~ ~ ~l 330 TOTAL MAXIMUM WELL I Z ALLOWABLE INdEGTION WELLSTATUS NO. N O J N ~ CHART TOTAL TOTAL E TEMP CHOKE 7"CSG 10"CSG METER CALC INJ INJ WELL F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR ~ . GASCORR FACTOR = HEADER PRESS = TOTAL FORD.S. DRILL SITE PROD TEST PROD TEST 'BAT:H BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI ,,, OUT /~0 .... ~ ~ CHEMICALS TYPE GAL/DAY COMMENTS: ARCO Alaska, Inc. II ,,.o,-r S WELL T Z_ PRODUCTION WELL STATUS GAS LIFT STATUS NO. A O T N U E FTP TEMP CHOKE 7" CSG 10" CSG GAS INJ METER WELL S PSI F BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARK ~ ( ~ 115 3V ( I~ ~75 ,,. TOTAL j~ ~ MAXIMUM WELL I Z ALLOWABLE INJECTION WELL STATUS NO. N O J N ~ CHART TOTAL TOTAL E TEMP CHOKE 7"CSG 10"CsG METER CALC INJ INJ WELL F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR ~o~ ,~~~' - 6,s co.. ~,c~o. = ¢ ~ HEADER PRESS = TOTAL FOR D.S. DRILL SITE PROD TEST PROD TEST BATH BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI OUT / COMMENTS: CHEMICALS TYPE GAL/DAY ~ 02-01-87~ 15 T-6597737 NSK ARCO AlaS ka, Inc. ORILLSlTE STATUS REPORT DATE: !- ~ I - ~'"/ TIME: ~.~ DRiLL.~IT; ~ ~ _ ~/(~LL ST ~ PRODUCTION WELL STATUS GAS LIFT STATUS T N ~ E FTP TEMP CHOKE 7"CSG '10"CSG (3AS 1NJ METER PSI F BEAN PSI psi TEMP HCF TOT. A..L ~1/EHL~j REMARK 3 p ~ ~ sz / ~ ~_~ / / I ~ ~ ' ., ...... ~,, _ ......... ~ ~, . ............. ,, _ _ ........... .. , ........... TOT, L ~ .,, MAXIMJJM INJECTION WELL STATUS WELL I Z ALLOWABLE ,, NO. ~ O LN~ ~ .... CHART TOTAL TOTAL ~ TEMP CHOKE 7" CSG 10"CSG METER CALC INJ INJ WELL F. . BEAN PSI ..P. SI TOTAL MMSCF ,.. .BBL~S MMSCF SI/HR _ ,, , ,., . . HEAD, ER PRESS =, ...... ~ ~T~ TOTAL FOR D.S. DRILm'SI:rE " PROD TEST PROD TEST ' BATH BL/~'N'J~ET RLJN TIME H EATER TEMP TEMP PSI PSI TEMP GAS PSi , ,, ,, .-. CHEMICALS TYPE GAL/DAY -_ COMMENTS: OPERATORS SIGNATURE: ~"~. '~_O STATE OF ALASKA ALASt~,-r OIL AND GAS CONSERVATION COMI~_~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO A1 aska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 768' FSL, 81_3' FEL, Sec. 7 T12N RgE UM At top of productive interval ' ' ~ 1160' FSL, 3385' FEL, Sec. 7, T12N, RgE, UN /~:.e~f~e, ct i~'~, d e pt..h~ A A l~b rbL, JbZg' FEL, Sec. 7, T12N, RgE, UN At total depth 1208' FSL, 3684' FEL, Sec, 7, T12N, RgE: UN 11. Present well condition summary Total depth: measured 7350' MD feet true vertical 6398' MD feet 5. Datum elevation (DF or KB) RKB 72 6. Unit or Property name KuparmJ~ Pivor Ilnit 7. Well number 3A-11 8. Permit number Permit #85-238 9, APl number 50-- 029-21458 10. Pool I~,Jp~r:!k i~iver Oi! Poo! Plugs (measured)None feet Effective depth: measured 7253' MD feet true vertical 6318' MD feet Casing Length Size Structural 106' 16" Conductor Surface 3209' 9-5/8" X X X ~r~ Nl~(r, d4 ate Production xxx~-JSCXxxxx Perforation depth: 7342' 7" Junk (measured) None Cemented Measured depth 185 SX ASII 106' MD 106' 1050 SX ASII 3209' MD 3121' & 300 SX Class G, Top Job w/lO0 SX AS1 500 SX Class G 7342' MD 6392' & 125 SX PFC measured 6830'-6866' MD, 6972'-7010' MD True Vertical depth TVD TVD TVD true vertical5975'-6004' TVD, 6089'-6120' TVD Tubing (size, grade and measured depth) 3½",J-55, 9.2 lb/ft, Tail @ 6917' MD Packers and SSSV (type and measured depth) Otis RRH ¢ 6734'; Oti~ wn @ 6889" Camco TP. DP-!A-SSA @ 1807' 12.Attachments Description summary of proposal [] Detailed operations program [] Convert well from oil producer to wat~_r ~njentnr 13. Estimated date for commencing operation January 10, 1987 BOP sketch:[] 14. If proposal was verbally approved Name of approver /~ n. Z/, --~'m / ://~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~,~.--'z.'/ ~ Sr. Operations Engineer Conditions of approval Title Dat~/23/86 Commission Use Only Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI No. "~ '" O'~ Subsequent Work Ret2orted Approved by fl LI ~ 'i" il Form 10-403 Rev ~¥4J~~iiE g' "="" Commissioner on Form No./~- '~Ld_~tecl _'~/.~ by order of the commission Date Submit in triplicate ARCO Alaska. In~_.-, Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907' 276 1215 DATE 09-15-86 TRANSMITTAL # 5761 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run #3 7585-8532 lA-14 .12-05-G5 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 ' 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85- Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt Acknowledged: Vault*films F N 198-6 Alask~ Oil & Gas CODS. GommjSSjOD Date Anchorage NSK Files*bl ARCO Alllkl. Inc. ,s · Subsidiary of AllafllicRichfieldComplny , STATE OF ALASKA ~ ALASKA"T3'~L AND GAS CONSERVATION Ci:::TF~M ISSION ~:-~, WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL E]XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-238 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21458 4. Location of well at surface 9. Unit or Lease Name 768' FSL, 813' FEL, Sec.7~ T12N, RgE, UN Kuparuk River Uni'c At Top Producing Interval 10. Well Number 1160' FSL, :3385' FEL, Sec.7, T12N, R9E, UM :3A-11 At Total Depth 11. Field and Pool 1208' FSL, :3684' FEL, Sec.7, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 72' RKB ADL 25631 ALK 2564 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore I16. No. of Completions 11/11/85 1 1/15/85 11/17/85*I N/A feet MS LI 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 7350 'MD ,6398 'TVD 7253 'MD ,6318 'TVD YES~ NO[]I 1815 feetMD 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" 62.5# H-bO Surf 106' 24" 185 sx A5 II ,, 9-5/8" :36.0# J-55 Surf :3209' 12-1/4" 1050 sx AS Ill & :300 sx Class G Performed top job w/100 sx AS I 7" 26.0# J-55 Surf 7:342' 8-1/2" 500 sx Class G & 175 sx AS I 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) 6972' - 7010' w/4 spf, 90° phasing 3-1/2" 6917' 6742' & 6889' 6830' - 6866' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATEDib~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO 191 Alaska 0il & Gas Co.s. ~0mmi~si0n Form 10-407 * NOTE: Tubing was run & well perforated 1/10/86. GRU1/WC09 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · Top Kuparuk C 6827' 5972' N/A Base Kuparuk C 6866' 6003' Top Kuparuk A 6940' 6063' . Base Kuparuk A 7077' 6174' . ~ · 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed ~~ LklJI._/ Title Date ~'~'~t/-~3 ~ // INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the Ioc~i6h'"',o.'f ~tl~l~ d.er~e~ting tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njectibn, Shut:in, Other-explain. Item 28:' if o cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/26/86 12/16/85 2/01/86 3A-11 Arctic Pak well w/175 sx AS I. Rn CET log f/7212'-5796'. Begin frac @ 1630 hrs, 2/1/86. AFE: AK0332 Frac'd Kuparuk "A" Sand perfs 6972'-7010' in 7 stages per 1/30/86 procedure using gelled diesel, 5% Musol, 100 mesh & 20/40 mesh. Press'd ann to 2500 psi w/diesel. Tst ins to 7400 psi; OK. Stage 1: Pmp'd 45 bbls 5% Musol/diesel spear @ 4.6 BPM w/final pressure of 2810 psi. Stage 2: 20 bbls gelled diesel pre-pad @ 20 BPM w/final pressure of 5670 psi. Stage 3: 17 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM w/final pressure of 5560 psi. Stage 4: 12 bbls gelled diesel pad @ 20 BPM w/final pressure of 5170 psi. Stage 5: 6 bbls gelled diesel w/3 ppg 20/40 mesh @ 20 BPM w/final pressure of 4740 psi. Stage 6: 17 bbls gelled diesel w/8 ppg 20/40 mesh @ 20 BPM w/final pressure of 4070 psi. Stage 7: 60 bbls gelled diesel flush @ 20 BPM w/final pressure of 3950 psi. Job underflushed by 2 bbls. Pmp'd 672# 100 mesh & 5905# 20/40 mesh in formation leaving ±490# 20/40 mesh prop below tbg tail in 7" csg. Load to recover 188 bbls of diesel. Job complete @ 1830 hrs, 2/1/86. RI C IVED APR0 1986 AlasJm Oil & Gas ~ns. gOlij~JSSJOll Anchorage Drilling ~uperintendent / Elate ARCO Alaska, Inc. Post Office Box~.,,...J360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 6, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are -intent Kuparuk River Field' Well Action notices on the following Anticipated Start Date 3A-10 Perforate 3A-11 Perforate 3A-12 Perforate March 15, 1986 March 16, 1986 March 17, 1986 If you have any questions, please call me at 265-6840. Sincerely, wells G. B.VSmallwood Senior Operations Engineer GBS:pg'O014 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRichfleldCompany ~.~_~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COi~[MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100360, gnchorage, Alaska 99510 4. Location of Well SURFACE LOCATION' 768' FSL, 813' FEL, SEC. 7, T12N, R9E, LN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' (RKB) 12. 7. Permit No. 85-238 8. APl Number 50- 029-21458 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 3A-11 11, Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL ADL 25631, ALK 2564 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" Sand be perforated for production. Procedures call for the well to be perforatec through tubing with 4 SPF. Proposed Interval (~)' 6954 - 6972 ANTICIPATED START DATE' March 16, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..,~Z~ ~ -&$' ,~ //~ ,~/~ ~'~ Title.Kuparuk Sr. Operations Engr. The space below ,~r Commission use V Conditions of Approval, if any: Approved Copy '~eturnec] ..~ / BV Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. . Post Office B( '.)0360 Anchorage, Alaska'99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports and gyroscopic surveys for the following wel 1 s' 3A-10 3A-11 3C-14 3C-15 3C-16 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L150 Enclosures ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASKA"orr_ AND GAS CONSERVATION C~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification o{ Service Well OIL E~xX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-2~8 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21458 '4. Location of well at surface 9. Unit or Lease Name 768' F5L, 813' FEL, Sec.7, T12N, R9E, UM~~1 LOCATIONS Kuparuk River Uni'c At Top Producing Interval 1 VERIi:J~D 1 10. Well Number 1160' FSL, 3385' FEL, Sec.7, T12N, RgE, UM~Surf.~i¥2 3A-11 i~ I At Total Depth iD. H.~ 11. Field and Pool 1208' FSL, 3684' FEL, Sec.7, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 72' RKBI ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/11/85 11/15/85 11/17/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7350'MD,6~98'TVD 7253'MD,6318'TVD YES ~ NO [] 1815 feetMDI 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 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 106' 24" 185 sx AS II 9-5/8" 36.0# J-55 Surf 3209' 12-1/4" 1050 sx AS Ill & 300 sx Class G Performed top job w/100 sx AS I 7" 26.0# J-55 Surf 7342' 8-1/2" 500 sx Class G & 175 sx AS I 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) 6972' - 7010' W/4 spf, 90° phasing ;~-1/2" 6917' 6742' & 6889' 6830' - 6866' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GASoMCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · , Form 10-407 * NOTE: Tubing was run & well perforated 1/10/86. DAM/WC~8 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk ¢ Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 6827' 6866' 6940' 7077' 5972' 6003' 6063' 6174' 30. FORMATION TESTS Include interval Tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well History (completion details), Gyroscopic Surv, ey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and og on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump~ Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form ~0-407 ARCO Oil and Gas ComP'~ny Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel3ort" should be submitled 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 dat& in blocks provided. The "F|nal Report" form may be used for reporting the entire operation if space is available. District t Alaska Field Lease or Unit Kuparuk River Auth. or W.O, no. ~Title AFE AK0332 County or Parish North Slope Borough ADL 25631 Completion JAccounting cost center code State Alaska IWell no. 3A-11 Nordic 1 AP1 50-029-21458 Operator IA.R.Co. W.i. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun I Date Complete I 1/8/86 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our ~ Prior status if a W.O, 2130 hrs. Date and depth as of 8:00 a.m. Old TO Released rig 1/09/86 1/10/86 0245 hrs. Classifications (oil, gas, etc.) Oil Flowing Producing method Complete record for each day reported 7" @ 7342' 7212' PBTD, Rn GR/JB 10.0 ppg NaCl/NaBr Accept rig @ 2130 hrs, 1/8/86. RU Schl. Perf w/4" csg gun, 4 SPF, 90° phasing f/6972'-7010' & w/5" gun, 12 SPF, 120° phasing f/6830'-6866'. RIH w/GR/JB. 7" @ 7342' 7212' PBTD, RR / Diesel in ann & tbS,'~88q - Set WD pkr @ 6889' ~WL~ RD Schl. RU & rn 220 jts, 3½,,, 9.3#, J-55 EUE 8RD IPC tb~w/SSSV @ 1815', SBR @ 6718', RRH pkr @ 6742', WD pkr @ ¢~4L~', TT @ 6917'. Set pkr & tst. Tst SSSV. SBR sheared. NU & tst tree. Displ well to diesel. Set BPV. RR @ 0245 hfs, 1/10/86. INew TD IPB Depth 7212' PBTD Date Kind of rig 1 / 10/86 Rotary IType completion (single, dual, etc.) r Single Of,icial reservoir name(s) Kuparuk Sands Potential test data 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. Waler % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation an(~ldistribution, see Procedures Manual, Section 10, Drittin~, Pages 86 and 87. Date I Title Drilling Superintendent ~ r $UB.~URFACE DIRECTIONAL ~URVEY [-~UIDANCE [~ONTINUOUS ['~OOL Company Well Name Field/Location __ ARCO ALASKA INCORPORATED 3A-11 (768' FSL, 813' FEL, S7, T12N, R9E) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71179 Logaed BY;. WEST O__at.~e 26-JAN-1986 Computed HALSTEAD GCT DZ~ECTI]NDL SU~E¥ 'USTOMER LISTINS FOR aRC] KUP&RJ'K Ng~f~ SLOPS,,~L~SK& SURCEY DATE: 12-15-25 EN$I.NEER: W:ST METHODS OF CD~PUT&TIDt T33L LDC&TION: T4N~ENTIaL- ~VE~SE3 OE¢IATION ~ND ~ZZ~J'TH INTERPgL~TZ]N: LZN~R VERTICAL S~CTI]N: tORIZ. DIST. PRDJECT~O 3~TO &' T~G"'T ~LZMUTH 11 3~-11 KJPARJK NSRTH SLDPE,AL~SK~ COMPUTaTION DATE: 26-J~N-85 [NTE~OLAT=D VALJES FSR :VEN 100 mES? O: TRUE SJB-SEA 4EASURED VERTI"AL V:RTI"AL 3EPTH DEPTq DEPTH O.OO 0.00 -?Z.O0 100.02 99.99 27.99 200.00 199.99 127.99 300,00 299.99 227.99 400,00 399.99 327,99 500,00 499.99 427,99 600,00 599,99 527.99 700,00 599.99 52?,99 BOO.OD 799.99 727.99 900,00 ~99,99 ~27.99 lOO0.DO 999,99 927,99 1100,00 1099,99 1027,99 1200,00 1199,98 1127,93 1300,00 1299,98 1227,98 1400.00 1399,98 1327.98 1500,00 1699,98 1427,98 1500,00 1599.98 1527.98 1700.00 1699,98 1527,98 18DO,OD 1799,97 1727.97 1900,00 1899.94 1827.94 1999.90 2099,87 2199,55 2298,58 2397,00 Z~,.93.9? 2589~6. 3,1 33t+6.48 3423 · 76 3501.00 3578.32 35 55.75 2000,00 2100,00 2200,00 2300,00 2~DO,DD' 2500,03 2500,00 2700.00 2BO0,OD 2900,00 3000.00 310'0.00 3300.00 3~00.00 3500.00 3500.0~ 3700,00 38-00.00 3gO0.O0 CSURSE V:RTI'AL DOSLE<S ~EVIqTISN AZIMUTq SECTION SEVERITY ]EG ~IN DES MI~ FE~T 3:3/103 0 0 N 0 0 E 0.00 0.03 0 8 N 45 5~ ~ 0.48 0.2a 0 7 S 8 69 : 0.61 0.22 0 8 N 75 25 ~ 0.44 0.29 0 3 S 42 57 E 0.30 0.35 0 14 S 28 5 E 0.14 0.13 0 17 S 45 40 E -0.20 3.1~ 0 15 S 72 28 E -0.64 3.0~ 0 13 S 73 25 E -1.05 0.11 0 10 S 30 55 5 -1.37 0.25 0 19 S 4 45 E -1.51 3.22 0 Z7 S 12 43 'E -1.69 0.15 0 19 S 23 ~ : -2.03 0.15 0 13 S 12 ~1 ~ -2,28 2.20 0 18 S 4 5D E -2.3q i).17 0 19 S 28 ~ E -2.60 0.17 0 10 S 58 ZD E -2.99 9.35 0 9 N 32 29 ~ -3.19 3.53 1 20 N 13 4~ ~ -3.29 0.75 1 26 N 31 22 E -3.82 0.59 1927.90 2027.37 2127.55 2225.68 2325.00 Z~21.97 2517.25 2610.85 1702.81 2792,26 1 2 5 .8 12 15 19 Z1 2~ 28 Z2 N 53 33 E -5.38 1.53 33 N ~3 Z W -4.68 59 N 59 25 N Z.11 3.10 56 N 7~ 31 'd 1~.80 3.5~ 15 N 78 ~ W 32.94 3.69 ~7 N 7~ ~7 W 57.18 ~4 N 7~ 59 W 37.23 3.12 39 N 79 37 W 122.34 3.02 $1 N 82 2~ W 151.57 3.52 19 N 81 17 W 206.21 3.7~ 28'78,79 2961,77 3041,52 3119,43 3197,07 3274,48 3351.76 3~29.00 3505.32 3583.75 31 35 38 38 39 39 39 39 39 39 59 N 79 49 W 255.30 3.81 34 N 78 8 W 312,02 3.53 18 N 78 15 W 372,21 Z.15 59 N 79 21 W ~3~.86 0.37 11 N 80 1 W 497.86 3.39 19 N 80 17 W 561.16 0.1~ 26 N 80 7 ~ 62~.61 0,15 !3 N 80 12 W 688.12 0.17 18 q 80 11 W 751.53 0.23 9 N 80 7 W ~1~.79 0.25 R ~-TA',,I 3UL~R .~3qTH/SDJT-~ E2ST/WEST 3.30 N O.OO 0.19 $ 0.52 3.7_7 3 0.55 0.35 S 0.55 O..Z':~ S :3.35 0.56 '5 3. Z 3 0.9~ S 1.19 ':3 0.47 1.$~ S 1.!5 1 gg S 1 Z~ c.58 S 1.31 3.23 S 1.55 3.56 S 1.74 4.11 S 1.77 4.56 S 1.91 5.~5~ S _~.~ 5.31 S 2.45 3.52 .3 2.7~ 1.~9 S 3.53 0.33 W 5.~9 2.34 N 5.10 6.~6 ~ 1.05 12.03 N 13.10 15.7,5 q 30.89 21.~6 ;'~1 54 . 3 -"+ 29.55 .q 83.58 37.62 N 117.97 43,~0 ~ 15~,77 49.~3 N 201,01 57.59 ~ 250'41 W 68.24 '~ 305-17 W 31.12 N 36~.08 W 9~.0:~ N a25,62 W 104.35 '~ ~87.62 W 115.11 N 550,02 W 125.38 N 612.55 W 1.36.75 ~ 575.13 W 147.53 i 7~7.~3 W 15:3.39 q 7'39.97 W ~]RZZ. DIST. 3.30 0.55 0.71 0.61 3.45 0.~0 1.27 1.56 1.33 2.75 2.39 3.59 4.05 5.52 5..57 3.92 5.50 5,51 '17. !2 34.5? '¢. 51 3 · ~ 2 162.66 207.30 256.97 312.70 37'3.01 t+35.6~ 49~. 5,5 551 · 93 525.35 5313. :35 752.2~ 315.50 7.,2.0,3 FT aZIqdT~ ]:S ulq S 33 la '~ 3 Z5 37 : s 2s 21 ~ $ Z2 17 ~ ~ 23 57 ~ S 35 ~0 i 5 67 39 ~ S 73 51 ,4 S 57 5,~ ~ S 53 35( S Z~ 9 .. S 3 23 S 21 27 ~ S 33 39 S 36 5 E ARCO ~LASKA, I~C. 3~.-11 K:JPARLJK N3RTH SLDPE,~L~SKA COqPUTATI34 40 41 42 44 45 47 4~ 50 51 52 53 5~ 55 55 57 58 5 ~ 60 61 6Z 63 64 65 65 67 6~ 69 70 7Z 73 T3 DATE: 26-J~N-35 INT:RPDL~TEO VALUES FOR EVEN 100 PEET COgRSE VERTICAL DOGLEG 2:VI~TION AZIMJTH SECTION SEVERITY ~G ~IN DEG 4I~ FEET DE$/10D TRUE SJB-S:A SURED VERTICAL VERTI'AL EPTH DEPTfl DEPTH 39 2 N 80 3 W $77.32 0.13 38 59 N 79 5% 4 940.91 9.50 39 12 N 79 3% W 1093.78 9.22 39 18 N 79 33 W 1067.06 0.09 39 19 N 79 3] 'W 1130.36 39 12 N 79 45 ~ 1193.72 D.39 38 53 N 79 43 W 1255.71 0.43 38 27 N 80 5 ~ 1319.17 0.50 38 10 N 2~ 3& W 1381.19 0.55 37 33 N 80 55 W 1442.58 0.39 00.00 3733.38 3561.38 O0.OD 3811.03 3739.03 00.00 3898.70 3~16.70 00.00 3966.10 389~.10 00.30 4043.51 3971.51 00.00 ~120.~5 %048.86 O0.09 %198.51 %125.51 00.00 %276.59 %20%.59 DO.D0 4355.33 %283.03 00.00 %433.96 %361.95 37 30 N 80 ~7 W 1503.53 9.50 36 $B N 31 10 W 1553.9~ ~.79 36 ~.B N ~1 55. W' 1523.67 D.57 37 0 N 82 1~ W 1533.92 2.73 36 22 N 32 49 W 1743.59 2.55 36 19 N 83 31 W 1~02.84 3.5~ 36 17 ~ 8~ 3 W la52.0~ 0.45 36 33 N.84 3D W 1921.48 0.30 37 17 N 84 22 W 1981.31 1.43 37 ~3 N 83 48 W 2042.27 0.19 O0.DD 4513.Z5 4441.25 O0.OD 4592.94 %520.94 DO.OD %673.13 %501.13 O0.O0 %752.~4 %680.'94 DO.OD $833.17 $751.17 DO.OD 4913.70 ¢841.70 DO.DO $994.22 ~922.22 00,00 5074.59 5002.59 30.00 515~.55 5082.65 00.00 5233.~6 5151.85 ~0.00 O0.OO 00.00 00.00 00.00 O0.O0 00.00 O0.OD 00,00 00.00 531Z.90 5391.95 5~70.36 5550-00 5:{ i, 18 5243.90 5319.95 5398.86 '5478.00 5557.18 5635.57 5715.86 5797.40 5377.85 5958.38 6039.15 5120.39 5202.71 6285.04 5326.20 37 ~7 N 84 7 W 2103,45 0.35 37 ~9 N 84 15 W Z164.63 0.09 37 $7 N 8% 31 W 2225.95 0.70 37 %1 N 84 51 W Z2~5.95 0.41 37 36 N 85 1) W 2347.90 0.39 36 59 N 85 5~ W Z408.51 1.33 36 Z4 N 86 1 W ~467.91 36 Z4 N 85'47 W Z525.98 0.22 36 18 N 84 30 W 2586.22 1.41 36 19 N 83 4Z W Z645.44 0.87 36 0 N 83 15 W 2704.35 3.55 35 3 N 81 57, W Z762.63 2.62 34 34 N 77 14 W 2819.36 0.00 34 34 N 77 1~ W 2875.99 0.00 34 34 N 77 15 W 2904.30 Q.O0 0'00 0.00 0.00 0.00 O.OO M: ~ S U R" N3RTH/ 159 · l~O. 191. 202 · 214. 225 · 235. 247. 258. 277. 287. Z 95. 304. 312. 319. 325. 331. 337. 343, ] 3~TH 3UL2R C33RDI'~&TES SOUTH E~ST/W:ST Y FeET 22 N 852.07 W 14 'q 92~,.12 W '41 q 985.0'9 90 q 1043.35 35 N IlI$,63 W 55 N 1173.00 w 35 q 1235.00 B'~c N 1295.51 20 q 1357.56 33 '~-,J 141~.25- W H3RIZ. DIST. 5'9 iQ 1473.43 :)~ q 1597.1.H 30 '4 1656.36 11 q i716.03 13 'Q 177~.93 53 ~ 1533.~5 ~2 ',l 1893.05 35 q 1952.72 55 N Z013.40 37~.52 941.51 11257.31 1131.13 11)4.53 1257.'50 131 9. )$ 13',~l. ~9 1~4].35 1504.29 155%.$7 1524.37 I $ ~,~. 57 17~4.1~{ 1'~03.35 1~52,52 1 ~21. 85 1~,~1.59 2042.50 2103.54 2154.77 2225.05 2287.03 2347.~4 2~05.53 255T,91 2525.9~ 2585.23 2545.$5 2704.37 2762.66 2819.38 237.5. O0 29,34.31 3E~RTJRE ~ZIMUTH 3:3 N 89 31 ~ q ,3 i 6 W ~ 81 24 W q 8i 26 W ~ 91 24 W q 81 19 N q ~1 17 4 :CgMPUT~TI]N D~T~: 25-J~N-35 ~aS.E 5 ARCD ~L~SK&, INC. 3&-ll KUP~R~K N3RTH SLS~E,AL&SK& INT':~OL~TED V~LJES FOR TRUE MEASURED V=RTI'~L. . DEPTH DEPTfl SJ~-SE.& CDJRSE VXRTIS&L V2RTI-&L ]EVI&TIOq ~ZIMdTH SECTIgN S~VE~ITY DEPTH ]:G ~IN 2:~ MI~ FEET 0.93 O.DO 1330.00 999.99 2000.00 1999.90 3000.0~ 2950.79 4OO0.DO 3733.38 5000.00 4513.25 6000.00 5312.~0 70DO.OD 5111.15 7350.00 5398.20 -7Z.O0 927.99 1927.90 2878.79 3561.38 ~441.25 5240.90 $03~.15 532~.20 0 0 N O ~ ~ 0.00 0 19 S ~ ~5 5 -1.51 0.22 1 Z2 N 53 .33 5 -5.38 1.53 31 59 N 7~ 49 W 255.30 3.~1 39 2 N ~0 3 W ~77.82 9.13 37 30 N 80 ~7 ~ 1503.53 3.50 37 ~7 ~ 8~ 7 W ~103.45 0.35 35 0 N 83 1~ W 2704.35 0.55 34 34 N 77 1~ W 2904.30 9.00 3~T- 3: SJq'¢~Y: <.:LL'Y 5USNZ'~S 1. O. 57. 159 · 277. 350 · ~+93. 939 · :D 3ULAR C]SqDI~T~S SOUTM cAST/4:ST 5~ S 1.g4 5~ '~ 250.41 22 N 55Z.,07 5~ :~ 1473.~3 ~0 N 2074.52 54 q 2574.05 59 'q 2370.~0 ~I~T. O.OO 2.25 3.50 255.~7 57{.5Z 2133.64 2704.J7 Z~04.31 3:P~RTUR: 2Z"aUTq ~50 ~L~SK/~, IqC. KJ,~4RJK N3RTH SL'3PE, AL~,S~ ~, COXPUT~TIDX D~TE: Z6-J~N-85 347- 3= SJRV-Y: 12--!D-3D 72.,.,"'D --T INTERPOLATED V~LJES :OR :VEN 100 r-::T O: TRdE SJB-S~A ME~SURmD VERTIC6L VERT'-~L DEPTH DmPT~ DEDTH 0,00 0,00 -72,00 72,01 72,00 0,00 172,01 172,00 100,00 272,01 272,00 200.00 372,01 372.00 30D.O0 ~72,01 472,00 400,00 572.01 572.00 500.00 572,01 672.00 500,00 ?72,01 772,00 700,00 872.01 B72,00 800.00 ~72,01 972,00 903,00 1072,01 1072,20 1000.00 1172,02 1172,00 1100,00 1272,02 1272,00 1200,00 1372.02 1372.00 1300.00 ~72,02 1472,00 1400.00 1572,02 1572,00 1500,00 1572,02 1672,00 1600,00 1772,02 1772,00 1700,00 1~72,05 1872,00 1800.00 1972.09 1972.00 1900.00 2072.12 2072.00 2000.00 2172.32 2172.00 2100.00 2273.02 2272.00 2200.00 2374,~? 23?2°00 230~,00 2~77,21 2~72,00 2400,00 2581,73 257~,00 2500.00 2558.3'5 ~2.00 2500.00 2?96.89 ~.00 2703.00 2908.78 .~00" 2800.00 3025.22 Z)O0.O0 31~7.~7 3000,00 3275~00 :'i00 3100.00 3403.?8 32'12,00 3200,00 3.532,9~ 3372,00 3300.00 35~.~7 3~72.00 3400.00 3791.8~ 3572.00 3500.00 3~20.9¢ 3672.00 3600.00 ~0~9.73 3772.00 3700.00 ¢118.~g 3~72.00 3800.00 CDJRSE VERTiSAL DDS_EG DEVI~TIDN &ZIMUTH SSCTION SEVERITY ];G ~IN DEG MIq ~EET O~S/lOD 0 0 N 0 9 E 0,00 O.OD 0 8 N 46 45 W 0.43 0.31 0 7 S 15 3~ W 0.62 0.25 0 7 S 83 12 = 0 51 0 20 0 4 q ?T lB ~ 0.33 O.Z~ 0 13 S 25 15 =_ 0.20 0.1~ 0 17 S 39 40 : -0.09 3.11 0 16 S 65 15 = -0.52 D.Z3 0 .13 S 74 32 ~ -0,95 0,07 0 11 S ~7 20 E -1.30 ~.17 0 16 S 7 3'E -1.47 0,13 0 25 S 5 5 '5 -1,62 3,33 0 22 S 24 35 E -1,93 0,2~ 0 i4 S 23 15 E -2,22 O.l~ 0 15 S 3 51 ~ -2.35 D.Og 0 20 S la 55 E -2,52 J.25 0 17 S ~5 35 E -~,sg 0.41 0 6 N 59 1 E -3.16 0.31 0 59 N 11 50 5 -3.26 1.50 1 27 N 22 5 E -3.60 0.72 1 1 11 15 13 21 28 31 N 52 39 5 -&.8,5 ].5~ 39 N 31 25 W -5,42 3.11 11 N 5~ 4~ ~ -0.35 15 N 70 i1 W 19.30 3.5,5 19 N 7B 47 W 27.74 3.6,3 0 N 75 35 W 51.15 3.5,3 ~8 N 7~ 33 W S1.30 3.59 26 N 7~ 54 W I12.0~ 3.01 34 N 322:3 W 150.25 3.49 38 N ~1 $ W 210.35 13.72 32 37 38 39 39 39 39 39 39 39 55 N 79 32 ~l 259,93 3,75 3 N 77 37 W 1340,11 3.02 56 N 79 12 J 419,14 0,45 12 N BO 2 W 500.24 0.37 21 N 8D 15 ~ 582.06 25 N 80 7 W 66~.29 3.20 19 N $0 12. W 745.36 0,25 ? N 8J 7 W B2';~,01 0,22 3 N 80 1 W 909.14 0.0,5 9 N 79 36 W 99].15 0.45 SIJ _B-S R~'TAN3 NgRTH/S :!ET 0.00 0.23 3.13 0.35 3.2 '3 0.~5 0.~. 1.14 1.27 1..$1 1.74 2 .37 3.55 3.~7 4.51 5.05 ~.39 2.12 0.09 1.55 ~.51 14.73 19 .~90 23.9 ? 35. ~ 2 50.05 60.15 74.28 90.16 134,77 118,54 132,71 146.55 150,55 174,54 3JT-I : ~.ST/W"' ST giST. O. 0 9 ~ 0. 'J 0 ,3 · 65 W '3 · 5 0.57 W 0.57 0.3 :B W 3 · ~ 7 3.2B W 9.53 0.0~ W ,3.~4 O. ~5 E 1.~0 O. 77 E ! · 43 !.lO E 1.79 1.22 ;~ 2.12 1.27 E 2.59 1.4'~ E 3.4:' 1.70 ~ 3 · 94 1.75 ~ ~. 34 1. ~5 ~ 4.88 2.15 2.41 ~ 5.59 2.52 E 5.11 3.5g ~.'gO ~ 4.'~0 5.72 5 5.93 1. Z 1 E 5 · 9,Z~ W I~.25 23.7-} W 2~. &B,68 W 5'2..5 ~ 77.92 W ~g.::~2 113,79 W 11~.~ 155.46 W 161.35 332.65 W 340 · 85 489.98 570.62 651.65 ~ 56~.03 732.3~ 812.~ w ~23.7I 89 Z. :~ 2 972.~9 CDMPUT~TIO~ Daf=: 26-J~N-%5 P~;E 5 ARCO aLASKa, INC. 3~-11 KUPARUK N]RTH SL3~E,~L~SK& INTERPOLATE3 VALJES ;OR EVEN 100 ===T 0= MEASURED VE 3EPTH TRUE SJB-S:~ RTIC~L VErTICaL DEPTfl DE~TH CDJqSE 26VI~TI31 aZIMUTH D~G MIN DEG MI~ 4307.5Z 4~35.85 4555.91 4594.14 4821.59 49~7.9~ 5073.85 5198.59 5323.83 5~¢8.23 3972.00 3900.00 ~072.00 ~000.00 ~172.00 ~lO0.O0 ~272.00 ~203.00 ~3TZ.O0 ~303.00 ~472.00 ~57Z.00 ~500.00 ~672.00 ~772.00 ~700.00 ~872.00 ~800.00 39 17 N 79 33 W 39 ZO N 7g ~Z W 39 0 N 79 45 ~ 38 Z8 N ~0 5 W 38 ~ N BO ~1 W 37 33 N 80 53 ~ 36 58 N 8~ 58 W 36 ~7 N 81 $5 W 36 51 N 82 Zl W 36 Z2 N a3 1z w 55 55 5B 5~ 6O 63 65 67 1'2 96 Zl ~8 T¢ 01 27 54 79 03 .3:1 .77 .85 .22 .75 .8D .2~+ ~972.90 ~900.00 5072.00 5000.00 5172.00 5103.00 5272.00 5200.00 5372.00 5300.00 5~72.00 5~00.00 5572°00 5500.00 567Z.00 5503.00 5772.00 5700.00 5872.00 5~OO..OO 6~ 71 73 73 27 51 75 ~6 18 5O .~5 .03 .71 .18 .OD 5972.00 5903.00 5072.00 5000.00 5172.00 $100.00 6272.00 5ZOO.O0 5372.00 5300.00 5398.20 53ZS.2D 36 17 N 8~ Z W 36 7 N 83 23 W 35 26 N 82 ~$ W 34 34 N T? 14 W 34 34 N 77 1¢ W 34 3~ N 77 1~ w VERTICAL DSSLEG SECTION SEVERITY ~EET 1071.89 0.09 1133.72 0.22 1235.23 3.31 1315.52 0.50 139~.54 3.63 1471.75 3.53 15~8.29 1'522.82 0.55 169~.30 1.01 1772.17 0.4~ 1845.70 0.27 1919.57 0.29 199~.55 1.23 2~71.74 Z!49.1~ O.iZ 2225.53 0.73 21303.91 3.29 23~0.77 0.79 2~55.52 0.42 Z52~.90 9.25 2502.43 1.21 1.575.32 3.45 2748.21 2.17 1~17.50 0.00 290~.30 O.O] O~T .... ]F SJ~V"Y: <:LLY 5USqZ~"' :q:S''~:=R: N':ST ~:OTH R~CT~NSUL~R N]qTq/S3dT~ FEET 233.35 247.!7 Z60.3~ 27~.50 29:5.55 306.Z~ 315.57 323.~0 331.24 335.3~ 3~6.?0 354.50 36~. 28 369.33 375.57 3 i~ 0. B ~{ 386.12 '~00.52 CCJqgI'~ATqS Hi,ii. EAST/W-ST gIST. F~ET 1053.10 I133.$~ 1213.~$ W 1236.07 1292.~2 W 1315.33 l~79 ;33 W 13'~5 3~ 1447.07 W 1~72.52 1~2_~ .57_ 1595.3~ 1671.11 'N 174,.,2 W 1772.73 1~{17.54 W 1~46.16 'i$9!.1~ W 1~19.~3 1965.92 20~2.7~ 211',).57 w '21a9.33 2197.27 2274.17 W 2303.~7 2350.97 W 23:~9.79 2425.~{1 W 2555.5g 24'~9~ . 2~ 2572.53 3i 19 W d I 17 ~:.0 ~LASK~, IWC. 3~-11 KJP&RU~ N3~TH SL3PE,~LaSK~ TOP ~UP~RJK ' ~$E KUPAR~K C TOP ~UP&RUK ~ ~SE KUP~RUK mBDT TO CO~DUT~TI3~ iNT=RmCL6TED V&LJES F3R 5EL3N KB 5327.00 6865.00 594`0.00 7077.00 7Z53.00 7350.00 D~T=: 26-J~N-B5 'HOS=N ~3RIZ3~S 5971.53 6003.04, 5052.57 5173.61 531 3.34 63~;B ~0 32!GIq: TV) 7:"38 ' 5~31.04 5~90.57 5101.51 5325.!0 " 'q :3 ' ",l ': =~: ..,IZST =S'L, SJ~Z&:E _3C 813' -= S~~ 7, R~CT~NSJLAR CG 3)2.41 ~ 427.7~ q 7'. '"" =T T12',~, R9£, g',t '3 R D I,,1 ~ T ='; '-' r, S T/~': .5T 2572.~1 w 271~.75 ~ £~17.13 ~4 CDMPUTB. TI]~I DATE: Z$-Ja, N-~5 P'~]E 7 3~-11 NDRTH SLgPE,~LESK~ TOP TOP BfiSE PBDT TO M~RK~R KUP~RUK ' KUDARUK C K~RUK A ~EASJRE3 DEDTH ~DZT.OO 5S55.90 7077.00 T253.00 7350.00 SJ'qM~RY ---,q G I 'q z :-- R: .N=ST ]RIGIN= 755' TVO SJE-S=~ 5971..53 $003.0~ 5062.6? 61'73.61 5318.34 5398.20 5599.$3 5990.57 5101.51 5325.20 213' = N ] 5 J R:.~ F_, E .]C~TIDq SEC 7, T12'~ ~TH/S'JTH 352.~1 q 2572.41 ~JS.I7 'q 271~.75 ~Z7.7~_, '4 2~!7.1. J.. ~3g,5) W 2~7]."30 FT FINAL ME&SdRED DEPIH 7350.00 WELL LDC~TI]N TRJE VERTICAL DEPTH 5398.20 &f TO: S~B-SE~ VERTI2fiL DEPTH $~Z6.ZO -d:]RIESNT~L ]EP~TU~; DISTfiNCE &ZI~YJTq :E:~T DES M!~ 29J~.31 ~ ;51 17 SCHLUMBEROER O ~ RECT I ONAL SURVEY COMPANY ARCO ALASKA !NC WELL SA-Il FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 000071179 WbJLL~ - JA-l£ (768' FSL,813' F~-rL, 87, T12N- R9E) F:~I:ILE = I/S00 IN/FT HORIZONTAL PROJECTION soO - 1000 - I ~00 SOUTH -2000 -9000 -2500 -2000 -1500 -I000 -500 0 E;O0 1ooo EAST WISLL - 3A- 11 (768"FSL, 813' FEL, S7,r 'N, R9E VERTICH PROJECTION SOUTH -2000 - I500 - 1000 -SO(} 0 O SOO 1000 ISO0 2000 +.t.-H:'-.'...,b,f,.~ :4~:bi-~.';-~.~4- ~.~.~.½~ ii i i~i ~i ~ i~i F~-~.'_.'.' ~ ~ ~, .4-.-,,..-Y-L 4 ! ! )-~ ! ! ! ! ! Y! ! ! -! ! : ! ! ! ! ! ! ~ ! .:" ~ ] ! -.L~- i ,_:-' :: ~ ! i ii_--" .:. i ~ ~ ~ ,i -:. ,-4-.-.':4-+--f-4t~.-+½~ }}}+--.b+4+H.+H ibii~ii~.~-il iiii i l}i~i~ i i!i.,: ii!! !!il !!!5 -4....4...~--~-..¢--~-.*...;--;-~M-L..L-.--.¢...L..~.~...-~--.¢--.~--~..-.~-4,...L--L.-~4-4~L~--4~ i : :' ! · ~ ._' :' :' -" ~ ~ } i i i i ~__~_t i -~---L4--~---.*-..].-4--'l..b--~l-.i--g4..~ ..4.4-.-$-..L.; ~ ~ --£...L-,L.4---14-.4-.,i-4-~ ~ ~ ~ ';~ -:,; ~ :: ~ .: :~4-L----5i~4-~ L,-,""'~'~: ;~ ~InNi :"' .~-"H-:'i-:i-S1 ~i ~ g -Fl : i i i I '-' [ ( ("T i :-'-T"T--~-T i , ~ i ! i i i i ! i i i i i i i ! iq i i i ! ] i i i i ~ i i i ! ? ! ! ~'-I J*--g'"i--~l'-~'4-4~'~---;'-'~+4~'l t · , · ' ' ' ,-.i-.i--i...i ..... ;-.;.-.i-4- I i ~--.i---4..4-&~ :: ! ! ! ! ! ! !. ! i, ! ! ! ! i i, i ! :: :. ! ! ! ! -:. i i :l~ i :: : : :: : : :: ; : :: : : :l: : : :: : : :; : ; : i : : : : : : : :il:: : : i -,1]i i : [ I I [ ; T: : : : : : ; : : ."TY}[ Ell." ::-- ! ." i ii: iiIrii [ ' "~" -:-'- ; = i ;'-?-?" ..... *-'"'"*""f'" '"?'-*-'*'-? ..... +'~~"?'~'"--~-'~"--'"' :· - ; : : : ;: ; ; : : : : : :: - ,.~...,- .-,...: :-4--,l~-~..-~.~..~. l.......,...~... ...... ~.-.-...-. · ; ; : .-~--~J : : ~..~---~ : : : &-4, ~ , i i ': :~ i,---i :- -: ~ -..b-..;- .... ~.- _+..,.. ~...,...~.__?..,_,:._+.._,+?...: ....... +.+.+..., .....; ,--?*-+-'-?'*.-+: ti-+:'--++-+--.'-: ~: ~: :-:~:q-+' --~: r~ --+~--r-~: -'--- ~..-" ?-.."+~,'- : : I'~ : t : ! : i I : : , ; i : : : : : : : : ~ : : : : : i : : : : : i : : : ; : : : : : : : : : : : ---}----~."--H-+-Hi."-4 ...... ..¢-..H---'.;-+.~...b--;'----} ...... f-..H-.-:;--..-.Ht---:'---'} ..... ~-b4-.~ i-i--&+.-.4."-+4 i ; i-.~-~..~>+- ] [ ~ :-~-.-+-¥-¥-H--~-¢-.: -~-4 +-44--L.-4--4--b4-...-4.-b-4--i-+4...:.,---.b-;' ...... b.4...4..-b.b4...b.4.--.L--4---~-.4--4-...~-~.-' i.,,~N~:: i ! i, i~~--b.~:'-4-.' ~-.4. i : ; ; ~ I ; ; : ~ ! : ' : : i : : I - : : : : : ; ~ : I lJtJN J : : : : I : : : : : l ~;,~-4--.} -,~ ........... -4-4-.---i. 4-- g 4.--.; .;- { .;..-- i-.-,;.-.-; .................. .... ;....;...~...:....-L:...-i.-...i.---i ...... i---.;---.b--;---;--;--~} '"-~-*--t'-' ........... .~--~i---.4--,i------~;--~-.;-J~-.'---4--~ .................... i ! i ...a--,~-.i.-q-4--.~..i.--~. -.i.--4-.4~- ~. .--';-..i.-.i-.-'}ii ..... ...... i--L..i--i.l! -.-i-..i-4---.~ .... ...... 1 L..-;-..i-..i .................. ...... i--.-L--i-.-~...- ..}---L---;-.--}.--~ ...... +--i---~--.i,---~: -~' 4,---. ..... -4-+--i-~--i-i ............ i 'i :. 4--4.-.UA--~--.i,-i.--~-- I : 4--'¢-'L'4-'i -?--.?---~.-.? ...... '1'--'?...'~---? ..... ?-..?---~'.--f .!-..'~ ..... ?---? ...... -,---?-.-?--.?"-'P-.'7---5--.? ......... ~.--?...?--.~..{.-?...~..{...-~......4....;-f-.4-...i.-.4-..z-~ --{...~.-4--~.~--~.---..;-4.....; .... ~..L.L-L~_,T~..L.L.L-i.~ -~£.-.L~-T]--L.L.?~ · ..}-..}....~.-i ...... i-4...H-} ........... ,.'-.:---4 ..... t--4-..} ......... -~-.~--.H?---4--.?*..? ......... }--'b4--4-t-H~.4---.-4-4--.H-.-,[-4--4-4-4 ..... b~--H-(.-H-L4--- ~--(--H~ ..................................... ,-: ............ t ..................................... , .................................. , ....... ............... - ....... "'mr .... i...i4..4-.....,'.....L.!...i...~.4..,b.~...i ..... L.i...i...; .... L.L ;...L.~...i..+-L.i ...... L4-..L-L.. -.-L.' · ~...-4-L.L.L..~.;.-L.-;-. M..4-4-L .L..L.i.4 .... L.L-L..i.J...L.i-i-i- .-Li.4...i-. .... .....,. ....... ..... ..... .... i...L.L.i ..... i...L.L.i ..... i...L.i..,i- ...... L.i...L.i ..... -'.:..L..L.i...:.-.i....L..i..-i..- .-L..i-i---i ..... i--.i-.-~i-- --i -: ..... -.~-i ,"-~'-'r'l ...... r"'"'"??"l "'?"T"?'"?"T'T"?'"?'"? ....... T'?"t'"T""r'"?'"T'"'T"'.*.~' -T".'W'..'F' :'Y' -Y~ .-'T~-. - '-T'": :'F-~.--.'~'' ..-T-W= .-'?--t'- -'.?:'T-y'y"F~T"T"T'"T- ""'F"T-'?-?-T'",'T' ..~: ..- -:T'"'T-C-'T"~ .'-T-. 'r--'7'"T.. .... -.J...,i.~.~--+ ....... i..,~.,.~-...~ ...... ~.....,*..* ......... 4-.4.-4. ...... 4...;...,....,; ..... t.-.~-.-,..-.-;..-,--$-4.-.~-;,.-. ' ' ' '---.i-4---.~-~ -: i i ~ --4---~. ' ' ' }-4-$.--~-..~....4-.i.~-~.--~--4-.;-.-~..~.. .':-.-}-.;"-..i ....... b.H...4 ...... {''"U'-""'4'"I'I'{I"+'"4'"{ ....... H-..H.-.J---0-.H---{ ...... i-H4 } i-i; ) i i [+---..'..+Of--.~--~Hbf---+--H:--;H--H-f-t'- t'".'."'i-'! ....... i_.f..fl~ ..... i...t..lill.t.4?..%l? ....... t'''!''ltllt'!'''t'''t'lT'i''''--~ i ii --~?N--i--??lt--t'l ~'?'t--'--'~M'''???'i ...... t'--i--?N--?t?":--'' -.?.-..i.---4..-..} ......... H...;.--.i.-.i ....... i--.,.--*...~..-, ...... · .......... ;.--*---,.--i..-~---;--.:t--~'---'?..---.~O { ~: : ~ i{ i } 5 .~--4-----.;-.-4---4-.O---~--4---,~--..~--~-'--;---4,---4..--~-,---4---4--4---i.--.~--~--.~-4--4---.-4--,'~-;,.---~-. · ~...4....b.4 ..... 4-..4...4...4-..i...4...+.-.!...~.-,...4.--~..-4-..i ....... 4..4.~..i.I..4...4.--4-..4 ....... ~4-.J } i i }4- }{ 4-b.-:'.'4-:"-H.:,-----b.4-4.4.-{-(--b-b~-.-4...0-g-4-..{----b4-4-4--- ~.,,i...i,,,i ....... i....;,..i.-.i...q...;....H-4....;.-{...½...+.-i..--; ....... i...;....:...+...{...L..,~....~.-.?: ....... g-0-'{'} ~ } i i" } } .}.-4.--,~--4-4-b--H'.'~:'-0+-;;--.~4--4--.b4"-b+---b4--..b4--- :T:!:::U::'F~..:i:T~;:~-.-~...!..-:~T:J:-.!---H---:.~: q-..!.-.!..-q. ~.~.~-.~--..-i--H--!~:+-½-!-.:4-H---b-~z.bi---i .... i--~-+-..'--!-H4--,+H4-+-!l-lbbb H---ill-H4-+-b-Nill] I ~,ll~ll ~.l ¥.jl'l:'''~ f'll? ............. +l.r,,t ...... ?,.;.,, ..... + ....... t-,,~l- l ..... ~.l.+ ......... H'H".'" H'f'+'+".~l'~ ...... H'~-+'l'.:'"f-'H'H't''-' ...... H'f-H'%'f'IH"5-'F l+l'j"''%H+''?+''l+'''?~' '5''' ['''H15--?'--::l'+''?''''r--~'''HlJ i. ~llt.. +. l~''Tl';''4' ~l''~'''[l'l~l''~''l~' ~'.li.1~'',''-~ ........ ;''l?+lll''''j 1.+ ...... ;l'l~ ...... ~''~--.~....:.''''{''.¥''i--'--~'l'~ ...... :~'4'--¥--'>'.H--''Hfl--'~ ..... b.H+.,'~'''!--fl--1}--..il..HLf----~----l~--'.b.j----~--l--~----l~l----~'----t.--.HHHH------Hf'.Hfllt ~..~., H"i-"H' ~ ~ ...... f-i-'"R'-! .... :-+--! .... L!'"t" ;--'i"::-;'--f---'*+-f--tT-f-'H?-~'-H.'-'-f-'t-i-+-ff-ff-t ....... f--!-'-f-+ ~-i"-ff-f+T--f--t--t'-i--i---?--'t--~ ....... NinTH I! PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALEO IN VERTICAL OEPTHS HORIZ SCALE = I/SDO IN/FT WELL 3A-11 (768' FSL, 813' FEL, S7, T12N, R9E VERTICAL PROJECTION -SOO O 0 ~ 1000 1 ~00 ~000 ~00 3000 -.'-4-. ~i ~':~ [ i ~ ~ 'j:- , ~ ~ ~ i~i :.~i ..-~ ' ...... -:- ~..~-+...f--+---i-.4-+--f-"'~l"J'l)"~'l ~.' .-f-f-~, ]""?-t'"r'rTT-~-T, · : :TI ~ I i i i ! i i i ii i i i i i i i i I i i i ! ! i i i i i ! :'L:L:4-L...-LL$~,4-.;-44 .... t-i--;.-.~-.4..-.:"-4-l--,~: ~l---4-l! J ! i ii il i i ~i i i f ii, i ~i ~ .k~-J J J"J' [ ii i d-4"~ -t-i-",~-+"-f-, .t't~ .-t-t'..'t-r"~-..'!-:~'t-.- r--"-v'v:-T"r".-F'i .-?T:"~ [ [ [ [ i ] i i ~ ! i I I i J i i i i i J i [ J J i ! ~ J i i ~ i i i ! · -~' ...-~ '..'!-i-; ..-f-f-;"-i-f-!.:-t:-"-?".:"'!'"f"l-i-~'-~':. J i ii i J ii I J ,? ! !! i i ! il i i il...' i i L '-t'~'."P~--'~--?'+'"?-f";d--f:'"f-'.'.' ....... '.:-i'"..~i'T'T-!-T-T-'T~ ...' '..' J:J CF i i i t i i i i ~ J'i i ! i i ! i i U 1 i i i i ~ ~ .: ,' .~ ~ · .T_4-~..-kT---~-.-j,--,e~---..-~".:'?-:-.t"'U'U'? ...... ?T"t'1 ..... t.-TTT" :.-T~.~T?-1 :.. i i i I i J i i J i i J i J i ! t } L ~ ~ ~ i :.. ~ J i4- - !--- '+-'-t-.-~l~j-.'". ~-r-t---T-T-~t--'--t.".?T-t-'- : :-T-r-: f'! J ? j i J ~ i : i i i i I i ~ ~ ! i i J J i i ~ i ! ~ i i ~ i j i i ! } i i_Jr_£.4_~.. -l-4...j--~..-.~-..i--~-.-4--.~-.l--f?.~-~--f-..~-.i....--+.-i---i---i-~--k--.~'?'--+.' ..-!-T--~'- i i i i i i i i-i I i ] i I ~ ~ J~ :-I-%-' ..'-'U'~ .'.-'U? J [ i i i ~ i i -4-i-.:-.i-..~-.4-¥-~4-...--4-.~---i--.: ..... .~---¥4-~-~-j i "..,--?i ~i i-?? tI -.~-:.4-? i ii ~ i i ' i -:T-TT' i i i )'~ -.~-p.4-!-..-~-~...-~:--t--..'-"-t..--..'"':--"~'":"'r'T-'I"-~.:~T-T--~ ..-' ~-~-UT-: ] ..' ~ ~ i: i i J :: .: ~ ~ .-' -: -.' ~_:: i i ..~ i ' ' I i i · ~ i i i i : i ~ ~ ~ ~ '.- ~ .= i -'_ _-' ~ [ i : : : : : : ~,~1 _'- i .i..-: ! '-' i i '.~,t..4-~ ~ ~,4--.~ :, ,;..4--..~ ..4 ..... : ' ' -..i--4-,1~-4. .... ., ..4...~....,,...4. ...... ,i...4....a.........~-,,--~.-,,~--,---..-~-.--i---~ ; ; ~-,.-- ..-*-.,--~. : . · ; -..?-,-~-?~., --.'t-.-'l--r . : : : ......... -..)q.4-4-....4...k~-..-~--~.-.;:-.,.' ....... .L-F.~--.i ..... ~---~.--~---f---t-.f-~-'.:~'t--~-~ ii .--?~i--.] ~ i .~?~-i-1-N-f-f-~--~'i i L,-':-'~ · ~. · · ' ! : : , , : : ' : : : ......... - ' -i~i-- --i--i---4~.i- ~-i-4-4-.~.--, -4-~:--.,--.~.-. --~.--~,-~ ,--~-~,-.--~- ~..*-.~ ~-~-~'.--'r-r- - .... ~ ................. ~'~"'-'"'"'? ........... ?":'"? ...... ?':"':' ...... '-'""~""'-'-'-'-~-'-~"-~-7. ....................... · L,-4q- -;-~-,-.;- -~ 4-;4 ...... x.;...;..: ...... ;--~.--.;.-.~..-I--..~--~--¥-.;----~-.:~:-~--~- ~-+-~-~-.--i-~--.~-e~--.'-~-...-f4..'-4-f"r"~--t"r-'.---'"m-.,'"..'--t-U1-.: '.--'~' 'T'Y't-T"J-:7'T'T"T- /ii : I : J : ' ' i ' - ' , · I ' ' : ! : ; : . i i ' ' ' ' : ' :: i ] : : i ~ : : : ::i_!i!:: '.iZ"~::i :::::::::::::::::::::::::::::: :]::i:i::'-;:LI...i....~..L'-' ...... E.7.:_:_~. 4-..~_i_.f...--~;F~kk--kkt---:.'-k~4-f;- ~q---i-~.-tq--h '..;-.-.:--~-+-H-+"H'+-f'"::-1 -.4-i..',-..t .... ,N..-.:,-4 ...... i--~4-.-t.-+-.i-%-i ..... -.'.:.--f--.i-.-!-+-H-%-f'-'~"+~+'kf--':.-f'i'ff½ ii CH'"k?:'"~""-ff"t't~'t'-~'l'Z~Z:E:?'.:::t:tR] --'~-~ !~ ~-l-i.i i ~ : i''i' ..... ~iI~::: : .'~'--;--i .... ...... ~-.-*'-'; -'~---~--H-+-i i : ! t i i : : .... i'-'P'+'+i ! t!-.~'-f'+-'t-'?-?-?-t- .! ,.':~. i ] i ]"?~-'t-?--'T'T-TT-?-T"~-T"~..j ] ] ..... .? .-'~T: 'T -FT ; ' "~U%~] ""i' J ! J ] i · : ! i !'T : j : --J ; , : , : i : i = : ; ' i i ! i ~ ~ i ! i ! : ~ : : : : : -.' : i i ~ ~ ! ; ! ~ ~ ! ~ k: : : : : : : ; : '_L: : : i : Z...i_.i...~-.~---i.--; I. , :.. _~.; ~. ~. i : ~-~-! 4.-.;...~.-.; ...... ~...;...~_~..J,...~...~.~.-~....4.~.~.~?.-?-~. -:-?-i-~-?--? ..... .,-~. ?---~-,-~--.- ..... t-t-..~nc~.. .?-t..-~"..-t--m~ ~ : ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: !ii iii ii ~.4...!....i.-~.4.....:'-~ ....... ~..~...~-4 ...... ~.+.~-.~--.!.-+.+-+--f-h~-+H J j jif ill ~-'~t-'H-t:-t-t't--"t-'r-t.~'t-t"~t~-ViT. i~'Z;Z>'-:]]L'F!? ~7.'..'~L ..J...~..~-~ ...... ~...~..,~--.i ....... i-i-..i-; , l.--.L~..,i. ~ i-.i 4...-.'--. i"?~-' i ~ .; ~ ! .~-,?t~...--'~.-?'??' -?-t-?V--~.'"'T-T'- 'T-'?--T' ~ T ! ~ % ~ i .: ~ ~ ~ ~ T !~ ; : .-~..~.-~...~---.~.i-'.,-.;:'.....-k?;..-~ ..... !4--.~--.~ ...... i...~.?.-.-:-..~+-~ i!ii'iii F.+~]'+++--~-.~-:t~--t--t'-t?'}-t-t---tt~!-t-'tt'"'"t~"t-t'p'"t"T"t"l .4-.j...L.~ ....... L4-..~...j ..... ~h~'"½"'~ ...... ~'"¥'~-'-~"t-+--~r-..'f : J J--';-~-f"'.:.-t-'f-+-'f"~ ..... -~-'~"T"'..-d-'TT".-'.-F'UT-T"'-T-'VT3.-'--'.-CT ....... ~-'..'"'--T-T-'~q"T'T":"I ~ J i i ,~ i ! i~ i i i ~ i : ~ t! i: Il i t ] it ~. ~ ~...[-.-"-.L L]...i...L...Li.,~.~.4_.L..L..i-.~ ..... ¢--:--.-L.-;--4-~.-;---,--.; ...... ;....;_~_...i....L4...¥..}_;...! , t ~ L~-' T~TL--L}.]--L-L--i ...... LL-;---~-.4.--~..4..-~--~ ...... ~---L-:..'---~-+-N--4-~-.---N-N---*'---h-¥--i-4 "'~~L"~'"i'"{"+"~'"f'"! ...... !'"?"";.""'t-!'"f"!'"¢ ..... ~.'"~"~"t'?"¢d'"t ...... t?~.".'-~- ~ ~_..4.4_Z_L.+..~_~...i_..i ..... L.L-~4-1-4---:,.-.L.;]---L4---.L~-J-.-~---~---~---~ ...... -L-~---;---~---i---::.--~.--~--~ .... "'i"".+"'?"f"t"f-~"~".f"-T"T"T"V'?"';""~"z ......... ~' :'"T"~ 'T'"T"?'T'[ "'T-t.'"'!Z'? ]].T'T'T .... L..~..i_.i_..L~.._L.~ ...~ ....... L-L~--~.I.--.':..¥-4-~.-L--L4---L--L-t---'~---L-~--- -~--4---~---L-*'---+---~ --~--+ .... '"t"t'"t'"t'i'-'t'--t'"~"?;-'T'T"T"T ...... T':'"T'"f ~"'-".'"F'yF'!'-","TT .... FT]'-'T] ~ .,'FFF ~ i [ i :: i ': :, I i ~ i / i i i ~ ~ ! i :~ ! : ~ ~ '; ~ ~ I ~ ~ ~ :. ::...L.L.I...L.z...L.~ ...... ~..~ !...,...i...!...L.L...L.....4_,L..~...-".*...L.L-.~-¢-i. ...... L.L..¥.~.._t....:-.-z--¥.:.. ....... .;.'-.%4-~-4---.;--.¥-~--4-.-f.--;:---¥-?+--i---?-~--+--¢. ....... f--,..--?-?.t-'-f--?--T-~," · "."-?"'T"'~ ...... T'~?'"~"'~ ...... ~'": ' "[ | ; i ~ '[ : ? / : : ~ ~ : ~ i ~ ! ! ! ! i ! = : : : · = : : : ; : ; , : ......... ;. ~ .,....z...~..;.... -+..i----+-.I-.+-~..+.+-. !.-.,:-.~.--~ ..... r--+-~.--¢-..: ...... f"?~'-";'-T"?'~-r"'.. ...... -.;-4-"t-'t"Fr-r'?-: ..... ~.:.-T-......*..TF.T..T.T..-.T...T.`.-...-..~..T.T.T.T.T..I...~..-.:...T.ZT..:...~]?]Z~]]]~].L..~]i...L..~.i... · -+--.~'"~'"".'-'k'.~'"!'"f-~''' I"'F'f"~'",:'"t"!"?"t"'?'i"~'"~'"t'f'T"t'"t'"~-T ....... '.-'.-t-'t't~'bt":,'"t'"'-'?-r"Y'~]'!]]]]i.] Zi]Ei]]]~.T.E]]C[.T.]]!].[[L'.C'-:.'...L.L..I-4...!...L..:-4:~-L--L: ~ ...i...?~...i-I...f.+..~..+..[...~1qI3OI3t.T..:...i...:...T...:..~..~..!...7..:7`?..~ ...... ':-'"T"t'"T'?"'F'T"':']'"T"?.Y:'"F! ~ ~ :,~i ~!ii ~ ~;-: ~i~ i, I~: :: ~:~ ~ ~ ':: PROJECTION ON VERTICAL PLANE 2'78. - gS. SCALEO IN VERTICAL DEPTHS HORIZ SCALE = 1/SO0 IN/FT ~-78. EXACT RAO I US OF CURVATURE METHOD TIE-IN LOCATION MEASUREO 0EPTH TRUE VERTICAL DEPTH O!STANCE NORTH DISTANCE EAST BOTTOH HOLE COURSE - LENOTH COURSE AZIMUTH LOCAT I ON 0.0 0.0 0.0 0.0 2904.4 ~78 .? FT FT FT FT FT DEG MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH OISTRNCE WEST 79S0.0 6998.9 499.9 ~870.9 FT FT FT FT REF 000071179 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. . . 'OPERATOR, ' Reports and Haterials to be received by: /~--/ 7- Date -Required' ' Date Received Remarks "' L , Samples Hud Log ~~ ~.~ p/ - ~ .~,/< toro Chlp8 ~ . Cbr~ 'Description . Registered Survey Plat . . Inclination Survey Directional Surve~ L. FJ. 04 ARCO Alaska, Inc. Post Office BG'J~i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-31-85 TRANSMITTAL # 5497 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Open Hole/ Schl/ One * of each 2H-10~ 5" DIL/SFL-GR ~ 2" DIL/SFL-GR % 5" DEN/NEU ~2" DEN/NEU \5" DEN/NEU ~2" DEN/NEU ~Cyberlook 2H-11 ~5" DIL/SFL-GR (poro) (poro) (raw) ( raw ) ~2" DIL/SFL-GR ~5" DEN/NEU-GR (poro) ~%2" ~,, DEN/NEU-GR (poro) DEN/NEU-GR (raw) EN/NEU-GR (raw) yberlook (poro) (poro) (raw) (raw) (poro) (poro) (raw) (raw) 3A-11 ~" ~IL/SFL-GR \2" UIL/SFL-GR ~5" DEN/NEU '2" ~EN/NEU ~5" ~EN/NEU ~2" DEN/NEU NCyberlook 3A-i2~5'' DIL/SFL ~2" DIL/SFL ~5" DEN/NEU ~2" DEN/NEU 5" DEN/NEU ~ 2" DEN/NEU ~-,Cyberlook 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run 01 11-23-85 Run 01 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run 01 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run 01 11-16-85 Run #1 11-16-85 Run #1 11-16-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run #1 11-23-85 Run 01 11-2~-85 Run 01 2856-7960 2856-7960 2856-7934 2856-7934 2856-7934 2856-7934 7500-7900 2744-6752 2744-6752 2744-6727 2744-6727 2744-6727 2744-6727 6190-6705 3208-7330 3208-7330 6600-7303 6600-7303 6600-7303 6600-7303 6600-7250 3797-8006 3797-8006 7200-7981 7200-7981 7200-7981 7200-7981 7300-7700 aska 0[1 "':~? :las eons Commission Receipt Acknowledged: State of Ak*bl/se Rathmell*bl Drilling*bi D&M*bl NSK Clerk*bl Vault*films Date: ARCO Alaska, Inc. Post Office B'D,x'~I00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-11 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3A-11. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU12/L159 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .. STATE OF ALASKA ALASKA .,~__¢,r AND GAS CONSERVATION C. ./IlSSION WELL COMPLETION OR RECOMPLETION' 'EPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED C~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc, 85-238 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21z~58 .. Location of we, at su,ace ~ ..;# 9. Unit or Lease Name 768' FSL, 813' FEL, 5ec.7, T12N, RgE, UM Kuparuk River Unit , At Top Producing Interval 10. Well Number To be submitted when gyro is run. : ': ~-; ~' :' :::~-~ 3A-11 At Total Depth 11. Field and Pool To be submitted when gyro fs run. ~[1.$~,~ 0ii ~ GS:'~ O0i]S, C0~iiiiF, Si0~ Kuparuk RSver Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease ues~gnat~on and~er~a~ ~o1 Kuparuk River 0i ] Pool 72~ RKBI ADL 25631 ALK 256~ 12. Date Spudded 13. Date T.D. Reached 14. Date COmp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 11/11/85 11/15/85 11/17/85I N/A feet MSL N/A 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 7350~HD 7253~MD YES [] NO ~XI N/A feet MD 1550~ (approx) "22. Type Electric or Other Logs Run DIL/GR/SP/SFL~ FDC/CNL~ Cai 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD :AMOUNT PULLED 16" 62.5# H-~0 Surf 106~ 2~,- 185 sx AS II 9-5/8" 36,0# J-55 Surf 3209~ 12-1/~?' 1050 sx AS III & 300 s: Class C Performed top job w/10( sx AS I 7" 26,0# J-55 Surf 73~,2~ 8-1/2" 500 sx Class G & 175 s~ AS I 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. I~/A PRODUCTION TEST Date First Production J 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 Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology', porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 TEMP/WC96 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 130. ' . . . ~ . GEOLOGIC MARKERS FORMATION TESTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS Well Hi story_ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~/7~J ~ Title Associate Engineer Date /2-~ ~ -8~' 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, a~r injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the'cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-exPlain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO 011 and Gn Company Well History - Initial Report - Daily I~l~l~al: Prepare and ~ul~mlt the "Initial R~I~O~I" on the first Wednesday after a well is spudded or workover operations are started. Dally won prior to SPUdding should be summarized on the form giving inclusive dates only. District IState Alaska Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0332 Parker 141 tCounty, parish or borough North Slope Borough Lease ADL 25631 or Unit Title Drill IWell no. 3A-1i API 50-029-21458 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate IHour 11/11/85 Date and depth aa of 8:00 a.m. 11/lO/85 thru 11/12/85 11/13/85 11/14/85 11/15/85 Complete record for each day reported 0300 hrs. IARCO W.I. Prior status if a W.O. 56.24% 16" @ 106' 2967', (2861'), DD Wt. 9.3, PV 10, YP 16, PH 9.5, WL 17.6, Sol 5 Accept ri~ @ 2245 hrs, 11/10/85. NU diverter sys. Spud well @ 0300 hfs, 11/11/85. Drl, DD & surv 12~' hole to 2967'. 2195', 5.9°, N57.3W, 2194.76 TVD, 9.20 VS, 3.29N, 8.83W 2696', 21.5°, N78.SW, 2679.89 TVD, 127.07 VS, 34.45N, 123.43W 9-5/8" @ 3209' 3229', (262'), Prep to DO cmt Wt. 9.3, PV 8, YP 5, PH 9.5, WL 18.1, Sol 5 DD & surv to 3229', C&C, short trip, TOH. RU & rn 81 its, 9-5/8", 36#, J-55 HF/ERW BTC csg w/FS @ 3209', FC @ 3128'. Cmt w/1050 sx AS III, followed by tail slurry of 300 sx C1 "G" cmt. Bump plug. ND diverter sys. Perform top job w/100 sx AS I. NU & tst BOPE. PU BHA. 2849', 26.5°, N82W, 2819.66 TVD, 189.28 VS, 44.83N, 184.79W 3184', 38.1°, N77W, 3102.20 TVD, 368.20 VS, 78.95N, 360.66W 9-5/8" @ 3209' 4990', (1761'), Turbine drlg Wt. 9.2, PV 8, YP 5, PH 9.5, WL 16.4, Sol 5 TIH, tag FC @ 3127', tst csg to 1500 psi. DO cmt & make 10' new formation. Conduct formation tst to 12.6 ppg EMW. POOH, PU turbine. TIH, drl 8½" hole to 4990'. 3490', 39.5°, NS0.5W, 3340.68 TVD, 559.66 VS, 116.36N, 548.72W 3987', 39.2°, N79.1W, 3725.00 TVD, 874.58 VS, 172.16N, 858.87W 4210', 39.5°, N78.7W, 3897.44 TVD, 1015.79 VS, 199.38N, 997.62W 4727', 38.5°, NS0.5W, 4299.22 TVD, 1340.90 VS, 258.11N, 1317.63W 9-5/8" @ 3209' 6820', (1830'), POOH, Lk'g f/wshout Wt. 9.9, PV 14, YP 9, PH 9.5, WL 9.6, Sol 10 Turbine drl & surv 8½" hole to 6820'. 5290', 37.2°, N82.5W, 4743.78 TVD, 1686.35 VS, 309.17N, 1659.20W 5850', 37.9°, N82.5W, 5187.76 TVD, 2027.62 VS, 353.72N, 1997.66W 6352', 37.9°, N84.SW, 5583.88 TVD, 2335.84 VS, 387.83N, 2304.14W 6726', 36.3°, N84.5W, 5882.18 TVD, 2561.17 VS, 408.86N, 2528.76W EC 'Alaska Oii & Gas Cons. Commission A,.uilu,a§8 The above is correct Signature For form preparation and dlst~utlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inelrucllons: Prepare and submit the "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. Accounting cost center code Dislrict ~County or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWoII no. Kuparuk River ADL 25631 3A-11 Auth. or W.O. no. [Title AFE AK0332 I Drill Parker 141 Operator ARCO Alaska, Inc. Spudded or W,O, begun API 50-029-21458 Spudded Date and depth as of 8:00 a.m. 11116185 thru 11118185 JA.R.Co. W.I. 56.24% Date 11/11/85 Old TD Released rig 1300 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data Complete record for each day reported I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W.O. 0300 hrs. I 7" @ 7342' 7253' PBTD, 7350' TD, RR 10.0 ppg Brine Drl 8½" hole to 7350' TD, 20 std wiper trip, CBU, POH f/logs. RU Schl, rn DIL/GR/SP/SFL f/7337'-3209', FDC/CNL f/7337'-6600', CAL f/7337'-6100'. RD Schl. RIH, make cond'g trip, TOH. RU & rn 169 jts, 7", 26#, J-55 BTC csg w/FS @ 7342', FC @ 7253'. Cmt w/100 sx Cl "G" w/50-50 Healey flyash, .8% D-20, .2% D-46, .5% D-65 & .5% D-112, followed by 400 sx Cl "G" w/l% S-1 & .2% D-46. Displ using rig pmps, bump-pl~ug. CIP @ @ 0900 hrs, 11/17/85. ND BOPE, instl pack-off, NU & wellhead & tst pack-off to 3000 psi. Ri{ @ 1300 hrs, 11/17/85. 7078', 35.1°, N81W, 6168.03 TVD, 2766.55 VS, 434.78N,2732.32W 7310', 34.4°, N71.2W,6358.65 TVD, 2898.12 VS, 466.55N,2860.89W Alaska OiJ & Gas Co.s. ¢o:~,missio. Anchorarje New TD [PB Depth 7350' TD 7253' PBTD Date JKind of rig 11/17/85 Rotary I Type completion (single, dual, etc.) Single 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 Allowable Effective date corrected The above is correct Signature ITitle For form preparation and di~ribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office B~,..~-$00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one si~ned copy of this transmittal. DATE12-19-85 o TRANSMITTAL # 5473 Please acknowledge receipt and Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4// G3-18-85 Run #1 4570.0-9471.0 ~2H-9// 12-02-85 Run #1 1800.0-8113.0 ~2H-10 ~; 11-23-85 Run #1 2856.0-7960.0 '~2H-12 /' 11-07-85 Run #1 2743.0-6829.0 ~2U-7// 03-19-85 Run #1 3594.5-8179.5 ~ 2V- 16/! 06-03-85 Run #1 2973.0-7168.0 ~ 3A-10 H 11-09-85 Run #1 3179.0-7014.0 ~3A- 11/~ 11-16-85 Run #1 3208.0-7330.0 ~ 3A-12;/ 11-23-85 Run #1 3797.0-8006.0 '~3A-13J/ 12-01-85 Run #1 1800.0-7597.0 ~.~3A- 14'/ 12-09-85 Run #1 0144.5-7818.0 3C-9/, 07-10-85 Run #1 3920.0-8332.5 3F-8 ~! 11-09-85 Run #1&2 0115.0-7040.0 ~ 3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ~3F- 10~ 11-27-85 Run #1 1800.0-6631.0 '~ 3F-11 ~ 12-05-85 Run #1 0148.0-8618.5 ~J 3J-9~/ 11-24-85 Run #1&2 0~91.0-6789.0 ~ 3J-10-/ 12-08-85 Run #1 0096.5-7348.5 ref#' ref# 71048 ref# 71002 ref#' 70947 ref# 7095 ~~/~ ~ ~h_ ref# 70952- t"~l~p ref# 70960 ref~ 70989 ref9 71003 ref9 71047 ref9 71073 refg. ref~ ref~ 7~037 ref~ 71061 ref~ 71034 ref~ 7~074 Receipt Acknowledged 'STATE OF ~S~_* 3 -II ARCO Alaska, Inc. Post Office Bo~.,~J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 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 November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED DEC' 1985 OJi & Gas Cons. Commisslot~ Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlantlcRichfieldCompany. .- STATE OF ALASKA ALASKA O~-AN D GAS CONSERVATION COI~ilSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS '1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-238 · 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21458 4. Location of Well atsurface 768' FSL, 813' FEL, Sec.7, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 72' RKBI ADL 25631 ALK 256/+ For the Month of November , 19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well 8 0300 hfs, 11/11/85. Drld 12-1//+" hole to 3229'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7350'TD (11/15/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7253'. Secured well & RR ~ 1300 hrs, 11/17/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 106'. Cmtd w/185 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3209'. Cmtd w/1050 sx AS Iil & 300 sx Class G. Top job performed w/lO0 sx AS I. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7342'. Cmtd w/500 sx Class G & 175 sx AS I. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7337' - 3209' FDC/CNL f/7337' - 6600' Cal f/7337' - 6100' 6. DST data, perforating data, shows of H2S, miscellaneous data None RECE VED Alaska 0ii & Gas Cons. O0mmissi0r~ Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ ~ ~~(-JL, TITLE ^sso¢iate Engineer' DATE //~'t/~-~'' NOTE--Repor~//on this form is required for each calendar month, regardless of the 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 TEMP2/MR68 Submit in duplicate October 10, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-11 ARCO Alaska, Inc. Permit No. 85-238 Sur. Loc. 768'.FSL, 813'FEL, Sec. 7, T12N, R9E, UM. Btmhole Loc. 1226'FSL, 1034'_VWL, Sec. 7, Tt2N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to com~__encing 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, k~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~r~ t r Ut/f~k-~ Br s ~ ~. V. Cha~t~rt0n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conse~gation w/o encl. Mr. Doug L. Lowery 'ARCO Alaska, Inc. Post Office B0'~"'1'00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-11 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk a $100 application fee Diagrams showing the proposed horizontal projections of the wellbore o A proximity plot A diagram and description of the surface system o A diagram and description We estimate spudding this well any questions, please call me Sincerely, Regional Drilling Engineer JBK/jFB/tw PD/L176 Enclosures of the BOP on October at 263-4970. 3A-11, along with and vertical hole diverter equipment 28, 1985. If you have RECEIVED OCT o Alaska Oil &A Gas Cons, Commissior~ nchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA 0'TL AND GAS CONSERVATION C0)v-'K'MISSION PERMIT TO DRILL DRILL l-~X REDRILL [] DEEPEN [] 20 AAC 25.005 SERVICE [] ST R AT~~ ~,,L_~ SINGLE ZONE ~ MULTIPLE ZONE "~ lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~t[X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 768' FSL, 813' FEL, Sec.7, T12N, RgE, UN At top of proposed producing interval 1194' FSL, 1242' FWL, Sec.7, T12N, RgE, UN At total depth 1226' FSL, 1034' FWL, Sec.7, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designatior~ and serial no. RKB 72', PAD 41' ADL 256]1~ ALK 25~ 12. Bond information (see 20 AAC 25.025) 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-11 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Federal Insurance Company Type Statewt de Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mt, NW of Deadhorse miles 1034' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7335' MD, 6333' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 1949 feet. MAXIMUM HOLE ANGLE 39 o (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 3A-lOwell 25' @ surface feet 18. Approximate spud date 10/28/85 psig@ ROoF Surface . psig@ 607! ft. TD (TVD) 21 Pr( SIZE CASING AND LINER SE~ING DEPTH QUANTITY OF CEMENT Hole Casing Weigh~ Grade Coupling Length MD TOP TVD MD BOTTOM TVD {include stage data} 26" 16" 62.5~ H-~O We]d 80' 32' I 32' 112~ 112' * 200 cf 12-1/~" 9-5/8" 36.0~ 1-55/HF-EI ~W BTC 3212' 32~ I . ' I 32' 32~ 31~7' 720 sx AS III & ~ ,I 300 sx Class G 8-1/2" 7" 26.~ ,~-55/HF-E~',W BTC 730~~ 31~ ~ 31~ ~ 73351 6333~ 300 sx Class G ' ] I I ~ i~ I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7335' MD (6333' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2692 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing.the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A-11 will be 25' away from 3A-10 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cer/t,~that the foregoing is true and correct to the best of my knowledge // The spac,~w 'f~r~o~q/mi/~o~uuse ]"-- - CONDITIONS OF APPROVAL Samples required Mud log required E]YES E}NO E]YES [-}NO Permit number APPROVED BY/ Form 10401, ~' P6/PDI~'6 Approval date 0/8,¢ DATE Directional Survey required I APl number t--lYES I-]NO I 50- 029-21458 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 1 0, ]_985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3A-11 (cont'd) Upon completion of the disposal processs the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing, Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off loeation~ this well will be fracture stimulated. RECEIVED OCT 0 a OJJ & Gas Cons. Commission Anchorage :: KUPARU_K___' F_tELD,.~_.N.ORT. H'__SLO_PE: ~'ALA_SKA__-~ ..... L/' '~'__~,,_~.~_2.._L~: , ..... . ............. L - - . ..._ · ..... . ....... ~ ._.: _ _ ~ ...... = ..... _ . . ................................................ . ............... . ....... : . · _! ....... ._i---1000.~ . ......... . _ 4~ . _ i.-__ ......... BASE PER.AFROST -- TVD= 1552:----i~ .... .-- -:- ..........~ .......~ ~2'' - ' .... i .... : ....... 2.2___2000... _. 'KOPi TVD=i949 THD'"1949 DEP=o :5--; Ti; ~ --i _z. i_i~-_ . ' i . :-L;_:'~ _ 3 TOP UOHU SHDS TVD-1992. THD~1992 DEP"O ...... ......... 9 -8U!LD :3 DEG ....... ----~ s ............ p£_R.._! 0_0._ F_r ::o ..... 2~ TOP W SAK SNDS TVD=2662_-'THD=2680:DEP=l~38 '~: ~:-~-': :~-:_-:::--:}i;:-:;:L---;'T C -- ' ........ ' ........ ' ........... rn - __K, 1.2. .... _T._V.D.=.29_4'._?_L.T. HP_=_.2.9_99.'. DE.P=282_~.: ........ : ........... -/.:_:.: < ...... EOC__ ___ ___ ___~:O'5/~"'CSC~-PT) ........... - ........ - ~- --?- - ~-- ~ - _. _ . · 33 . . TVD":31 47' THD=B244'-DEP~422-':--' :'T.5:' "-:-:_L._:. :'"-.:--_:: "~1 ....... '- £ .... :- ' .......: 0 ' : ,-- :AVERAOE ANGLE : _ . -RECEIVED .................. 3S--DEG-51- FII N '" OCT_O ' 3:: . .............. K.5 TVD=_44.B7 :THD=4'O65:_DEP=l Alaska. .... '. . . _ . . . ..... :- . . .:.' ........ · .... · .:-___ '_ - . ' ..... ' - ---Anchora~: ::. .......... ~' .......... 5000 ................................ . _ .... ..... ........ ...... ....... . ...... . ..... : ..... ....... .._: ............. ..... ................ .... ! - . . .... ~ -- . _. ~ ............ : ............... : ....... --- . - ' , ...... : '-T/ZONE--D TVD=S967 rt'lD=6865 DEP=2694 .... 61 .................. - ~'. ' - '__..Li_..T_/ZONE.CL..TVD=SOZ2 THD=6871 ..... ......... ', T/ZONE A- - TVD=60?I THD=6998 DEP,-2778 --._ .... nn t ...... .. '. - ...... : --- ~~_ ............ ',~-- -TAROET- ...... CNTR ..... ' TVD,,61. 24 ................. THD,,7067~__ ' · ~ ..... ' ...... BASE--KUP-SHDS TVD--61?? T~D~?I ...... :.- ......... .- -. ......:-- ID:-I:L. oo:PI1L-TVD=6~3 THD=Z335 · ....... ; ....... ! ___ ~- :- ....... - ....... ....... ............ i ........................ 7_ o,- ..... , ;---: "---;;-:::::-:: · . ._ . .~ . - . _ : .... ":T 'O ...... 1000 -. .2000::'-:'-':: -' $000' :::---:---_:: :-" ...................... .......____ __:__-- ~_______~ ~_.* - .. :. _ ~- . ~_ .... : ..................... ............................. V.~.T ~'~..,-'-.~F~.~ ~n. .......... - .............. · ...................................... ...... ~ ..... ;. ....... ~- ............................. --. :-' T .... i ............ :-: ...... : .................... ......... : ' -: ..........': - ........ i .......... ..... ; ........... : _ ~_. ..... _. .......... ;_ ._ - _ _ . · . ............... , ................. ..... - . :- . : .... 20CC 1000 _ I . I 000 _ , , HOR ~ ZONT AL PROJECT ~[ ON . , SCALE I' !N.';, 1000 FEET PAD 3A, WELL NO~'il. KUPARUK FIELD. NORTH · EASTMAN WHIPSTOCK iNC. ~ · . :. :_.,t . . ; -. 'WEST-~EAST 4000 ;3000 ' 2000' I · I , ; , * , I , ' TARGET CENTER ?VD-6! 24 .............. #ORI'H 4~2 ! WEST 2~, 87' TARGET LOCATIO# ~ '' 1200' FSL, 1200, FWL SEC. ?. TI2#. RGE ' i , · '~ ,, i ~ ., . '~ .......~" 'r '° ' ' " ,N ~1 DEO 2820' (TO TARGET) ~ ) SURF,~c~ SURFACE LOCATION, ?68, FSL. 813' FEL SEC ..?....TI2#.. RgE r ' ' I 100- 000 - 00. . 1200 I 1 ! O0 1 000 I I 900 I 800 - 700 600 500 · I ' I I I ARCO' 'ALASKA. INC. PAD 3A. WELL NO, !0-11-12 KUPARUK FIELD, NORTH SLOPE. PROPOSED ALASKA EASTHAN WHIPSTOCK. INC. I NOTE, ~ i WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 400 3oo - % - . , ;00 _ I - 1200 I iloo ~000 900 800 7'00 q 600 , 500. ! lO0 i '~ 300 , KUPARUK IRI VER UNIT 20" .DI VEDTER SCHEMAT I C DE SCR I PT I ON 1. 16' CC~:)UCTOR. 2. TAI~O STARTER HEAD. .'5. TANKO SAVER SUB. 4, TANKO LOY~ER QUICK-C~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSYo 6. 20' 2000 PSI DRILLING SPOOl_ Vi/I 0" OUTLETS. '7. !0" NCR BALL VALVES Vi/lO' DIVERTER LINES. VALVES OPEN AUTOMATICALLY UPON CLOSURE OF Ah,NJL. AR PREVENTER. 8. 20' 2000 PSI At,~LAR PREVENTER. RECEIVED IVIAZINTENANCE & OPERATION i. UP'-ON INITIAL ]NSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES -- HAVE- OPENED PROPERLY, 2. CLOSE Aha',IULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY I2 HOURS. 5 CLOSE Ah~NULAR PREVENTER IN THE EVENT' '"" "'" '' ~m~f AN IhFLUX OF FLUIDS OR GAS IS DETECTED. IF -.. NECESSARY, MANtJALLY OVERRIDE AN~ . CLOSE APPROPRI ATE VALVE TO ACHIEVE DO~NWlND DIVERSION. DO NOT SHUT IN V,~LL AlasKa Oil & 6as Cons. 6ommission . Anchorags UNDER ANY CIRCUMSTANCES. 7 DIAGRA/vl #1 13-5/8"-~-~ PSI RSRRA BOP STACK i. 16' - 2000 PSI TAhI<CO STARTING HF_AD 2. I1' - 3000 PSI ~A,SIN~ ~.AD 3. I1' - 3000 PSI X 1~5/8' - SOX) PS! SPACE~ SI=OOL 4. 13-5/8' - ~ PSI PIPE RANE; 5. 13--5/8' - 5000 PSI DRZLLZNO SPOOL Vi/OK:DOE: AhD KZLL LZhF_S 6. 13---5/8' - 5000 PSI ~ RAM W/PIPE R. NV~ (:DJ TOP. ?. 13--5/8' - 5000 PSI AhAt.I.AR < <. ,J 6 5 mm l 4 3 2 ACCLNULATCR CAPACITY TEST 1. C~ AND FILL AC~TCR RES~OIR TO P~ LEVEL WITH HYDRALI_IC FLUID.' A~ THAT AC~TOR P~ IS ~5OC~ PSI WITH 3. (]~ERVE TItw~o ~ CLOSE ALL ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~T~ L~ LIMIT IS 45 ~~ ~I~ T~ ~ i~ ~I ~I~ CEIVED 13-5/8" BOP STACK TEST I. FILL ~C~ STACK AID CHC~ I~IFCI_D ~?ITH ARCTIC DIESEL. C~C~ THAT ALL LCX~ DO/QN SC~ IN ~E]_LFF_AD ARE F-LN_LY RETRACTED. SEAT TEST PLUG IN ~%LJ-F_AD WITH RUNNINO J'r AhD RUIN IN LOC~ SC~. LIhE VALVES ADJACENT TO BO::: STACX. ALL 0TI..ER 4. PRESSIJRE UP TO ~ PSI AhD HOD FOR I0 MIN. IN.- CREASE PEE~ TO 5000 PSI AhD HOLD FOR I0 MIN. BLr'rr) I::~E~ TO 0 PSI. 5. C~~ ~ A~M, AI~AL KILL AhD C~ LIhE VALVES. CLOSE TOP PIPE R/~ AhD h4SR VALVES CD4 KILL AhD CHOKE LIhES. 6. TEST TO 250 PSI AhD 30C~) PSI AS IN STEP 7. C~IhL~ TESTIh~3 ALL VALVES, LIhF_So AhD C~S WITH A P_SO PSI LC~ AhD 3C~ PSI HIGH. TEST AS IN STEP 4. DO F/3T F:~~ 'r~ST ~ C~ THAT Lx~rr A FULL CLOSINO POSITIVE SEAL C~. C~Y FI~IC~J TFET (~$ THAT DO NIDT FULLY CLOSE. C~ TOP PIPE R/~ AhD CLOSE BOTTCM PIPE P~. '~ST BOTTCI~ PIPE P,~ TO 250 PSI AID 3000 PSI. OPEN BOTTC~ PIPE P,/~, BACK 0LFF RU~IN~ dT AhD CLOSE BLIhD RA~ AhD TEST TO 2.90 PSI AhD 3000 'PSI', - - '~NIFO.~ AhZ) LI~S A~S FULL CF FLUID. SET ALL VALVES IN DRILLIh~ POSITICt~L 12. TEST STAhDPIPE VALVES, KELLY, K~qLI Y C~So DRILL PIPE SAFETY VALVE, A~) INSID~ ~P TO ~ PSI 3OOO PSI. 13. REC~ TEST INFO--TIC/4 C~ BL~VIOJT PREVENqg~ TEST FC~, SIGN, AhD S~ TO DRILLIh~ SUPERVI~. 14. PERFC~ CI]V~E BC~ TEST /~ NIPPLIN0 UP AhD V~Y TF~ER F-U~ICNALLY Cl:~'r~ BCI:~ DAILY. Alasi(a Oil & Gas Cons. Commission . Anchor8.~9 5100~4001 REV. 2 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 3A Pad Wel 1 s 1-16 Dear Mr. Chatterton- 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 GRU11/L22 Enclosure If RECEIVED AUG ) 0 1005 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRichfleldCompany · 7 8 k. F NOTES ; C..;CRD~NATZS ~RE A.S.P, ZONE 4 2. SECTION ~_,NE DISTANCES ARE TRUE. '5. HOR!ZONTAL POSITIONS BASEDCN THE D.S.-3A WEST & 3AMID PER LHD ~ ASSOC. 4. VERTICAL POSITION BASED CN 3A EAST & 3A MID PER LHD 1~ ASSOC. 5,O.G, ELEVATIONS iNTERPOLATED FROM S/C D~/G. CED- RIXX- 3020 rev. ~ --~¢ oF ,4/.., t. ar/%' ..' L "% 'I,.~ 8j j~r :~ ..__ e~4eeee ee · .... . · ~:..~..'.., ....~ HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND L~SCENSED TO PRACTICE LAND SURVEYING IN THE 9TATE OF ALASKA, THAT TH~S ~LAT REPRESENTS A SURVEY MADE ~JNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14~1985 AS BUILT'--.._,. CONDUCTORS I- 16 l- Y=5,gg6,860.05 S07.712.0! ~78' FSL, 736t 2- Y=5,Og6,884.I7 X= 507,705.57 503' FSL, 3- Y=5,996,908.32 X= 507,699.06 tAT= 70°2~'09.520'' LONG, 1~,9°56'[~,020'' FEL, 36.80G, c0.8 PAD LAT= 70°7~t 09.758' LONG= 159°56 !4.207' FEL, 36.80G, ~0.9 PaD LAT= 70o2~09.~95'' LONG= t~g°56 527' ;SL, 7~9'FEL, 36.7 OG, ~+0.8 PAD 4- Y=5,996,932.72 LAT= 70°24' 10.235'' X= 507,692.55 LONG= 149°56 1~.58'/" 551' FSL, 756' FEL, 36.70G, 40.8 5- (=5,gg6,956.61 LAT= 70°2~'10.~70'' X= 507,686.21 LONG= 1~g°56 1~.773" 575'FSL, 762'~EL, 36.5 OG, 40.g P~D 6- Y=5,gg6,gSO.8~ LAT= 70°2~'10.70g" X= 507,67g.66 LONG= 1~g°56 1~.g63" 5go FSL, 768' FEL, 36.50G ~0.8 PAD 7- Y=5,gg7,00~.go LAT= 70°2~ 10.9q5' X= 507,673.26 LONG= [~9°56 15.t5[ 623 FSL, 774'FEL, 36.50G, ~ . 1 8- Y=5,997,029.03 LAT= 70°2~ I .193 X= 507,666.81 LONG= 1~9°56 15.33~" §~7 FSL, 781~ FEL, 36.~ OG 60.9 9- Y=5,997,101.2~ LAT= 70°24 11.893' X= 507,647.70 LONG= 1~9°56'15.896' 720 FSL, 800' FEL, 36.30G 41.7 PAP 10- Y=5,997,125.66 X= 5u ,6~0.89 /~6 elL, 806~ 11- Y=5,997,1~9.84 X= 507,63~.~ 768 FSL, 813~ 12- Y~5,g97,I73.97 X: 507,§27,96 792 FSL, 819~ 13- Y=5,gg7,198.08 X= 507,6Z1.~8 817 FSL, 825' 14- ¥=5,997,222.29 X= 507,615.01 LAT= 70°2~ ~2.13~" LONG= 149°56'16.095'' FEL, 36.3 OG ~1.6 PAD LAT= 70°2~ 12 371' LONG: 1~9°56~ 6.283" FEL, 36.2 OG ~ PAD LAT= 70o2~ 12 LONG= 1~g°56' FEL, 36.10G, ~ LAT= 70°2~' !2 LONG= 1~g°56' FEL, 36.0. 0G, ~ LAT= 70°2~'!3 LONG: 1A9°5~' 841 FSL, 832' FEL, 35.8 OG, , 15- Y=5,g97,2~,6.~,4 LAT= 70°2A,' 13 322" '5~ FSL, 838~ FEL 35.6 OG ~ :(= se* bO2 1 ONG I~9°55' ]Gas Cons. Commis~'A' ; ] ~ ~ ~ E L ] 5 5 9 ,~, 9, mchorage m Kup~ruk Pro~ect CONDUCTOR AS- BUILT LOCATIONS Drefted by:~ Dwi. no.: NSK 85- CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc ,,,, ....... ,. f~> '(2 thru 8) (3) Admin ....... ('9 thru..l 2) (10 and 12) (13 thru 21) (5) BOPE~~.~./~ ('2-2 thru 26)- le . 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27¸. YES NO Is the permit fee attached ......................................... Is well to be located in a defined pool ......................... Is well located proper distance from property line .. · e . . e. Is well located proper distance from other wells ............... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore .p~.a~ Is operator the only affected party ................... Can permit be approved before ten-day wait ........................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ...................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, 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 ~O~g) psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ........ , ......................... Additional requirements ............................................. REMARKS Additional Remarks: Geology: Eng~n.~er lng: ,,cs WVA~:~/~ MTM ~ HJH rev: 03/13/85 6.011 IN ITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infOrmation, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically '. .. organize this category of information. bis T A F.'~ ~ ** TAPE HF:Ai.')E',R ** SERVICM NA,HE DhTE :85/12/13 TAPE ¢; A ~E :0989 C[]~TI~UATIOk~ ~ :01 P~EVIOUS ?~PE : C [) ~ ~'~ Et~,{ T S :L,I~RARY ** FILE HE~OER FIGE ~,i.A M E :EDI[ .OO! VERSION ~ : D A T E : FIBE TYPE PREVIOUS FI}~E ** '[NFOR~,,~ATION' REC[)RD$ ** PRES: UNIT TYPE .¢ ~ C &"~'E SI ZE CODE 000 000 030 065 000 O00 030 065 000 000 Olb 065 000 000 00 2 065 000 000 004 065 nO0 000 002 065 000 000 0:! 0 065 000 000 010 065 000 000 004, 0 ~55 U~IT TYPE CATE SIZE CODE 00 () 0 00 (.) 0 ! 06 5 TYPE FLUID FLUID q A[i.'R I X SA~OSTONE * AI3~SK~. CO~,~PLiTING CEiq'I'KR ************************************************************************************* CO~P,~N~' : ARCO ALASKA 't,'~C WELL = B~-I ~ S".~ AT E = ~LhSi<~ 008 ~I~','~FR AT ACC: 70989 RUN ~O~E, D~TE Lr]GGE!): 16-~0V-85 = 9,625" [~ 3209,0' - BIT SIZE = WEIGHTED POLY~{~.':R = 9,90 bB/G R~ = 3,890 = .36.0 ,S R~F 4,530 {a 67:0 DF = 9,5 ~{C = 205~0 ~ 67'0 D~~ : 9.6 C:.{ RM AT ~HT = :1.945 {a 141, DF T[.-~IS OATA F!A$ ~OT 8EE:J'..~ i~EPTH SBIFTEt) - OVERLAYS FZELD PR][I'~']:'S I' ECEIV[D [j V P 010. J-i (.? 2 v E R I ~'" I.'. C ,~ T' ~.' U t',~ L I S ".I' T ~,,~ ,".:; P A G E 3 , · $ C J.i [., iJ ~ ,':~ E t-;. G & P LOGS , :'J.: DA',CA AV.~].I.j~ELi";: 7330.0' T6 320B,0' · F(!~:~;ATI!')h, I)ES!SI'FY CO,~PENSATED LOG (FDN) * · DATA .~\,'AIL, ABLEI: 7200,0' TO 6600.0' * , Alaska uii a Gas Cons. 6ommissiQ~._ ~ Anchorag~ ,. ......... b V P 010. t4 S ? V E R 1 F i (77 t', "I' 1' Ii r,J 'I: I S T I ;h ('j P A G E: 4 LiHi'I' AP1 APl AP1 APl FILE SIZE SPL RE, PN I,t.?G TYPE C[,~SS hlOD NO. CODP~ K I' 00 0 00 00 0 0 ,i 1 6 O ~! ~,~,'~ O0 220 O1 0 0 4 1 6 O q ~,,~,,' O0 t20 44 0 0 4 1 68 t,~ 00 010 01 0 0 ~ I 6B GAPi O0 3!0 O1 0 0 4 1. 68 (;API O0 310 C1 0 0 4 I 6B I ~ 00 280 01 0 0 4 1 68 G/C3 O0 t50 02 0 0 4 I 68 G/C3 O0 356 01 fl 0 4 1 68 00 ~20 01 0 0 ~ 1 68 PU OO 890 O0 0 0 4 I 68 P ROCi".:$$ C~ ,.-., . b) ti 0000000000o000 8 o0o00000000000 8 O0000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 000000000u0000 ** DATA ** DEPT 7364,.5000 SFbd SP ,,61.6758 GR RNOB -q99,2500 DRH(3 DEPT 7~OO 0000 SP -65:1.602 GR' RUDB -999,2500 ORH[) {.)klPT 7200. OOOO SP -76; o 352 GR R~[]8 2 4469 !.)RH S P 5977 G k R b~ [) B 2 ' 3 '880 D , ,, ~ , D E P '[ "1 U o o. 0000 S P ' 63,30 o 8G RHOB 2,3u22 DR. ,)0(,0 SFt,U L)E'.PT b O0,q, -,- . S P 74 .....7 z ? G RIIOB 2,3962 LE, 6800 O0()0 SFLt., SP -7~'5362 OEPT 6700 n00() ='" SP 7'~ ' - .7227 G R H U B .. 3 633 D g P '[' 66 () 0.9 o o o SP -76,7227 R H O F~, 2, ,,~ 3,3 u D 2,271'7 IhD 2 7424 Ib~ 2, 110.1523 GR -999".2500 CAL, I -999, -999.2500 h~RA'T ,-999' 2500 NP~I -999, 2.0t20 l bi]:> 1,9600 Ib~, 96,2773 GR 999 2500 .' Q . : 9= 9 2500 NRAT 999.2500 4 79'76 I.[.~D 4,9 .1.05'4..023 O ' 0473 1523 aR 10 192b0 1, [., ~ 0579 CILI' 1'10'0255 NRAT 3.4450 l'~t?a 1 :i 3.~660 LbO 9,85'35 IbM 97, 773 GR T 86.8572 CAL, I 0.0084 NRA 2.7258 ~PHI 5,3992 IL.O ~, 7546 Ib 102,5273 f;R 92,1.5.32 CAI..,... 0.0 098 b R A '!.' ,2.9 g 32 i?,~ P ~ .t 2,2854 ILD 1,5215 1o8.3398 GR li. 2,8g75 CAL, I O. 0460 NRAT 3. 7993 .NPHI 2 ,, 0549 1 t5 D 2,0862 I h i~q 11.8 652.3 Ga 1:18.5748 CA[.,I o, () 373 ~ a A T 3,72 56 t,,~ p H I 3967 IBM,. 0g 74 ri A .., I 6 f~ 7 7 m P H 1: i , 999, :999, t2. 2~ 41. 4~ 8, 33, }: 2~ 9, ,4:2 , IS'IV 2500 2500 913 5OO 2500 9109 b6~2 8097 9709 8593 4465 3223 5780 2870 8'718 8427 2504 0212 6897 2545 1077 2939 5334 4729 9236 2479 gFu:ska. Oil & Gas Cons,, Com?,issio::~ Pa,cb?,r'a~e SP -6H, 472'! GR R ~-!O~ -999.2500 OEPT 6400 0000 $ P - ~ 9: b 9 ? 7 RHOb' -999~ 2500 DgPT 6200. O00n SFbl~ SP -90 66(,)2 gk R !t 0 ~! 9 99 ' " It - : 25(...0 D HI.! O g P I: 6100,00 (`) 0 ,:q F b !J SP '"'96.6602 GR R ~. O B - 5.:, 99.250 ~") D R E 0 DKPT 6000. 000O SP -9,t 09'17 R*40B -9~9: 7500 DKPT 5900, OOO0 SP -105,8477 R H [} B - 9 99. ?. 500 DEBT 5800. o000 SFI,0 SP 103,7227 GR R H [) E~ ; 999,2500 O R H ;'~ O g P T 5700.00 t; 0oe ~. L, t.} SP 103. ~477 Gk D E P T 5 b 0 O, 00/l 0 $ F I., u SP -74,9727 GR. DEPT 5.40t:) · ,)0oo S F'I., iJ SP 22 3389 !3 E P T 5300, 00 t) O S F [, SP '730,2920 GR R ~-,~ t:)I? - ¢0 q 9.25 O 0 I:,') I:e !- ,[t D K P T 5200. (.) (:) t) 0 S F t.., ~l 1., 777_ 5 I L L) 3~ 2.39(.)o GR -9q~4 25~)0 ;,)RAT 4.0 (') 46 I I~f') 128.~1.2.5 GR -909.2500 NR~.T 4[.. 032 ") I L O 113,2148 GF,'. -999.2500 I.l R ,~'P 2.0979 :.l' L 0 164, 31.'} · ,~,5 gi"i T -999:25(}0 NPA 3.0979 1.01.4048 GR -999' 2500 r.~RAT 4 50 (') 7 1 L D 119' ,6523 GR -999. 2500 tSRAT 4.0905 i b D 97,089 P,, GR - ~ 99.2500 I:,? R A T 14,53 II,.D 4023 fl; R 2500 bRAq' 3. ~ 182 I [., D 104, 2148 GR -999"2500 NR.AT 3.6389 I .b D ':)8. 9023 GR - 999. ,,'2, 500 F; R A '1: 3.20. 2 Ir,l) 110 2'173 -909:2500 ~RAT 2.7737 ILO 119,5898 2 5 (. 0 N R A ~ 3,1663 'I l., D 117,8398 GR -999.2,.~0(, NRAq' 3 , 6077 I L D I .7999 2999 2bO0 999: 2500 3 5295 99 9.500 3.7190 -999.2500 -999.2500 2.3]62 -999.2500 -999.2500 3.2932 -999,2500 -999,2500 5,0~67 :999,25oo 999.2500 3,7991 2999.2500 999.25o0 4,332~ -999,25ou -999. 2500 3,5374 -999, ~50u -999. 50O 3.8987 -999.2500 '909.250o 3987 -999.2 5Ur -999.25O0 2,9436 -999,250() -999.i 506 2 , 8792 -999,:~500 -999. 50o 3.7249 CAL. i CabI ~PHI CALl NPHI I' L~~ CALl C~bI ~ P H I I. L, h CALl N P i-i I CALl NPHI I CALl N P H I C A b I N p H l :[ 'b M C,AbI ~9 P H I 1'. b M CALl CALl C 1,7I;91 -999,2500 -999,2500 3.5354 -999,2500 -999.250t) 3.7346 -999.2500 -909,2.5.00 2.3245 -999. 2500 -999,2500 3,2737 -,999,2500 999.2500 4.8445 '999,2500 -999. 2500 4,0398 '999,2500 -999. ,9.500 4,3250 -999,2500 -999.25o() .3,51. 39 · ,999,2500 -999,250(') 3,8538 2 oo 999.2 O0 3,353~ -999 2500 999'2500 , 2.88:11 -999,2500 '999. 250() 2 , 8069 '999,2500 -999.2500 3. 6096 [-'.i ', L..':.,;: . ':, lb V P 0 ~ ¢), t. i 02 V !::: iR I F' .l C..A T 1 :.'3 ',? b I S T T. ~,! G P A d F: 6 SP -,52,488 J DEPT 510() 0000 SP -41,550~ R H r) ~. - 9 ~ 9.2509 D ~P -25,3857 RHOB -999,2500 SP 33 ~ ~, 4A b R~{}[~ -~99,75o0 DR[tO 9EPT 4890,0000 SFLU SP -30.6045 GR RNOB -999.2500 OEPT 4700. 0000 SFI.,U $p -30,5~9 GR REOB -999,2509 D E P T 4600,000 (.) S P - 35,80 (..) ~ G R RNOB - 999,2500 DEPT 4500, O0ot) SFLU SP -3~,61.33 RP08 -999.25u~) OEPT 440o, 0000 SFLU 5 ~ 20 G SP -35,250~ ~3 F,P..T 4 3 O0, () 000 o"' IF I, t.~ $ P ' 37. ] u o 8 g 0 E P T 420 r), 00 O 0 S F L, SD -47,0508 R ['~ 0 B - 999. ? S () 0 D g P T 41 {.10.00 n r~ $ F 1.., U SP -46.1,$45 G R l:l 0 b - 999, '25 t.) o D E P T .4000, ~ 0 t) 0 SP -42. 332o DEPT 39()0,0000 SF'f, SP -43,80t~8 G 144 0625 GR - 99:2.5oo 4.1.14t) ILD 1'10 8i25 GR -999:2500 t!R_h T 2.0823 tfJD 156.8125 GR -999.2500 3.945L 162.3125 GR - 99 t}. 2 b 00 !,,t R a T 2.5174 134.3125 GR -999.25{)0 !',i R A T !. 4.581 1,~6 8398 GR 9 9~ 25 )0 - . '('' '.1' 2,2620 I21.9648 (.iR -9q9. 250(.) 2,3694 I '14,27'13 GR - q 99.2 '500 ~ R'A T 2.6819 11.6,9023 GR - 999.2500 ~':: [-;' A T 2.980 "? 'I L D 1 o 3.1523 G R -999.2500 ~'~RAT 2.840,1. :I. t,[~ 81 3398 GR -999' 2500 "t'RAT 2 o 9 t=i 'l 2 I '[~ D IF] ?, 2 .L 48 g R - 999.25 {'510 N. R q T 2,/$ 3 38 I. L,. D ~ 6 (} 27 3 G R - 999 ' 2500 3,2952 1 1.11.0273 GR "999.~500 NRAT 999 2500 -'999: 2500 3.7913 -999. 2500 -g99,2500 1.8399 -o99.,,. 2500 -999.2500 2 6057 - 99!2500 -~99 2500 2.0354 :~99,250o 999°250o ! 9551 -999! 25OO -999 2500 2 41.82 -999: 2500 -999~" 2500 2.7678 -999.2500 -999o2500 ~.9045 .,999 ' '" '~ 250( 2soo 3. 3694 -999. ~ "UO -99g, ~00 3.3~,,99 -999. 2500 3.0784 -999.250() -999. 2500 2,7385 -999, 3,6604 -99~ ,. 2F, O0 -99 2500 CAbI I !: ,k CAL, 1 f,~ P H I CALl NPH! IL,~~, Ca. bl N P H i 1 CAL, 1 NPHI lb~ CAhI I b M CAbI NPHI CALl NPHI CAbl Cabl I b M C ,~ b I N P H I CILI NPHI C A b I l',J P N I CALl N P H ,l -999.2500 -999.2500 3,842~ -999,2500 -999.2500 ~.8682 -999,2500 -999.2500 2.6858 -999,2500 -999.2500 2.090~ -999,2500 -999.2500 1.873! -999,2500 -999,2500 2,3616 -999,2500 -999.2500 2,6F97 -999,250() -999.2500 2,851,8 -999,2500 '999,25U0 3,2932 - 99..2500 ~99,2500 · -999,25)0 -999.2500 2,9924 'g99,2500 -999,2500 2,6233 -999,2500 -999,2500 3.4963 -999,2500 -999.2500 L\,'P 01o 1402 VE:RIFI, C!xTILi" .... . 3~0045,.8320a0()0 -q99,9.50{.) ~ ~.! LI R - 999,2 '500 !.'., k H C D E P'_i? 3~00,9'~)OG SFl,d SP -47,1133 Gi{ RglOb -999.2500 DPt!r3 ..9 ~3 P T 3500,9000 SPbi] $? -45,3320 G~ RHO[~, -999.2500 L)R i~[] DE:P"', ~ 3400,0000.. $? -50.050a G~ R !i 0 ~ - 999,2 $ 0 u D R ~-! 0 . SF DEPT 3300. OOU:) ' SP -52.8320 R H 0 R - q 9 g. 25 () 0 O ¢~' H 0 DEPT 3200. OhO0 SH'LU SP '19,2607 GR RHOB -999,2500 DRHO P'[DE t",I A F4 E :EuI SERvlCF: NA~,~E V~:R SION ~ : DATE : NEXT PILE NAMe? : 2. '7 C, 92 I09.1523 Ga -999. 2500 3.79'7 1. ILO 94.7773 Ge -99~. 2500 ~,~ R ~ T ,!. ~ 61 '7 I b b 08 3398 GR -t309~2500 hJRAT 3. 6350 ~7.8398 GR -999.2~00 4.3015 82,5898 -999.2500 5. 1296 85 0273 GRAT -9'99~2500 17130 IT,D 56:7305 GR -999.2500 1,7100 50.bu55 Ga -999. 2500 .091 10 2,4,, 2.3381 -999.2500 -999.2500 3,9651 -999.2500 -999.2500 2.8108 -99g 2500 -999~2500 3,5784 '999 2500 -999~2500 4,9578 :999,2500 g99,2500 5,3835 :999 2500 999:2500 7,0242 -999,2500 -g99.2500 10.5:]32 -999,2500 -999,250O l L!~,', CAI.,][ !'; p I-t l NPHI CALl. CAbI NPHi I b C~bI CAb I NPHI CAl,.,l NPttI CA bi NPHI 2.41.2¢ -999.2500 -999,2500 3,5979 -999.2500 -999.2500 2.5002 -g99,2500 -999,2500 3,4202 -999,2500 -999.2500 4,~609 -999,2500 -999,2500 5,1765 -999.2500 -999,2500 200U.6875 999,2500 :999.250(1 2(')00,~875 -999,2500 -999.2500 TAPE TRAI[~ER ** SF:RVlCt); NA~'~E :EDTT D~T~] :R5t12/13 E ~',~AME 10989 i~JXT TAPE t'~'~H; : COix~'~fEI',tTS :OI'.~RARY 2"APE