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Home My WebLink About184-159CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF2 Subject:10-426 forms for Witnessed & non-witnessed MIT-IA"s on 2D-pad 8/8/25 Date:Saturday, August 9, 2025 8:38:05 AM Attachments:image001.png MIT KRU 2D PAD 08-08-25.xlsx MIT KRU 2D-11 and 2D-14 SI TESTS 08-08-25.xlsx Morning, Please see the attached 10-426 forms from the AOGCC witnessed and non-witnessed MIT-IA’s on 2D-pad that were performed on 8-8-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58' 37' OPERATOR:FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1840990 Type Inj N Tubing 1425 1425 1425 1425 Type T 5878 BBL Pump 1.6 IA 340 2200 2145 2130 Interv 1500 BBL Return 1.3 OA 130 130 130 130 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1841590 Type Inj N Tubing 1625 1625 1625 1625 Type T 5825 BBL Pump 1.7 IA 440 2400 2340 2340 Interv 1500 BBL Return 1.7 OA 20 20 20 20 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu TYPE TEST Codes INTERVAL Codes Result Codes 2D-11 2D-14 p, Kuparuk / KRU / 2D Pad Borge/Kirk 08/08/25 9 9 9 9 999 9 9 9 9 -5HJJ 2D-14 MEMORANDUM TO: Jim Regg 2 q j 3/-7c%Z\ P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT 2D-14 Insp Num: mitMFH210818071458 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 20, 2021 SUBJECT: Mechanical Integgrity Tests ConocoPhiIlips Alaska, Inc. 2D-14 KUPARUK RIV UNIT 2D-14 Src: Inspector Reviewed By: P.I. Supry ti}� Comm API Well Number 50-029-21183-00-00 Inspector Name: Matt Herrera Permit Number: 184-159-0 Inspection Date: 8/14/2021 Initial 15 Min 30 Min 45 Min 60 Min 1420- 1420 — 1420 - 2210 2145 2135 245 245 245 Friday, August 20, 2021 Page 1 of I Packer Depth Pretest Well 213-14 Type lnj W -'TVD 5825 - Tubing 1415 - PTD 1841590 Type Test SPT' Test psi 1500 IA 470 I3I3L Pumped: 2.5 ' BBL Returned: 24 OA 195 •. Interval 4vRTST P/F p Notes: MITI -IA Performed to 2200 PSI Per Operations , Initial 15 Min 30 Min 45 Min 60 Min 1420- 1420 — 1420 - 2210 2145 2135 245 245 245 Friday, August 20, 2021 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 10,2017 TO: Jim Regg 2 P.I.Supervisor ert )12./// 1f 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2D-14 FROM: Chuck Scheve KUPARUK RIV UNIT 2D-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2D-14 API Well Number 50-029-21183-00-00 Inspector Name: Chuck Scheve Permit Number: 184-159-0 Inspection Date: 8/7/2017 - Insp Num: mitCSl70808074104 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2D-I4 ;Type Inj W iTVD 5825 Tubing 2280 2280 2280 2280 -PTD 1841590 - 1Type Test SPT Test psi 1500 IA 840 3050 ' 3010 3010 BBL Pumped: 2 BBL Returned: 2 OA 530 - 730 730 730 Interval 4YRTST P/F P Notes: SCANNED i i E , 2 Thursday,August 10,2017 Page 1 of 1 is.c. ( s9 REC;LIVED • • APR 0 5 2016 WELL LOG TRANSMITTAL# AOGC.0 To: Alaska Oil and Gas Conservation Comm. March 31, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED l{/-2/2O1C Anchorage, Alaska 99501 M.K. BENDER SCANNED RE: Injection Profile : 2D-14 Run Date: 1/28/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2D-14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21183-00 Injection Profile Log 1 Color Log 50-029-21183-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:G i _ -� / / • • 2/0157 02 2016 WELL LOG TRANSMITTAL#903032876 AOGCC To: Alaska Oil and Gas Conservation Comm. January 29, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED ?.r t'Uzoica Anchorage, Alaska 99501 BENDER scoNfp RE: Perforation Record: 2D-14 Run Date: 1/3/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2D-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21183-00 Perforation Record (Field Print) 1 color log 50-029-21183-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: (1 ,4412-42-4z6Ldi) 15-elfeat • ��\��%% THE STATE /'" 77,7 333 `Nest Seventh Avenue T:117.- - (GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 ft 4 Main: 907 279 1433 ak 907.2'6.7542 tVi Erik Nelson SO' Workover/Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360I g/4 C4f Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2D-14 Sundry Number: 314-162 Dear Mr. Nelson: 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. Commissioner DATED this ) / day of March, 2014. Encl. STATE OF ALASKA '" ' - AL A OIL AND GAS CONSERVATION COMMi ..)Ncep i P- f) �..� ' * APPLICATION FOR SUNDRY APPROVALS "sir? 6 ;. 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell 17, Change Antel,FINrarnr Suspend r Plug Fbrforations Perforate r Pull Tubing p-, luiretxteqten r Operational Shutdown r Re-enter Susp.Well r Stimulate r Atter casing r Other: (- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 184-159 1 3.Address: 6.API Number: Stratigraphic r Service p' . P.O. Box 100360,Anchorage,Alaska 99510 50-029-21183-00• 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 r.• r 2D-14 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25658 . 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): 8300 ' 6228 ' 8171' 6125' 7793' 8016' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 117' 117' SURFACE 3870 9.625 3905' 3113' PRODUCTION 8223 7 8256' 6193' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7896-7914',7960-7978',7992-8046' • 5917-5929,5963-5977,5988-6029 3.5 J-55 7805 Packers and SSSV Type: 'Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=7776 TVD=5825 ' SAFETY VLV-BAKER FVL SAFETY VALVE MD=1881 TVD=1744 12.Attachments: Description Summary of Proposal F•• 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/31/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ p - GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson @ 263-4693 Email: Erik.Nelsoni conocophillips.com Printed Name rik.N n Title: Workover/Wells Engineer Signature ��A� Phone:263-4693 Date /1/Ar-zl/ Commission Use Only RBDMS MAY 1 1 2014 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ?j\LA -k Lot / Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: 3(J p rt-,5 /U 4 2-067f5 , , -fA fr kr, } --)r5.5zd /14 / ri .4! r ' V'''4- d 4 ft-i'r- ot-a b,7, d , ' er-1 - Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 — 4 U % APPROVED BY Approved by: .- '��, COMMISSIONER THE COMMISSION Date: 3 / 1 Appfoved application is valid tor 12 t- months tro he date of approval. Form 10-403(Revised 10/2012) /114,6 3/Pipit Submit Form rm and Attachments in Duplicate )74)74 -7 3/1 ' r,� ORIGINALcctc 51\01\A IA ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 14 March 2014 Commissioner Dan Seamount State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 2D-14 (PTD 184-159). Well 2D-14 was drilled and completed towards the end of 1984 and was pre-produced before being turned around as an injector in the latter part of 1985. This well was shut-in due to TxIA communication in 2000. It was placed on a water-only waiver in 2008 but was never brought on- line due to operational issues. The purpose of this workover is to restore mechanical integrity to the well by cutting and pulling the existing 3-W tubing above the existing packer and running a new 3-W tubing string above a stack packer which will overshot the tbg stub atop the existing packer. If you have any questions or require any further information, please contact me at 263-4693. Regards, Erik Q. Nelson Wells Engineer CPAI Drilling and Wells • 2D-14 Kuparuk Injector Expense Rig Workover PTD #: 184-159 Current Status 2D-14 is currently SI awaiting RWO operations Scope of Work • Pull 3-%" J-55 tbg from well • MU &TIH w/new 3-1/2" L-80 stack pkr assembly • Set FHL pkr, shear PBR, and space out& land new 3-W L-80 tbg General Well info MASP: 3040 psi using 0.1 psi/ft gas gradient Reservoir pressure/TVD: Calculated 3632 psi/5916' TVD (just above TOP in C-sand) Measured 3612 psi at 7804' MD (5846'TVD)w/ Panex gauges (01 Jun 2012) Wellhead type/pressure rating: FMC Gen III 3-1/8" 5M x 7-1/16" 5M BOP configuration: Annular/Pipe/ Blind/Flowcross/ Pipe TIFL/MIT-IA/MIT-OA: TIFL—Effective passing test on 13 Dec 2013 (3000 psi) during CMIT- T+IA(failed due to IA pressure loss MIT-IA—Failed on 13 Dec 2013 MIT-OA—Passed on 13 Dec 2013 Well Type: Injector Estimated Start Date: 31 Mar 2014 Production Engineer: Stephanie Pilch RWO Engineer: Erik Q. Nelson Work: 263—4693 Cell: 903—7407 E-Mail: Erik.Nelson@conocophillips.com Proposed RWO Procedure: Pre-Rig Well Work 1. Set a catcher sub on previously installed CA-2 plug (06 Jun 2012) 2. Pull DV from GLM#5 at 7722' MD (5785'TVD)for circ point 3. FP well and RDMO slickline RU, Test, &Pull Tbg 1. MIRU Rig. Accept Rig and take on fluids. Pull BPV, reverse circulate KWF, and insure well is dead. 2. Install BPV, ND tree, NU BOPE, install blanking plug, function and PT BOPE to 250/4200 psi and annular to 250/3500 psi 3. Pull blanking plug & BPV. Screw in landing jt, BOLDSs, and pull tbg hgr to the rig floor. 4. LD tbg hgr and TOOH sideways w/3-%" J-55 EUE-Mod tbg NOTE: If tbg is not free RU HES E-line for tbg cut Run 3-%"In!Completion 1. MU and TIH w/3-%" L-80 stack pkr completion to just above existing tbg stub 2. Spot— 30 bbls CI brine around Po' Boy overshot, pkr, and PBR. Locate tbg stub, drop ball/rod to set FHL pkr—7716' MD (just above lowest GLM in previous completion). CMIT-T+IA to 1500 psi to ✓ ensure pkr is set. Bleed tbg and IA to 0 psi upon successful PT. 3. Shear PBR. PU to MU, space out, and land tbg hgr. Land tbg hgr. PT tbg to 3500 psi and record on „/ chart for 30 min. PT IA to 3500 psi and record on chart for 30 min. Bleed IA and then tbg to 0 psi upon successful PT. 4. Set 2-way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 5. Pull 2-way check. Ramp up IA pressure to shear SOV and displace well to CI seawater w/freeze protect. Set BPV. 6. RDMO Rig. Post-Rig Work: 1. PuII BPV 2. Pull SOV from GLM and replace w/DV 3. MIT-T and MIT-IA to 3500 psi 4. Pull ball/rod & RHC plug 5. Pull catcher&CA-2 plug 6. Drift for tag 7. Handover to Ops via handover form for POI... KUP INJ 2D-14 Conoco ""ph- ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • C13n0C4hIla(Y 500292118300 KUPARUK RIVER UNIT INJ 48.42 3,100.00 8,300.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2D-14.2/5/2014 4.11:39 PM SSSV:TRDP Last WO: 39.99 12/24/1984 Vertical schematic(actual) - - --- 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 8,019.0 6/1/2012 Rev Reason:GLV C/O SET CATCHER lehallf 2/5/2014 IIz Casing Strings HANGER.31 5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 11 E CONDUCTOR 16 15.062 35.0 117.0 117.0 62.50 H-40 WELDED Lasing DescriptionOD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread II SURFACE 95/8 8.921 34.8 3,904.6 3,113.1 3600155 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 32.7 8,255.6 6,193.0 26.00 J-55 BUTT Tubing Strings " ' " '' - '' ' °'Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(IMO Grade Top Connection TUBING 31/2 2.992 31.5 7,804.6 5,846.5 9.30 J-55 EUE8RD .7.n-1'CONDUCTOR.3'5.0-1i7.0•- °" Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.5 31.5 0.12 HANGER FMC TUBING HANGER - 3.500 SAFETY VLV;1.881.3 4.J.; 1,881.3 1,744.1 41.36 SAFETY VLV BAKER FVL SAFETY VALVE 2.810 7,762.0 5,814.7 41.85 PBR BAKER PBR 2.810 7,775.7 5,824.8 41.77 PACKER BAKER FHL PACKER 3.000 1 7,792.5 5,837.4 41.67 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT;2.093.51111 7,804.0 5,846.0 41.61 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 7791'during 3.000 PDS(PROF on 03/07/98 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl • Top(RKB) (MB) (°) Des i Com Run Date ID(in) 7,792.0 5,837.0 41.68 CATCHER SET LONG CATCHER ON TOP OF CA-2 1/27/2014 • 7,792.5 5,837.4 41.67 PLUG 2.75"CA-2 PLUG 6/1/2012 0.000 • SURFACE;34.83,904.6 4 8,016.0 6,006.1 39.94 FISH E-line Fish 3/22/1985 0.000 Perforations&Slots GAS DET:4,363.9111 Shot Dens Top(TVD) B6n(TVD) (shotsM Top(ftKB) Btm(MB) (ftKB) (MB) Zone Date t) Type Corn GAS LIFT:5,941.0 7,898.0 7,914.0 5,916.5 5,928.6 C-4,UNIT 8, 1/20/1988 2.0 APERF Gearhart EnerJet II I 2D-14 111 7,960.0 7,978.0 5,963.4 5,977.1 A-5,2D-14 7/31/1990 4.0 APERF 21/8"EnerJet GAS LIFT;6,9.19.2 7,992.0 8,046.0 5,987.8 6,029.2 A-4,2D-14 12/24/1984 4.0 IPERF '120 deg.Phasing;4" Casing Gun Mandrel Inserts Sat GAS LIFT;7,467.2 n ti C on Top(TVD) Valve Latch Port Size TRO Run 1111 No Top(ftKB) (RKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date m III 1 2,083.5 1,891.2 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2012 GAS LIFT;7,722.0 2 4,363.9 3,430.1 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2012 3 5,941.0 4,526.3 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2012 4 6,939.2 5,222.2 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/7/2012 5 7,467.2 5,598.1 MMH FMHO 1 GAS LIFT OPEN BK 1/27/2014 6 7,722.0 5,784.9 MMH FMHO ' 1 GAS LIFT DMY BK 0.000 0.0 6/6/2012 PBR 7762.0 t min Notes:General&Safety PACKER.i'-5- •a-t, End Date Annotation • 9/8/2010 NOTE:WAIVERED WELL-T x IA COMMUNICATION 10/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;7,792.5, PLUG;7,792.5 CATCHER;7,792.0 'I(�',i SOS;7,804.0 APERF;7.898.0-7,914.0 • APERF;7,960.S-7,976.0 FISH;8,016.0 (PERF;7,992.0-8.046.0 PRODUCTION;32.7-8,255.6 I - • • K y /SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CANCELLATION ADMINISTRATIVE APPROVAL AMENDED AREA INJECTION ORDER 2B.053 Amended Ms. Kelly Lyons Problem Well Supervisor ConocoPhillips Alaska, Inc. ., ,, ; . .? fr" ' P.O. Box 100360 Anchorage, AK 99510 -0360 RE: Cancellation of Administrative Approval AIO 2B.053- Amended Kuparuk River Unit Well 2D-14 (PTD 1841590) Kuparuk River Oil Pool Dear Ms. Lyons: Pursuant to ConocoPhillips Alaska Inc. (CPAI)'s request dated August 22, 2011, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 2B.053- Amended, which allows continued water injection in Kuparuk River Unit (KRU) well 2D -14. This well exhibited tubing by inner annulus (TxIA) communication and CPAI did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. CPAI has since determined to not operate the well. Consequently, Administrative Approval AIO 2B.053- Amended no longer a +plies to operation of this well. Instead, operation of KRU 2D -14 will be governed b ' pr • visions of the underlying AIO No. 2B. DONE at Anchorage, Alaska : I at . s • 1 ember 22, 2011. 4 ill /LI 774,4„,z, aniel T. Seamount, Jr. • ''O orman CathJP. Foerster Commissioner, Chair Comm s' . ner Commissioner • • Conoco Phillips Recs. Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AUG 2 2O August 22, 2011 a Ceft. " ;,, .'.7chr orge Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Subject: 2D -14 (PTD 184 -159) Request for Cancellation of Amended Administrative Approval AIO 2B.053 Dear Commissioner. Seamount: ConocoPhillips Alaska requests the cancellation of Amended Administrative Approval (AA) AIO 2B.053 and the well will remain shut in long term for further evaluation. The well has been shut in since October 18, 2008. Currently the well will remain on the monthly injector report for reporting purposes of long term shut in. The AA approval, originally issued August 31, 2010 and then amended on December 13, 2010, was for continued water injection with TxIA communication. If ConocoPhillips intends to reestablish injection, the appropriate paperwork will be filed either for repair or resubmission for a new AA. Please call Brent Rogers or myself at 659 -7224 if you have any questions. Sincere, Kelly Lyons ConocoPhillips Problem Well Supervisor • • ~ SEAN PARNELL, GOVERNOR ADMINISTRATIVE APPROVAL AIO 2B.053 Mr. Martin Walters Problem Wells Supervisor ,.q ~ r~t~.,~-, ConocoPhillips Alaska, Inc.. «. , ~ ~ `~`. - `' =•' ~ ~ `` P.O. Box 100360 Anchorage, AK 99510-0360 RE: KRU 2D-14 (PTD 1841590) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for an administrative approval to continue water injection in the subject well. CPAI originally notified the Commission on October 20, 2008 that Kuparuk River Unit (KRU) 2D-14 exhibited intermittent tubing x inner annulus (TxIA) communication. The well has been inactive since June 2008 except for diagnostic testing on several occasions that has not been able to confirm the location of the leak. CPAI requests that the tubing and IA pressures be allowed to equalize at up to 3000 psi. 3000 psi is approximately 60% of the published internal yield of the 7" casing and 85% of the published internal yield of the 9-5/8" surface casing. For similar approvals, automatic shut in equipment tied to the well's outer annulus pressure that will activate at 1000 psi has been required. The reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 2D-14 exhibits at least two competent barriers to the release of well pressure. Installation of automatic shut in equipment on the well's outer annulus set to activate at 1000 psi will provide an additional level of protection due to the anticipated high annulus pressure. The Commission finds that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 2D-14 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; AIO 2B.053 • • August 31, 2010 Page 2 of 2 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; OtL 3. CPAI shall limit the inner annulus pressure to 3,000 psi and outer annulus pressure to 1,000 psi; 4. CPAI shall install, maintain and operate automatic well shut-in equipment linked to the well's outer annulus pressure. 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; 5. CPAI shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure. The initial MIT should be performed after thermal stabilization when the well is returned to operation; 6. CPAI shall perform a mechanical integrity test of the outer annulas to 1800 psi every 2 years; 7. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. at Anchorage, Alaska and dated August 31, 20 ~, M ~~~ , `~ie~ T. Seamount, Jr. T't'N t Cl`,~~ ' RECONSIDERATION AND APPEAL NOTICE v~ded in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 15, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: • ~~~~~~ AUG 2 4 2010 ~l~ska ~ ~ C~ Gs~, fission ~~lcltar~g~ ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing we112D-14 (PTD 184-159) to be online in water only injection service with known T x IA communication. If you need additional information, please contact myself or Brent Rogers at 659-7224, or MJ Loveland / Perry Klein at 659-7043. Sincerely, ~Gv~i~2~~ G~r~~%n ' Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Cc: Working Well File, Legal Well File • • ConocoPhillips Alaska, Inc. Kuparuk We112D-14 (PTD 184-159) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection we112D-14. Well History and Status Kuparuk River Unit we112D-14 (PTD 184-159) was drilled and completed in 1984 and 1985 as a development well and was converted to a service well in November 1985. 2D-14 was originally reported to the Commission on October 20, 2008 as showing signs of T x IA communication. The well has not been injected into for an extended period of time since June of 2008 except for a brief time in October of 2008 when the TxIA communication was noted. Due to no water injection capability at 2D Pad until recently, repair of the communication was not a high priority. In March of 2010, the well began experiencing elevated IA pressures which required frequent bleeding. Despite the obvious TxIA communication, the well passes all pertinent tests indicative of an intermittent or small leak. The following diagnostics have been completed to date: Date Test Result Comment 7/12/10 MITIA Passed 5/13/10 IA DD Inconclusive 8/21/09 MITIA Passed Witnessed by John Crisp 3/8/09 MITOA Passed Post Surface Casing Starter Head Weld 2/21/09 MITT Passed Tubing Tail Plug Set @ 7792' 11/29/08 TPOT & TPPPOT passed 11/29/08 MITIA Passed 11 /29/08 MITOA Failed Failure Due To Starter Head Leak 11/29/08 IA DD Passed Due to the intermittent nature of the communication, the location of the leak has not been identified. ConocoPhillips requests Administrative Approval which will allow the IA to equalize with the tubing in water only injection at a pressure not to exceed 3000 psi. If the condition of the well deteriorates and the leak point can be identified, repair options will be evaluated at that time. Well Integrity Supervisor 8/15/2010 • Barrier and Hazard Evaluation: Tubing: Despite passing and MITT and MITIA, the 3 1/2" 9.3# J-55 tubing does not have integrity to the packer @ 7776' MD, based on the pressure and bleed performance. Production casing: The production casing has integrity to the packer @ 7776' MD (5825' TVD) based on the passing MITIAs as outlined above. The 7", 26 ppf, J-55 production casing has an internal yield pressure rating of 4980 psi. ~c7~c~~~l~So _ ~ ~~ ~ ~~~ C~\ Surface casing: The surface casing has integrity based upon a passing MITOA outlined above. The well is completed with 9-5/8", 36 ppf, J-55 surface casing with an internal yield pressure rating of 3520 psi set at 3905' MD (3113' TVD) Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the production casing. Second barrier: The surface casing is the secondary barrier should the production casing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including ashut-in of the well. T/IA/OA plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. SYS: If necessary for approval, ConocoPhillips will install automatic well shut-in equipment on the well's outer annulus with an actuation pressure not to exceed 1,000 psi. Testing of the shut-in equipment shall be performed in conjunction with production well pilots and safety valves. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), IA pressure may equalize with injection pressure not to exceed 3000 psi; 2. Perform a passing MITIA every 2-years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum); A TxIA CMIT with tubing tail plug installed may be conducted should the MITIA fail. 3. Perform a passing MITOA to 1800 psi every 2 years; 4. IA pressure not to exceed 3000 psi & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. Well Integrity Supervisor 8/15/2010 2 ConocoPhillips FJaska,lnc. • KUP vzoos CONDUCTOR. 11] Sa/ely Valve, 1 BBt GAS LIFT, 2,083 SURFACE. 3.905 GAS LIFT, 4,364 GAS LIFT, 5,941 OIt GAS LIFT. 6.939 B[m GAS LIFT, ] 46] GAS LIFT, ],]22 PBR, ]. PACKER, ],]]6 NIPPLE, ].192 SOS, ],604 TTL, ],605 APERF, ].696-],914 APERF, ],960-],9>6 FISH, 8 016 IPERF, ].992-8,046 Zone 2D-14 i zizi~ saa Run Dale PRODUCTION, 6,256 TD. 6,300 Well Name 2D-14 End Date 9/1/2010 Days 365 Start Date 9/1/2009 3000 2500 2000 .Q 1500 1000 500 1.2 1 0.8 . ~ , . O.6d 0.4 0.2 0 0 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Mar-10 Apr-10 May-10 Jun-10 Jul-10 Aug-10 Sep-10 0 a J O7 O LL U E otes: Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Mar-10 Apr-10 May-10 Jun-10 Jul-10 Aug-10 Sep-10 Date Annular Communication Surveillance Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Thursday, June 24, 2010 8:33 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2D-14 (PTD 184-159) TxIA Attachments: 2D-14 TIO.pdf; 2D-14.pdf Tom, Page 1 of 1 Injector 2D-14 (PTD 184-159) still has suspected TxIA communication. It has not been online since the initial report in 2008 and is already on the monthly injector report. We are currently planning leak detection diagnostics. A 10-403 for repair or an AA application will follow pending the outcome of the diagnostics. Let me know if you have any questions. MJ Loveland (covering for Martin's Vacation) Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 `~`!~~' -iy.. "t r.: ... 8/31/2010 Date I 71112070 90 ,Date 412/2010 3000 2500 2000 Q. 1500 1000 500 0 Mar-10 i Annular Communication Surveillance _ WHP _ IAP _ OAP WHT ~1 ~~ ~ ~~ f~~~ Apr-10 May-10 Jun-10 Bleed History 2D-14 6/22/2010 2200 1500 700 INNER SWI 12 2D-14 6/13/2010 2100 1200 900 INNER SWI 2D-14 6/912010 2000 1150 850 INNER SWI 2D-14 6/4/2010 2050 14 2036 INNER SWI 2D-14 5/22/2010 2400 1550 850 INNER SWI 1 2D-14 5/13/2010 1950 1175 775 INNER SWI 2D-14 5/12/2010 2250 1650 600 INNER SWI 2D-14 5/9/2010 2300 1650 650 INNER SWI 2D-14 5/8/2010 2200 1600 600 INNER SWI 08 2D-14 5/4/2010 2300 1100 1200 INNER SWI 2D-14 4/28/2010 2250 1700 550 INNER SWI ll 2D-14 4/13/2010 2100 1200 900 INNER SWI 0.6d 2D-14 10/18/2008 2100 1000 1100 INNER PWI ~ 2D-14 10/18/2008 2550 1300 1250 INNER PWI 2D-14 4/12/2006 1650 300 1350 INNER PWI 2D-14 4!2/2006 2050 1350 700 INNER PWI 0.4 2D-14 3/13/2006 2250 1500 750 INNER PWI 2D-14 2/12/2006 2100 1500 600 INNER PWI 2D-14 12/14/2005 2100 1050 1050 INNER SWI 0.2 0 Jul-10 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 Mar-10 Apr-10 May-10 Jun-10 Date ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Guy Schwartz: a~ ~ ~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). 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 November l Ott', 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 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. 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 01/01/10 - o~.~ ~e ~r ~n ~ zk Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 2A-26 50103205750000 2080940 12" Na 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12!30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2D-05 50029211570000 1841260 SF n/a 24" n/a 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF Na 24" Na 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 ~ MEMORANDUM TO: Jim Regg ~ I P.I. Supervisor '~~~ ~ l ~~~~ ( FROM: John Crisp Petroleum Inspector C~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 24, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-14 KUPARIJK RIV iJNIT 2D-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~L"- Comm Well Name: KUPARUK RIV iINIT 2D-14 Insp Num: mitJCr090823161854 Rel Insp Num: API Well Number: 50-029-21183-00-00 Permit Number: 184-159-0 ~ Inspector Name: John Crisp Inspection Date: 8~21/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We^ zD'~4 ~ Type Inj. N ~T~ 5825 jA 160 2390 ~' 2300 2290 ~ P.T.Di 1841590 TypeTest SPT Test psi 2400 ~ QA 180 480 480 480 Interval 4YRTST p~' P - Tubing 1650 1650 1650 1650 NOtes: z•6 bbls pumped for test. No problems witnessed. ~,~ ~~'~ ~~~~-P~SS~,.~ ~~s~~~s~ g f•( ' `^,'4`~i f ~...}f;~~~ .f'~~' 4` , _. Monday, August 24, 2009 Page 1 of 1 REC~IV~® STATE OF ALASKA MAR x ~ 2t~09 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATId~d & Gas Cons. Commission --~- t. Operations Performed: Abandon ^ Repafr Well ^~ Plug Perforations ^ Stimulate ^ Other J BH weld 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. ~~>~~Gl;;~;r„~.,,< ^ Exploratory ^ 184159 3. Address: Stratigraphic ^ Service Q ` 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21183-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 127' 2D-14 8. Property Designation: 10. Field/Pool(s): ADL 25658~ALK 2584 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8300' feet true vertical 6228' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 117' 16" 117' 117' SURFACE 3778' 9-5l8" 3905' 3;112' PRODUCTION 8129' 7" 8256' 6;193' Perforation depth: Measured depth: 7$98'-7914', 7960'-7978'. 7992'-8046" r lq~;~r ~~+~ ~ r. `~~} y'k~~, , true vertical depth: 5916"-5929', 5963'-5977', 5987'-6029' Tubing (size, grade, and measured depth) 3-1f2" , J-55, 7805' MD. Packers & SSSV (type & measured depth) Baker FHL Packer 7.776' Baker FVL 1,881' 12. Stimulation or cement squeeze summary: S~ ~ l ~~- a~©c~ Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n!a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after proposed work: C^ Ga~ WAGQ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Ly v~ /a,~,;~~h ~~~~ Printed Name MJ Loveland Title WI Project Supervisor Signature ~ Phone 659-7043 659-7043 Date 3/9/09 ~ Form 1 -404 Revised 04/2004 ti ~ n ~ ' ~""' ~ ~ ~ ,~-~ ~ `' ~ `~`'~~ ~.. ~ Subm' ~ na~~~~ o ,-- ~ Y ± t 4 a ~ _ 2D-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/21/09 SET 2.75" CA-2 PLUG @ 7792' RK6.30 MIN MIT.PASS.BLED TBG AND IA DOWN MITT assed -INITIAL T/I/0=1500/450/0 PRESSURE TBG UP TO T/I/0=2100/450/0 AFTER 15 MIN T/I/0=2050/450/0 30 MIN T/I/0=2050/450/0 03/06/09 03/07/09 03/08/OS IA @ 30 psi and bleed down, OA @ zero. Purge nitrogen through OA and welders removed top portion of the TANKO top. Electrician set up Cooper heat for casing head weld. T/I/O = 0/0/0. BH weld complete. Purge nitrogen through the OA. Heat up casing head with cooper heat to ', 500 degrees. Seal weld casinghead using 3 pass weld as cer M.E specs. MT Inspected by Kakivik- passed. T/I/O = SI/0/0. MIT OA -Passed. Initial T/I/O = SI/0/0, pressured up OA to 1800 psi. start T/I/O = SI/0/1800, 15 min. reading T/I/O = SI/0/1700, 30 min. reading T/I/O = SI/0/1680. No fluids @ weld. Pumped 0.7 bbls of diesel. Bleed down OA to 180 psi, final T/I/O = SI/0/180. summary Bradenhead seal weld 2D-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary FW: 2D-14 (PTD 184-159) Rep~Of Suspected TxIA Communication • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, January 17, 2009 10:15 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Jim, Page 1 of 4 ~~~y Due to Operations' reluctance to provide the extra vigilance required to avoid the braiden head leak during 30 day test, we have decided to weld the braiden head before the injection test commences. ~ We will notify you when the well is ready to place on injection for the test. I suspect it will be ~45-60 days. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, December 22, 2008 7:40 AM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay Subject: RE: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Thank you for the clarification. I concur with placing the well on injection for up to 30 days to allow the well to thermally stabilize and to evaluate any IA repressurization that may occur. Braidenhead repair must be completed before recommencing injection following the 30 day diagnostic period. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Sunday, December 21, 2008 6:22 PM ~ To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 2D-14 (PTD 184-159) Report Of S ected TxIA Communication Jim, I have reviewed the diagnost~ that have been completed to date on this well and see that time and a TIO trend are really the only t s that we have left to confirm or refute if the IA pressure is thermally induced. The well 6/23/2009 FW: 2D-14 (PTD 184-159) Repor~ Suspected TxIA Communication Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, December 22, 2008 7:40 AM ~ ~' L ~~~~~ ~ ~~ To: NSK Well Integrity Proj Cc: NSK' Problem Well Supv; DOA AOGCC Prudhoe Bay Subject: RE: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Thank you for the clarification. I concur with placing the well on injection for up to 30 days to allow the well to thermally stabilize and to evaluate any IA repressurizatian that may occur. Braidenhead repair must be completed before recommencing injection following the 30 day diagnostic period. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Sunday, December 21, 2008 6:22 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Jim, I have reviewed the diagnostics that have been completed to date on this welt and see that time and a TIO trend are really the only tools that we have left to confirm or refute if the IA pressure is thermally induced. The well is completely liquid packed and was only online for 8 days after being shut in and cold soaked for 2 years. During that 8 day period the IA was only bled twice and may not have a chance to thermally stabilize. The requested 30 injection period would al-aw ample time far the IA to stabilize. The reasoning behind requesting the injection test period before repairing the starter head is mainly for budgeting and welding job prioritization. A braiden head weld takes approximately 60 days to plan and execute. If we could confirm the integrity of the well before the braiden head repair, it would allow us to better prioritize our welding jobs given the budget constraints for 2009. Please let me know if I can answer any additional questions or provide data to assist in your decision. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 19, 2008 3:35 PM To: NSK Problem Well Supv; NSK Well Integrity Proj L2/22/2008 FW: 2D-14 (PTD 184-159) Repoi~ Suspected TxIA Communication Page 2 of 3 Subject: RE: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Martin Walters and I exchanged voice messages regarding KRU 2D-14 earlier in the week. I believe he was curious about the status of the email request to allow injection for up to 30 days with monitoring for signs of communication. I cal{ed him to better understand what diagnotics would be done to confirm the wen's annulus pressures are thermally induced. [also was curious about the timing for repairs to the starter head, having not completely understood the statement "repair as soon as reasonably possible"). Why can't the starter head be repaired before CPAI brings the well on line? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Sunday, November 30, 2008 6:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF2 Prod Engrs; NSK Problem Well Supv; NSK Well Integrity Proj; Santana, Luis Alfredo Subject: FW: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Jim, Initial diagnostics were completed and all the tests have passed indicating the tubing down to the packer and production casing have integrity. The testing included the tubing packoffs, a MITIA and a IA DD test. Attached is the test results from the MITIA and below are the results from the IA DD test: Initial T/110=1425/1000/220 Start IA DD test T/If0=1425/360(220 10 min Tll/0=1425/370/220 20 min T/II0=1425/370/220 30 min TI110=142513701220 60 min Ttl/0=142513701220 During the diagnostics, an MITOA was performed and suspended due to a minor starter head leak. The starter head will be welded for repair as soon as reasonably possible and the appropriate 10-404 will be submitted upon repair. It is my opinion that the initial suspect T x lA communication was due to extensive therms( effects since the welt had been Si since 06/17/2000. GanocoPhillips would like to return the well to injection and monitor the WI-IP's. Allowing injection a minimum of 14 days and a maximum of 30 days with the uncertainty of the time it takes for the well to fully stabilize after being SI far 8 years. if there still appear to be signs of communication and thermal effects can be excluded as the reason, further diagnostics will be performed at that time. If after 30 days of injection and there are no signs of communication, the well will remain on injection under normal operating procedures. The weN will remain on the failed MET report for another 2 months and if the well shows signs of stabilization and no communication, it will be removed from the report and considered operating under normal well status. if after that time the well should show any signs of communication, under Rule 7, the wail would be reported and further diagnostics would be performed. Please respond and let us knave if this plan is acceptable and if you would like any further information. «MIT KRU 2D-14 11-29-08.x1s» 12/22/2008 FW: 2D-14 (PTD 184-159) Repol~f Suspected TxIA Communication Page 3 of 3 • Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Monday, October 20, 2008 4:30 PM To: 'tom maunder@alaska.gov'; 'jim.regg@alaska.gov' Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Santana, Luis Alfredo Subject: 2D-14 (PTD 184-159) Report Of Suspected TxIA Communication Tom/Jim, Kuparuk injector ZD-14 (PTD 184-159) is suspected of having possible TxIA communication based upon requiring frequent bleeds since being returned to injection on 10/10/08 and has been shut in. The well has a current T/IA/OA of 1178/400/5 and will be added to the Monthly Failed MIT report. ConocoPhillips intends to inject in the well as necessary to conduct additional diagnostics and will submit a 10-403 to repair or seek administrative approval to continue injection. Attached is a 90 day TIO plot and a wellbore schematic. «2D-14 TIO Plot.ppt» «2D-14 Wellbore Schematic.pdf» 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 Celi 907-943-1720 / 1999 Pager 907-659-7000 #909 12/22/2008 ~D i ~e~4 - ~ ~~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. ~ (Z~16' Kuparuk /KRU / 2D-14 11 /29/08 Greenwood / Hurley /Phillips - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2D-14 Type Inj. N TVD /5,825' Tubing 1,400 1,425 1,425 1,425 Interval O P.T.D. 1841590 Type test P Test psi 1500 Casing 500 3,000 2,925 2,900 P/F p / Notes: Diagnostic MITIA OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Intemal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2D-14 11-29-08.x1s _ ... _. - ~ d ;~. CC)#'iCfCC3~'}1i~~1~S r ti KUP Well Attributes _._-. _ .. 2 a>48 - ! / Wel{bore APtlUWI Fieltl Nama 500292118300 KUPARUK RIVER UNIT Wall Sielue proNlnj Well Type INJ PWI '.. Comment H2S (ppm) Data Annotation End Date _-wdl co~,r -zo-i4 to a2a -; 7Ana ---- SSSV: TRDP 0 7/1/2008 Last WO: -__.___,.______ 3cnemalk.-AClu t_i _ _ Annotation Depth (ftKB) End Dala Annotation Last Tag 7,967.0 10/2Y2008 -- -- - Rev Reason: SLM TAG, PULL PL_UG_ Casin~Strings J ~ T K ~ I String OD String ID Cesing Description (in) (in) Sat Depth Set Daptl Top (HKB) (ftKB) (kKl coNDUC'roR. ~ CONDUCTOR 76 75.062 0.0 117.0 ti] ! SURFACE 95/8 8.765 0.0 3,905.0 PRODUCTION 7 6.151 0.0 8,256.0 2D-14 _ _ .Intl 1 1 MU 1{lhH) TD Imaxl lit... 48.42 3,100.00 ( 8,300.0 KBArtl (k) Rig Release Date 39.99 12/217984 End Data 10/6/2008 (ND) String Wt String t) (IbalN) I Grade Strinp Too Thrd SafaN Valve, 1,881 GAS LIFT, 2,083 GAS LIFT, 5,941 GAS LIFT, 6,939 GAS LIFT, ],46] GAS LIFT, 7,]22 PBR, 7,]62 PACKER, l ]]6 ~' t__ NIPPLE,)]92 SOS, 7,804 TTL, 7,805 APERF, _ ~. ],898-],914 'i i APERF, ~ ],960-],9]8 Tubiny Stnngs ~ ~~ "t nO ID S C I il, -, ~ h (TV D) St ng Wt Sir ng IrrI Ti t ink C.~~.r I~t c~ ~ (~) Top (ttK8) _ tYC t YB) ~(Iba/flj_ Gra~ a ~; op TUF 'r: ~ a I .' 2.992 S.u :.?..1' 7 E i C ,E~^. OttTer In Hole {All Jewelry: Tubing Run 8 RetrievableLFish, etc.' __ - ioPD~NU, (ND) ! Top n 1 Top (ftKB) (ftKB) Inel (°) Deaeriptio Commanl Run Date II Perforations shot Top (ND) Btm (ND) Dana Top (ftKB) Btm (HKBI (HKB) (HKB) Zone Date (sh... Tvpe Comment i j i __ .-~- 3 ti3~ ~, ~_ _~ 1 1 2 ~_ ~__ y FISH, 8,016 ' IPERF, ~ - ~ ],9928,046 ,o TD, 8,300 MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'K¿óG cft ¡ 3.10.;' P.I. Supervisor l [ DATE: Monday, August 15,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2D-14 KUPARUK RIV UNIT 2D-14 sû . t,'/ \ \ Cb vr, FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Jp.j2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2D-14 Insp Num: mitJJ050810120134 Rei Insp Num: API Well Number: 50-029-21183-00-00 Permit Number: 184-159-0 Inspector Name: Jeff Jones Inspection Date: 8/8/2005 Packer I .---.---;------ I Well : 20-14 IType Inj.¡ N P.T~_..1. 1s415~ypeT~~t ¡--3FT Jnterval 4~TST_____ P/F __,'u Depth ._~_.__.,-- TVD_.___-L._=:~5 .!_~~ psi L 1456.25 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. '-ïA"! 1610 2250 I 2240 I" 2240 I ----------r-- ---- r --.-~----... r·----..----¡ ~--I--·-..------- I OA: 0 0 I 0 0 I I _[·__1______________... -----..----....----/------ ...---..-.--+-----....- Tubing 2850 ! 2875 I 2875 r 2875 I I _..-......__..--.__..~.._ ,_._..._..._1 _..___~___._______L..___..._.___. P Notes: 1.5 BBLs diesel pumped. 1 well house inspected, no exceptions noted. SC;'~N~~EL SEP ?~; Ü 200~j Monday, August 15,2005 Page 1 of I ) /~" (L. ,) cOnOCOPhiIUPSAI...a. ...S.·..·.k.·,..·.a...·.,..,. t:nc. ~ ·2D-14 API: 500292118300 SSSV Type: TRDP SSSV (1881-1882, OD:3.500) Gas Lift mdrelIDummy Valve 1 (2083-2084, OD:5,313) Gas Lift ¡ndrel/Dum m y Valve 2 (4364-4365, OD:5,313) Gas lift mdrel/Dummy Valve 3 (5941-5942, OD:5.313) Gas Lift mdrel/Dummy Valve 4 (6939-6940, OD:5.313) Gas Lift ¡ndrel/Dum m y Valve 5 (7467-746.8, OD:5.313) Gas lift ¡ndrellDummy Valve 6 (7722-7723, OD:5,313) PBR (7762-7763, OD:3,500) PKR (7776-7777, OD:6.151 ) NIP -- (7792-7793, OD:3.500) TUBING (0-7805, 00:3500. ID:2.992) Perf (7898-7914 ) Perf (7960-7978) Pert (7992-8046) E-line Fish - (8016-8021, 00 1375) '" ~ ~ " .", ~ ~: Ii .>: ~ ~ :[:.: ~ ~ 'ri¡:::::::::"::_I' . :::/:~:.:.¡. ~ : <}: ¡ > : .} f ¡:;.mw.·.·.·..::_.:·:::::~·· :::::::::::::····C::::rr :: ::J!!: I 'll1ii¡::::::::::::: ~ .mt~;:;:;:: ~ ..... ~ ¡ .. .:.:. ¡'.:: .::::::::::::: .......::__...:::::~.J :.:.:.:.:.;.: .:.;.;.;.;.;.: ::':;:;:':'.;".' :':::::jo·· .',' ~ ~ " '...." .:::::::::::: ].....",. :.:.;.:.:-:-: :::::::::::;: "I'" , ~ I ~ ~ I ~ ..,/.,:::.. ~ ~ ~ ~ ~ I ~ ~ ~r ~ .'- ~' P:~~~-~~ I . i·:::: 1':::«'-::::::.:.: ¡.......................:, -t -r -T -+ J ~ I Well Type: INJ Orig 12/2/1984 Completion: Annular Fluid: Last W/O: Reference Log: Ref Log Date: Last Tag: 8045 TO: 8300 ftKB Last Tag Date: 12/9/2004 Max Hole AnQle: 48 deg @ 3100 CaSing-Stting-ALL 'STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 T1.Ibin~$ttiriK:-TUlnNG Size I Top 3.500 0 PèrfÖr*iøtJ.s:..Summary Interval I TVD 7898 - 7914 5917 - 5929 KRU 2D-14 Angle @ TS: 41 deg @ 7899 Angle @ TO: 38 deg @ 8300 Rev Reason: TAG TO Last Update: 12/23/2004 7960 - 7978 7992 - 8046 5964 - 5977 5988 - 6029 Zone C-4,UNIT B A-5 A-4 Status Gas Lift Mandrels IValves St MD TVD I Man Man Type V Mfr I Mfr 1 2083 1891 MMH 31/2 X 1 2 4364 3430 MMH 31/2 X 1 3 5941 4526 MMH 31/2 X 1 4 6939 52221 MMH 31/2 X 1 5 7467 5598 MMH 31/2 X 1 6 7722 5785 MMH 31/2 X 1 Other (plugs,eq1.lip.,etc.)· -JEWELRY Depth TVD Type I 1881 1744 SSSV 7762 5815 PBR 7776 5825 PKR 7792 5837 NIP 7804 5846 SOS 7805 5847 TTL Fish. ;. FISH Depth I Description 8016 E-line Fish I I i Baker 'FVL' Baker Baker 'FHL' Camco '0' Nipple NO GO Baker I I .., Top o o o Ft SPF 16 2 Date Type Comment 1/20/1988 APER F Gearhart Ener Jet II 18 54 4 7/31/1990 APERF 21/8" EnerJet 4 12/24/1984 IPERF 120 deg. Phasing; 4" I Casing Gun V Type VOD latch Port TRO DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 Description Date Run 12/25/1984 112/25/1984 1112/25/1984 12/25/1984 112/25/1984 1/6/1985 Vlv Cmnt ID 2.810 2.810 3.000 2.750 2.992 2.992 Comment ~--'--- __-.J ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU/ 20 08108/05 Arend/Greenwood - AES Jeff Jones II,J\s-9 \Cb~ Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depth Pretest Initial 15 Min. 30 Min. Well 20-11 Type Inj. S TVO 5,879' Tubing 2,175 2,175 2,175 2,175 Interval 4 P.T.D. 1840990 Type test P Test psi 1500 Casing 1,350 2,870 2,830 2,830 P/F P Notes: Well 20-14 Type Inj. N TVO 5,825' Tubing 2,850 2,850 2,850 2,875 Interval 4 P.T.D. 1841590 Type test P T est psi 1500 Casing 1,610 2,250 2,240 2,240 P/F P Notes: Well 20-16 Type Inj. S TVO 5,814' Tubing 2,675 2,675 2,675 2,675 Interval 4 P.T.D. 1841610 Type test P T est psi 1500 Casing 1,750 3,240 3,170 3,160 P/F P Notes: Well Type Inj. TVO Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVO Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Test Details: SCANNEJJ t\UG 1 1. 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 2D 08-08-05.xls Al; ~ OILAND GAS CONSERVATION COMM. .ON REPORT OF SUNDRY WELL OPERATIONS 1. 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 X Other_ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 647' FNL, 184' FWL, Sec. 26, T11N, R9E, UM At top of productive interval 1317' FNL, 1567' FWL, Sec. 26, T11N, R9E, UM At effective depth 1458' FNL, 1447' FWL, Sec.26, T11N, R9E, UM At total depth 1465' FNL, 1407' FWL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8300' feet Plugs (measured) 6227' feet 6200'$8 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-14 Injector 9. Permit number 1~4-15c,)/90-566 10. APl number 5o-029211 83 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 81 71 ' feet Junk (measured) 61 2 5' feet Casing Length Structural Conductor 1 1 0' Surface 3 9 0 5' Intermediate Production 8 2 5 6' Liner Perforation depth: measured 7898'-7914', Size Cemented 1 6" 204 Sx CS II 9 5/8" 1500 Sx A.S. III 7" 275 Sx G 7992'-8046' Measured depth True vertical depth 110' 110' 3095' 3114' 8256' 6178' true vertical 5916'-5929', 5986'- 6030' Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7805' Packers and SSSV (type and measured depth) SSSV; Baker FVL @ 1881' Packer: Baker FHL 7775' 13. Stimulation or cement squeeze summary Intervals treated (measured) Perforated the A5 Sand from 7960'-7978' MD Treatment description including volumes used and final pressure RECEIVED SEP ! 0 1990 ,las a .0il & Gas CoDs. (;0mmiss[0D Anchoraf Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1600 1850 Tubing Pressure 2250 Subsequent to operation 1830 1650 225O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Wtr Injector 17. I hereb/v.~certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc.~,~,~ S, ubsidlary of Atlantic Richfield Company,' " -WELL --~ONTRACTOR ///..s - ~o1~ REMARKS IPBDT WELL SERVICE REPORT IFIELD - DISTRICT- STATE DAYS I IDATE 07'30 o~o - !/oo - 13oo · i' I--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots , STATE OF ALASKA , AL.ASKA OIL AND GAS C(~SERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown Re-enter suspended well 2. Name of Operator Alter casing _ Repair well _ Plugging _ ARCO Alaska. Inc. 3. Address P. O. BoX 100360, Anchorage, AK 99510 Change approved program _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Time extension Stimulate Variance_ Perforate ~ Other_ 6. Datum elevation (DF or KB) 6200'SS 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 647' FNL, 184' FWL, Sec. 26, T11N, R9E, UM At top of productive interval 1317' FNL, 1567' FWL, Sec. 26, T11N, R9E, UM At effective depth 1167' FNL, 1447' FWL, Sec. 26, T11N, R9E, UM At total depth 1119' FNL~ 1407' FWL~ Sec. 26~ T11N~ R9E~ UM 12. Present well condition summary Total Depth: measured 8300' feet true vertical 6227' feet Effective depth: measured 81 71 ' feet true vertical 6125' feet Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 3 9 0 5' 9 5/8" Intermediate Plugs (measured) 8. Well number 2D-14 9. Permit number 84-159 10. APl number so-0z9-21 1 83 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Junk (measured) Cemented Measured depth True vertical depth 204 Sx CS II 1 1 0' 1 1 0' 1418 Sx AS III 3095' 31 14 8256' Production Liner Perforation depth: measured 7898'-7914', true vertical 5916'-5929', Tubing (size, grade, and measured depth 3 1/2', 9.3 Ib/ft, J-55 7805' 7" 275 Sx Class G 8 2~6,' 61 78' 5986 -6030 Packers and SSSV (type and measured depth) SSSV; 1Baker FVL 1881', Packer: Baker FHL 7775' 13. Attachments Description summary of proposal_ Perforate the A5 Sand. 14. Estimated date for commencing operation August 1, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Detailed operation program X Status of well classification as: sketch Oil __ Gas __ Suspended _ Service Water 17. I h,~, certify that the foregoing is true and correct to the best of my knowledge. Iniector . Title Senior Operations Engineer FOR COMMISSION USE ONLY Date ?'" 2..~ '"'~¢ Conditions Of approval: Notify Commission so representative may witness Plug integrity_ BOP Test~ Location clearance__ Mechanical Integrity Test _ Subsequent form require !lAppr°val ~_~ -~' Approved by the order of the Commission Original $1gned By David W, jehn§~,on Commissioner Form 10-403 Rev 5/03/89 Approved Copy Returned Date ""~ I Z..,~0 SUBMIT I1(I TRIPLICATE Sundry Notice - Well 2D-14 Perforate the A5 Sand with a total of 4 shots per foot and 0 deg phasing from 7960' to 7978' MD. A and C Sand Pressure (6200' SS) = 3950 psi SPFO 4/25/90 NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. M. Lyden / L Wade July 18, · 1990 Page 4 Kuparuk Well 2D-14 Perforate A5 Sand 7/18/90 CC: 230DS28DL This procedure is designed to perforate the A5 Sand and increase injection. An E-line through tubing perforating system will be used. One run, magnetically decentralized with 4 shots per foot and 0 degree phasing is recommended. Since this is an injection well the perforating will not be performed underbalanced. The well should be shut in for 24 hours prior to perforating so that the perforating can be performed at balanced conditions. I .) MIRU slickline unit. 2.) Gauge tbg and tag fill. 3.) RDMO slickline unit. 4.) MIRU E-line perforating unit. Pressure test the lubricator. 5.) Tie-in and perforate the following depths: DIL/SFL ~_MD-RKB~ CBL ~MD-RKB} Shot Density/Phase ~ 7960' - 7978' 7960' - 7978' 4 spf / 0° 18' Perforate with the well shut in and leave it shut in well while running in and out with the gun. 6.) RDMO E-line perforating unit., 7.) Allow approximately 2 hrs before returning the well to injection. 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK STATE OF ALASKA ~'--'" ~ ALASKA OILAND GAS CONSERVATION COM,,,~SSION REPORT OF SUNDRY WELL OPERATIONS 0 !G [ Operation Shutdown m Stimulate X Plugging Perforate _ /~ Pull tubing Alter casing Repair well Pull tubing Other__ 6. Datum elevation (DF or KB) 5. Type of Well: Development Exploratory Stratigraphic Service 99510 4. Location of well at surface 647' FNL, 184' FWL, Sec. 26, T11N, R9E, UM At top of productive interval 1317' FNL, 1567' FWL, Sec. 26, T11N, R9E, UM At effective depth 1167' FNL, 1447' FWL, Sec. 26, T11N, R9E, UM At total depth 1119' FNL,1407' FWL, Sec. 26, T11N, R9E, UM 8 3 0 0' feet Plugs (measured) 6 2 2 7' feet 6200' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-14 Water Injector 9. Permit number/approval number 84-159/9-1032 10. APl number 5o-029-2118,3 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured 81 71 ' feet Junk (measured) true vertical 6125' feet Length Size Cemented Measured depth True vertical depth 1 10' 1 6" 204 Sx CS II 11 0' 1 10' 3905' 9 5/8" 1418~SxAS III 3905' 3114' 8256' 7" 275SxClassG 8256' 6187' measured 7992'-8046' true vertical 5986'-6030' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55 7805' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1881', Packer: Baker FHL 7775' 13. Stimulation or cement squeeze summary Ar~ch0ra~ Intervals treated (measured) ~' ° ,- 7992'-8046 Treatment description including volumes used and final pressure Backflow well 24 hrs, 20 bbls xylene @ 1BPM, 70 bbls DAD acid @ I BPM, 10 bbls ×ylene @ 1.5 BPM. Final injection pressure = 3540 psi. 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure -0- -0- 1275 1100 -0- -0- 1550 1400 16. Status of well classification as: Water Injector ×. Oil ~ Gas Suspended Service Tubing Pressure 2165 2135 Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title ~~1'~ 0~~ Form 10-404 Rev 05/17/89 SEQUENCE OF E~,aNTS Well ~'~Z~-/~L Operation .. ARCO Rep._~m~//~ &6~r,~ Date /-/,/-/d / 9~ TIMI~ _ /.2:00 7.'0 0 /~ ' ~o 12;z5 L2._'3~ 12 /:05 _/ ~5 1 _/_.'._55 _2_'__.~0 .2'3O' 2_.'_35___ _~..oo 3' ~5 l]:07 EVENT ~_p_ __C~_M_ ..... 4',~ ,,,' /~" ~,~ t&, dT'd O Well SEQUENCE Operation OF EVENTS ;ontinued) TIME ~ 2.3 .... ?:~7 EVENT ......... . .......... ~7_:-. ---v ........... ........ -. .... 7- .~,,-------0 --- ....... , r .... ---:7--~ ........... 7--- __m_,_:a : .... ,_:,.,,,,., __o~__~ .... '_d _. ...... J --~. .~. .... ~ -.J' . -,-~ ' ~ ~---~- ..... ___~_~ :___~_~:.__~_. ._~_,~,. __:___. ~ -- .~, .... 7c7 .... ' .......... .' ..~ ..... ~ .................... ~ ¥- ..... , ....... ~ ...... STATE OF ALASKA ~ 0 ~SKA OIL AND GAS CONSERVATION COIv,,~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ 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 -'X"- Exploratory _ Stratigraphic Service ~ 4. Location of well at surface 647' FNL, 184' FWL, Sec. 26, T11N, R9E, UM At top of productive interval 1317' FNL, 1567' FWL, Sec. 26, T11N, R9E, UM At effective depth 1167' FNL, 1447' FWL, Sec. 26, T11N, R9E, UM At total depth 1119' FNL,1407' FWL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8 3 00' feet 6227' feet Plugs (measured) 6. Datum elevation (DF or KB) 6200' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-14 9. Permit number/approval number 84-159/9-298 10. APl number 50-029-211 83 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 81 71 ' true vertical 6125' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 110' 16" 3905' 9 5/8" 8256' 7" measured 7898'-7914', true vertical 5916'-5928', Cemented 204 Sx CS II 1418 Sx AS III 275 Sx Class G 7992'-8046' 7986'-603O' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55 7805' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1881', Packer: Baker FHL 7775' Measured depth 110' 3905' True vertical depth 110' 3114' 13. Stimulation or cement squeeze summary 8256' 6187' i14. Intervals treated (measured) 7898'-7914', 7992'-8046'. Treatment description including volumes used and final pressure 275 gallons of chemlink SS-8660 @ 4 gpm. Final pressure 2350 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 0 - - 0 - 1500 1250 2230 Subsequent to operation - 0 - - 0 - 1525 1500 2470 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations, X 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ''~'' ~ Title Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE ARCO Alaska, I,r~.. Subsidiary of Atlantic Richfield Co, / WELL SERVICE REPORT WELL ~Z~-/~ ~TRACTOR . VZ'~ 0 - REMARKS ;PBDT IFIELD - DISTRICT- STATE OPERATION AT REPO~ IDA, S IDATE I 5"-~' ~o? //~ oc; ~3o0~8 0L. [-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Visibility miles IWind Vel. knots .- . ~"-'" STATE OF ALASKA AIJ--,...,A OIL AND GAS CONSERVATION COMMI~x'51ON '0 ~ APPLICATION FOR SUNDRY APPROVALS 1. 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 AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 647' FNL, 184' FWL, Sec. 26, T11N, R9E, UM At top of productive interval 1317' FNL, 1567' FWL, Sec. 26, T11N, R9E, UM At effective depth 1167' FNL, 1447' FWL, Sec. 26, T11N, R9E, UM At total depth 1119' FNL, 1407' FWL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 83 0 0' feet Plugs (measured) true vertical 622 7' feet None Effective depth: measured 81 71 ' feet Junk (measured) true vertical 61 2 5' feet None Casing Length Size Cemented Structural Conductor I 1 0' I 6" 204 Sx CS II Surface 3905' 9 5/8" 1418 Sx AS III Intermediate Production 82 5 6' 7" 275 Sx Class G Liner Perforation depth: measured 7992'-8046' true vertical 5986'-6030' Tubing (size, grade, and measured depth 3 1/2', 9.3 Ib/ft, J-55 7805' Packers and SSSV (type and measured depth) SSSV; Baker FVL 1881', Packer: Baker FHL 7775' 6. Datum elevation (DF or KB) 6200'SS feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-14 Water In!actor 9. Permit number 84-159 10. APl number 5o-029-21 1 83 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 110' 110' 3095' 31 1 4 8~256' 61 78' 13. Attachments Description summary of proposal Xylene/pad acid stimulation. Detailed operation program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 11-4-89 Oil __ Gas m Suspended 16. If proposal was verbally approved /!/3 / Name of approver /~, //{/¢p ,~ ~/,t, Date approved Service Water Iniector 17. I hereby certify that the foregoing is true and correct to th%best of my knowledge. Conditions of approval: Plug integrity ~ BOP Test Mechanical Integrity Test~ Notify Commission so representative may witness Location clearance Subsequent form require Approved b~/the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No ~,)~ I 10- ~-'CE-rfimissioner Date //--~-~ SUBMIT IN TRIPLICATE Sundry Notice Well 2D-14 Pump an A Sand xylene/PAD acid treatment through a CTU to clean up produced water injection damage. A and C Sand Pressure (6200' SS) = 4001 psi SPFO 10/18/89 NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS, NO BOP's WILL BE UTILIZED DURING THIS PROCEDURE, M..Lyden / L. Wade October 31, 1989 Page 3 PRODUCED WATER INJECTION DAMAGE REMOVAL WELL 2D-14 10/31/89 CC: 230DS28DL 1. Flow back well to surface facilities for 24 hrs prior to cleanout. 2. MIRU coiled tubing unit and pump equipment. RIH. . Clean out hole to approximately 8100' MD using remaining gelled water from a recent fracture treatment. Take samples of solids returned and send to lab for analysis. 4. Flow back well to surface facilities for 2 hrs or 200 bbls of returns. , , . . . Shut in well for 15 minutes, visually check produced water quality, take a sample for the lab then allow injection of produced water down the backside for 20 minutes. Record baseline produced water injection rate and pressure to compare to post treatment rates. Begin pumping 20 bbls of xylene at I bpm while reciprocating the CTU nozzle across the A Sand perforations. After pumping 13 bbls of xylene, initiate injection of produced water into the backside of the well at approximately 500 bwpd while pumping remaining xylene in order to force xylene into the A Sand perfs. Do not excede a differential pressure of 2000 psi between the coiled tubing and the 3-1/2" tubing annulus. Once 20 bbls of xylene has been displaced to perfs, stop produced water injection and allow xylene to soak for 15 minutes. Check produced water quality, take sample, then inject produced water down the backside for 20 minutes recording produced water injection rate and pressure. Follow with 70 bbls of 6% HCI PAD acid (Halliburtons trade name) emulsified with 20% xylene and divert with graded rock salt as follows: a) 50 bbls PAD acid at I bpm through the CTU with the produced water injection rate at 500 bwpd. b) Dived with 250 lbs of graded rock salt at 1ppg in saturated produced water at 1 bpm through the CTU with the produced water injection down the backside at 500 bwpd. c) 20 bbls PAD acid at 1.5 bpm with the produced water injection rate at 1000 bwpd. NOTE: Acceptable Acid Systems: Halliburton PAD acid Dowell DAD acid BJ Titan One Shot Add M~ Lyden/L. Wade October 31, 1989 Page 4 10. 11. 12. 13. 14. 15. Shut in well for 15 minutes, check produced water quality, take a sample, then allow injection of produced water down the backside for 20 minutes. Record produced water injection rate and pressure. Aftedlush acid with an additional 10 bbls of xylene at 2 bpm and a produced water injection rate of 300-400 bwpd. Shut in well for 15 minutes, check produced water quality, take a sample then allow injection of produced water down the backside for 20 minutes. Record produced water injection rate and pressure. RDMO CTU and pump equipment. Return well to full water injection rate. Monitor water quality, rate and pressure as well is returned to injection. lc. gO __ kc, o__l_~_- ~ ARCO Alaska, Inc. Post Office B 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 .Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Stad Date 1G-06 2D-14 2D-0 2D-1 WSW WSW WSW 8 5 -2&7 -8&9 -10&11 2V-16 Tbg. Comm. April, 1989 Stimulate April, 1989 Scale Treatment April, 1989 Fracture April, 1989 Conversion May, 1989 Conversion May, 1989 Conversion May, 1989 Perforate April, 1989 If you have any questions, please call me at 265-6840. Sincerely, (~. B. Smallwood Senior Operations Engineer GBS:kr Attach~nents CC: H. F. Blacker ATO 1126 J. Gruber ATO 1478 KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ OIL AND GAS CONSERVATION CC~MIb,~,ON · APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend _ Operation Shutdown Re-enter suspended well Alter casing _ Repair well Change approved program _ _ Plugging _ Pull tubing _ 2. Name of Operator ARCO Alaska. In¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 647' FNL, 184' FWL, Sec. 26, T11N, R9E, UM At top of productive interval 1317' FNL, 1567' FWL, Sec. 26, T11N, R9E, UM At effective depth 1167' FNL, 1447' FWL, Sec.26, T11N, R9E, UM At total depth 1119' FNL, 1407' FWL, Sec. 26, T11N, R9E, UM 12. Present well condition summary Total Depth: Time extension Stimulate X Variance Perforate Other 6. Datum elevation (DF or KB) 6200'SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-14 Water Injector 9. Permit number 84-159 10. APl number 50-02921 1 8300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool measured true vertical 8300' feet Plugs (measured) 6227' feet Effective depth: measured true vertical 81 71 ' feet Junk (measured) 61 2 5' feet Casing Length Size Structural Conductor I 1 0' I 6" Surface 3905' 9 5/8" Intermediate Production 8 2 5 6' 7" Liner Perforation depth: measured ~ 7992'-8046' MD Cemented Measured depth True vertical depth 204 Sx C. S. II I 10' 1 1 0' 1418 Sx AS III 3905' 31 14' 275 Sx Class "G" 8 2 5 6' 61 8 7' true vertical 5986'-6030' TVD Tubing (size, grade, and measured depth 3 1/2', 9.3 Ib/ft, J-55, 7805' Packers and SSSV (type and measured depth) SSSV; Baker FVL 1881', Packer: Baker FHL 7775'. 13. Attachments Description summary of proposal_ Detailed operation program _ BOP sketch _ .Pump Musol into A and C Sand/Acidize A Sand 14. Estimated date for commencing operation 4/10/89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service Water Ini.e. ctor 17. I hereby certify that the foregoing is true and correct to, he best of my knowledge. Signed L/z..,,-r_ ..¢..x.,.y'a,, T~tle :~ ,,/~..~-n ' / ' F~ ~MI~N USE ~LY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Commis~(BNNIE C. SMITH Form 10-403 Rev 06/15/88 ~ner IApprOval I SUBMIT IN TRIPLICATE Messrs. Lyden and Wade April 3, 1989 Page 2 PRODUCED WATER INJECTION DAMAGE RFJVK)VAL WELL 2D-14 4/03/89 CC: 230DS28DL · e @ackflow well through drain header for six hours. Control flow rate to approximately 4000 BPD rate to prevent damage to surface equipment or downhole. Return well to injection at maximum header pressure and let stabilize for one week prior to performing musol injection. Monitor injection rate and pressure for any improvement after backflowing. 3. MIRU injection pump capable of 2 GPM rate at 2200 psi pressure. o Mix 5 drums Chemlink SS-8660 (275 gallons) at a rate of 2 GPM with the produced water injection into Well 2D-14. Any injectivity improvement such as increased rate or lower wellhead pressure should be noted. Ensure KDGS is set up to record WHIP and injection rate during the treatment(Contact Operations Engineering). The treatment should take approximately 2 hours and 15 minutes to complete. SUNDRY NOTICE- WELL 2D-14 Pump a combined A and C Sand musol treatment and then selectively acidize the A Sand to clean-up produced water injection damage. NO BOP'S WILL UTILIZED DURING THIS PROCEDURE. The treatment will be pumped through a surface manifold. A and C SAND PRESSURE (6200' SS) = 4008 PSI 2/11/89 SPFO NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. ARCO Alaska, Inc. Date: April 5, 1989 Transmittal #: 7457 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 30-01 Kuparuk Well Pressure Report 3-26-89 Sand'A' 30-06 Kuparuk Well Pressure Report Sand'A' 30-09 Kuparuk Well Pressure Report 2- 1 5- 8 9 Sand 'A' 30-02 Kuparuk Well Pressure Report 2- 1 9 - 8 9 Sand 'A' 2.7- 1 3 Kuparuk Well Pressure Report 3 - 2 4 - 8 9 Both Sands 2 Z- 1 3 Kuparuk Well Pressure Report 3 - 2 4 - 8 9 Sand 'A' 2Z- 01 Kuparuk Fluid Level Report 3 - 21 - 8 9 Tubing 2 D - 1 6 Camco BHP Report 3 - 0 9 - 8 9 BHP 2 D - 1 4 Camco BHP Report 3 - 0 9 - 8 9 BHP 30-02 Sub-Surface Pressure Report 2- 1 9-89 #6461 3 3 O- 09 Sub-Surface Pressure Report 2 - 1 9 - 8 9 # 64 61 3 30-06 Sub-Surface Pressure Report 2-20-89 #29855 . Receipt Acknowledged: DISTRIBUTION; D&M State of Alaska Anchorage SAPC Mobil Chevron Unocal ARCO Alaska, Inc Post Office ~Jx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Co~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Sub,iect' Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1988. The data is provided in the form of separate zone surveys as or spinner logs listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me at (907) 263-4978. Sincerely, ~4. H. Kraly Operations Engineer MHK/SPT:pg:0163 Attachments ARCO Alatka, Inc. is a Subsidiary ol AtlanticRichfleldCompany 3~ --lo d ARCO Alaska, Inc.l Post Office 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: March 15, 1988 Transmittal #: 7119 RETURN TO: ARCO AlaSka, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. BoxlO0360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-8 2H-5 2H-5 3C-15 2D-12 Kuparuk Operations Engineering Water Injection Spinner. Data. Sheet. 2-16-88 Both Sands Kuparuk Operations Engineering Water Injection Spinner Data Sheet 3-2-88 Both Sands Kuparuk Operations Engineering Buildup Analysis 2-25-88 'C' Sand Kuparuk Well Pressure Report(otis) GRC Amerada Chart(2) 2-27-88 PBU 'A' Sand 8-26-87 PBU 'A' Sand Pressure/Temperature 2-16-88/2-19-88 PBU 'A' Sand 'Receipt Acknowledged: DISTRIBUTION: D &M Chevron Mobil SAPC Unocal ARCO Alaska. Inc. is a Subsidiary of Al ant cR chtieldCompa.n.y ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 3, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Attached in duplicate are multiple Reports of Sundry Well Operations on Kuparuk wells. The wells are listed below. Well Operation Perforation Perforation 2D-15 Perforation 1F-12 Set Storm Choke If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS:pg:0152 Attachments cc: File KOE1.4-9 RECEIVED Naska 0JJ & Gas Cons. C0mmlssJ0~ ~chc~,ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · "-"- STATE OF ALASKA ,~--. ALASK, JIL AND GAS CONSERVATION COMM, ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate I~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 995:10 4. Location of well at surface 647' FNL, 184' FEL, Sec. 26, TllN, R9E, UM At top of productive interval 1317' FSL, 1567' FNL, Sec. 26, TllN, RgE, UN At effective depth 1167' FSL, 1447' FWL, Sec. 26, T11N, R9E, UN At total depth 1119' FSL, 1407' FWL, Sec. 26, T11N, R9E, UM 5. Datum elevation (DF or KB) 6200' .SS Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-14 8. Approval number R-2R 9. APl number 50-- 029-21183-00 10. Pool Kuparuk River 0i] Pool 11. Present well condition summary Total depth: measured true vertical 8300' 6227' feet feet Effective depth: measured 8171' feet true vertical 6125' feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 110 ' 16" Surface 3905' 9-5/8" Intermediate Production 8256 ' 7" Liner Perforation depth: measured Cemented Measured depth True Vertical depth 204 Sx C.S. II 110' 110' 1418 Sx A.S. III 3905' 3114' 8256' 275 Sx Class "G" 7992'-8046' MD 6187' RF_-CEIVED true vertical 5986'-6030' TVD ?E~ ~ !'4U~' Tubing (size, grade and measured depth) 3-1/2", 9.3 lb/ft, J-55, 7805' ~'~;~*~ u. a Gas CONS..C9~ Anchor~e ........ Packers and SSSV (type and measured depth) SSSV' Baker FVL 1881', Packer' Baker FHL 7775' 12. Stimulation or cement squeeze summary Intervals treated(measured) Perforate C Sand (7898'-7914' MD, 2 SPF) through tubing. Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Casing Pressure 1325 Water-Bbl Tubing Pressure Prior to well operation 2300 2160 Subsequent to operation 4500 :1380 2085 14. Attachments Daily Report of Well Operations I~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge '~'// -' S i g n e d .,~____.~..,¢ ~ Form 10-404 Rev. 12:~-85' Title ~~~"~., ~/~',~ Date ,~/cfi ¢2 Submit in Duplicate~. ARCO Alaska, Sub~ldlmy of Atlantic Richfield Company WELL SERVICE REPORT WELL OPERATION AT REPORT TIME DAYS iOATE ' I Z.O [~ (~ REMARKS -ok u~ r~ RECEIVED .Alaska Oil & GaS 00115. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Temp. Weather Report Chill Factor J Visibility Wind Vel. °Fi miles knots /--' STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMM. ~$1ON 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. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 647' FNL, 184' FEL, Sec. 26, T11N, R9E, UM 5. Datum elevation (DF or KB) 6?ilo ' .g.g feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-14 ~ ~J,~,~r At top of productive interval 1317' FSL, 1567' FNL, Sec. 26, A~. ff (~tive depth A[tc~t~d~, 1407' EWE, Sec. 26, T11N, R9E, UM T11N, R9E, UM T11N, R9E, UM 8. Permit number 84-159 9. APl number 50- 0292118300 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8300' 6227' feet feet 8171' 6125' feet feet Plugs (measured) Junk (measured) Casing Length Structural 110 ' Conductor Surface 3905' Intermediate 8256' Production Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth True Vertical depth 16" 204 Sx C.S. II 110' 110' 9-5/8" 1418 Sx A.S. III 3905' 3114' 7" 275 Sx Class "G" 8256' 6187' 7992'-8046' MD ~.: '~--?.. 5986'-6030' TVD . . 3 1/2", 9.3 lb/ft, Packers and SSSV (type and measured depth) SSSV: Baker FVL 1881': Packer: Baker FHI 7775'. 12.Attachments Description summary of proposal [] Detailed operations program [] Perforate C Sand (7898' to 7914' MD, 2 SPF) throuqh tubinq. 13. Estimated date for commencing operation 01/14/88 BOP sketch [] 14. If proposal was verbally approved Name of approver Lo¢,~ ~ ~',,.~ Date approved 15. I hereby,certify that t~he fqrq~going is true and correct to thc, best of my knowledge Signed '~~' /~'d~'"~'-'~'¢?"2 Title ._K~~y¢~ ' - /v/ ' - Commission Use Only Date ///~,'/~ ~ Conditions of approval N°tifyc°mmissi°ns°representativemaywitness I Appr°valN°' ~]> [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned ~ ~llll~llaaalme.i by order of Commissioner the commission Date / -(.~/-~ ORIGINAL SIGNED BY Approved by LONNIE C. SMITH Form 10-403 Rev 12-1-85 Submit in triplicate--,,.. ARCO Alaska. Inc. _ · . Post Office bvz 100360 Anchorage. Alaska 99510-0360 Telept~one 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 signed copy of this transmittal. DATE 03-11-86 TRANSMITTAL # 5595 Please acknowledge receipt and Final Prints/ Schl/ CET or CBL's/ One * of each 3536-6934 ~lQ-12 01-21-85 Run #1 /~2A-8 11-02-85 Run #1 6986-8362 3 12-17-84 Run #1 5425-7488 ~2D-14 17-12-84 Run #1 6288-8136 ~2H-11 11-28-85 Run #1 4850-6642 ~2H-12 11-28-85 Run #1 5500-6776 -~W-15 02-02-85 Run #1 6500-8096 ~3A-4 11-03-85 Run #1 6792-8329 ~'~3F-4 11-12-85 Run #1 4770-6734 ~F-7 11-14-85 Run #1 4950-7876 PT~ASE NOTE: These logs were received from the vender today 03-11-86. Receipt Acknowledged: Vault*~films NSK Clerk*bl ~~1i~J. Oi & Gas Cons. Commission ARCO Alaska. Irtc. ~s a Sul}stgharf of &lla~ticRicl~fial~lComoany ARCO Alaska, Inc. Post Office E,~,,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- Well Action Date Performed on the 1L-1 Convers 1L-7 Convers 1Q-2 Convers 1Q-7 Convers 1Q-11 Convers 1Q-1 3 Convers 2B-5 Convers 2B-9 Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D-2 Convers 2D-7 Convers 2D-11 Convers 2D-14 Convers 2F-1 Convers 2F-2 Convers 2F-1 3 Convers 2F-1 4 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers on on on on · on on on on on on on on on · on on · on on · on on · on on · on on · on on · on · on on on on on on 11118185 11/18/85 11/17/85 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11/20/85 11/20/85 11/20/85 11/20/85 11/21/85 11/21/85 11/2:1/85 11/21/85 11/lq/85 11/14/85 11/14/85 11114185 11/14/85 11/14/85 11114185 RECEIVED 11/16/85 ~,, 11/1 6 / 85 .JAN.2O t a¢ 11116185 11 / 22 / 85 A~:her~9~ ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCom= ~ny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator ARCO A~SKA, INC. 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCATION- T11N, RD E, UM 7. Permit No. 84-159 8. APl Number ANCHORAGE, ALASKA 99510 50- 029-21183 9. Unit or Lease Name 647' FSL, 184' FEL, SEC. 26, KUPARUK RIVER UNIT 10. Well Number 2D-lq 11. Field and Pool KUPARUK RIVER FI ELD I 6. Lease Designation and Serial No. KUPARUK R I VER O I L 127' (RKB) ADL 25658 ALK 2584 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 5. Elevation in feet (indicate KB, DF, etc.) 12. 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). On November 20, 1985 Kuparuk well 2D-14 was converted producer to a water injector well as part of the full waterflood conversion effort. Water is being injected "A" and "C" sands. from a f eld nto both the 2 0 I986 Naska 0~1 & Gas Cons. C0rllffliSgiu 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,.~, .~'~ _t~/-~"~'~ Title KUPARUK The space below for Commission use OPERAT IONS COORD ! NATOR Date _. 1 2 / 1 8 / 8 5 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~,,.~. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation On September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per 'drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/~ 'L AND GAS-CONSERVATION C/ IMISSION SUNDRY TICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, 'Inc. see attached 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- see attached 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/^ 12. J 6 . Lease Designation and Serial No. see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other Y~ Pulling Tubing [] (Note: Report multiple completions on Form 10407 with a submitted Form 10407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list of~^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion', to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. sEP 2 0 Gas Cons. Comm~'ssi°n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Approved by (~~ ~/~~J Form 10403 ~' Rev. 7-1-80 Title Kuparuk Operations Coordinator Date 9/18/85 ^ ~o~,,~ c~y By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:009 100 96 95 84-152 151 126 143 101 99 159' 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 8O 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 2-1185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 II 25658 II I! 25657 I! II !! !! 25656 I! !! 25644 25643 !1 25655 25644 !! 25655 !! 25642 2580 12/15/85 lO/15/85 12/15/85 2579 -I! .2584 12/15/85 10/15/85 10/15/85 12/15/85 10/15/85 12/15/85 12/15/85 10/15/85 2584 12/15/85 '12/15/85 12/15/85 12/15/85 2583 12/15/85 12/15/85 10/15/85 10/15/85 12/15/85 12/15/85 10/15/85 10/15/85 2582 I! 12/15/85 10/15/85 10/15/85 12/15/85 10/15/85 12/15/85 10/15/85 2575 2574 lO/15/85 12/15/85 lO/15/85 lO/15/85 lO/15/85 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 '10/15/85 " 12/15/85 " 12/15/85 ' ECEIV 5/85 ~laska 0i! & Gas Cc;ns~ Cum. ARCO Alaska, Inc. , Post Office BoxY"1'0'0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~lay 1, 1985 ,. Mr. C. V. Chal~terton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells: DS 6-11 DS 15-8 2D-14 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L68 Enclosures RECEIVED MAY 0 1985 " Alaska Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AflanficRichfieldCompany " STATE Of ALASKA ' " ALASKA._._.- AND GAS CONSERVATION C~'. .VIISSION WELL COMPLETION OR RECOMPLETION] EPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-159 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21183 4. Location of well at surface 9. Unit or Lease Name 647' FNL, 184' FEL, 5ec.26, TllN, RgE, UN Kuparuk River Unit: At Top Producing Interval 10. Well Number 1317' FSL, 1567' FWL, Sec.26, TllN, RgE, UM 2D-14 At Total Depth "11. Field and Pool 1119' FSL, 1407' FWL, Sec.26, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKB ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 11/24/84 11/30/84 1 2/25/84] 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 8300'MD,6227'TVD 8171'MD,6125'TVD YES J-~X NO [] 1881 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL, Gyro (GCT), CBL, CCL/Temp. 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 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3905' 12-1/4" 918 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 8256' 8-1/2" 275 sx Class G & 250 s) AS ! 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) 7992' - 8046' w/4 spf, 120° phasing 3-1/2" 7805' 7776' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See at:tached Adde Idum, da~:ed /+/12/85. 27. N/A PRODUCTION TEST Date First Production ] Method of Operation (FloWing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONERECEIVED Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 GRU6/WC21 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ,,gi.-, , 30. " G~EOLOG'IC MARKEFtS : ~ ~ · .: 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 Upper Sand 7897' 5915' N/A Base Upper Sand 7912' 5926' Top Lower Sand 7945' 5951' Base Lower Sand 8102' 6071' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~/~,~L~ Title Associate Encjineer Date z~-~<~'<~ .INSTRUCTIONS General' This form is designed for submitting a-complete and correct well completiOn report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etC.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 2D-14 12/03/84 12/18/84 3/18/85 3/21/85 8171' PBTD On 12/02/84, pmp'd 25 bbls 10.1NaCl/NaBr dn 9-5/8" x 7" ann, followed by 5 bbls diesel. On 12/3/84, pmp 65 bbls of crude oil dn 9-5/8" x 7" ann for freeze protection. This annulus is not Arctic Pak'd to date. 8171' PBTD, SI Rn CBL f/8150' (Log TD) to 6288'. Rn gyro f/TD to surf. Frac'd well in 8 stages w/353 bbls gelled diesel, 1008# of 100 mesh & 2772# of 12/20 mesh. Left 11,172# of 12/20 mesh in csg. Log well w/CCL/Temp tl f/8034'-7720', lost tl. Will fsh after flowing well. Drilling ~uperintendent RECEIVED MAY 0 Alaska Oil & 6~s Cons. ~' Anchora~o ,ARCO Oil and Gas Company Daily Well History-Final Report I~l~u~ti~ae: Prepare end submil the "Flail R~rr' on the fimt Wednesday after allowable has been assigned or well is Plugged. Abandoned, or ~old. "Fiftal flel~rt" ~ould be submitted also when oeeretlons are susl~ended for an indefinite or appreciable length of time. On workovers when an official test is not required Ul~3a complaUon, report completion end representative test dst,= in blocks provided. The "Flail R~l't" form may be uSed for reporting the entire oOeration if space is available. I Accounting cost center code District ICounty or Parish /Slate Alaska J North Slope Borough J Alaska Field ILease or Unit I we. no. Kuparuk River ! ADL 25658 I 2D-14 Auth. or W.O. no. ITM AFE 802891 I Completion Roll'N 4 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. 0egun JOete I Complete Date and del3th Complete record for each day reported as of 8:00 a.m. 12/22/84 thru 12/25/84 API 50-029-21183 W.L [Total number of wells (active or.inactive) on this ICOSt center prior to plugging and 56 · 2/--I.Z labandonment of this well I IHour I Prior status if a W.O. 12/22/84 / 2330 hrs. I 7" @ 8255' 8171' PBTD, RR Crude Oil w/Diesel Cap Accept ri~ @ 2330 hfs, 12/22/84. ND wellhead, NU & Sst BOPE. RU Gearhart & perf w/4" gun @ 4 SPF/120° phasing f/8026'-8046', 8006'-8026', 7992'-8006', 4 SPF/120° phasing. Rn 6-1/8" gage ring to 7992', Rn 188 its, 3½", 9.3#, J-55 EUE IPC tbg w/SSSV @ 1881.26', FHL pkr @ 7775.65', "D" nipple @ 7792.48', Shear sub @ 7804.01', TT @ 7804.61'. MU tbg hgr, lnd tbg. Press tbg to 2500 psi, set pkr, shear PBR, re-lnd tbg. Tst ann to 2500 psi. Set BPV. ND BOPE, set BPV. NU tree, pull BPV, sst pack-off; OK. Tst tree to 5000 psi. Pull Sst plug, circ 35 bbls diesel, followed by 240 bbls crude. SI tbg press -- 600 psi. Tst SSSV, Shear out ball, bled tbg to 700 psi. Set BPV. RR @ 0330 hrs, 12/25/84. Standby w/crews, wait on weather. ~ch0rage C0mm~ss~0~ Old TO New TD Released rig Date 0330 hrs. Classifications (oil, gas, etc. I Oil J PB Depth IKind of rig 12/25/84 I Type completion (single, dual. etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential leal data 8171' PBTD Rotary 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 ~/~ ~,_~~_j 1/24/85 Drilling Superintendent For form prel3aratio~ ;n-d~ietribution, see Procedures M~null, Section 10. Drilling. Pages ~6 and 87. ARCO Alaska, Inc. Post Office 100-360 Anchorage; Alaska 99510-0360 Telephone 907 276 !2!5 ... .c. ~'\ t... ~..; '... ~'.":'~ "!' /,. ,", f",,. ¥.:,,";v ............... 'i L.v' :.'.-' ."; :"; :.'J ;4 ;'-.I ¢': ..l f".' 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ARCO Alaska, inc. is a q ,,'-'-~ '4i¢''v of Atfan¢cF:ichfieidCompany ALASI(A OIL A~ID 8A$ ~.O#$ERYATION-~,OMM/$$10# / sool PORCUPINE DRIVE · / AHCHORAGEoALAdKA TEL E P H ONE ! 1107! ~17 t,- 1433 i · o,_4_ L A ;/<~ _~N.~. , _ /Ftt--~. .'~_B E ~.~ y 5'T~£~ ~ p....._. , A . ?_~ ! ~ / ? PO I~ ~. ~ ~ ~o~' _¢/1~._ ~..~. %~. ~.~. ,~~.. We wish to bring to your attention that the yet received the following require8 item~ on the ~ubJect well ~hich our records indicate8 was complete~ / Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. · Chairman lc,C.024 AR~o Alaska, Inc. Post Office Bc._.~J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton- Enclosed are revised Well Completion Reports for the following wells' 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 2 l g[i AlasKa 0il & Gas Cons. l~ommis$loa Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany ,; ' STATE OF ALASKA ALASKA'"~-,L AND GAS CONSERVATION CC~.?MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISION OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2~ Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-159 3. Address 8. APl NUmber P, 0. Box 100360, Anchorage, AK 99510 50- 029-21183 4. Location of well at surface 9. Unit or Lease Name 647' FNL, 184' FEL, Sec.26, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1317' FSL, 1567' FWL, Sec.26, TllN, RgE, UM 2D-14 At Total Depth 11. Field and Pool 1119' FSL, 1407' FWL, Sec.26, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKB[ ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 116. No. of Completions 11/24/84 11/30/84 1 2/25/84I 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 8300'MD,6227'TVD 8171'MD,6125'TVD YES E~X NO [] 1881 feetMDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/Cal/FDC/CNL, Gyro ((]CT) ~ CBL 23. CASING, LINER AND CEMENTING RECOBD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3905' 12-1/4" 918 sx AS Ill & 500 sx!Class G 7" 26.0# J-55 Surf 8256' 8-1/2" 275 sx Class C & 250 si 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) 7992' - 8046' w/4 spf, 120° phasing 3-1/2" 7805' 7776' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED=l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~' 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APR 2 2 985 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 JMM2/WC09 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~1~.. 30. ' ' ~ ', · _ . . _ . . ~ ~ G'EoEOGIc MARI~ER'~ ; :', ::' .-: ~ :~'-: : FORMATION TEs'T-S .~ ' · NAME Include interval tested, pressure data, ali fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7897' 5915' N/A Base Upper Sand 7912' 5926' Top Lower Sand 7945' 5951' Base Lower Sand 8102' 6071' _ · : ~ . . , . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~, ~ ~ Title Associate Engineer Date z~-/~j)-~' .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 (G L) 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 Alaska, Inc. Post Office B'~' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ^pril 8, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-14 Dear Mr. Chatterton' Enclosed is an addendum to the 2D-14 Well History to include with the Well Completion Report dated 03/04/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L95 Enclosure RECEIVED APR Z ? Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . ARCO Alaska, In Post. Offic 360 Anchorage. Alaska 99510 Telephone 907 277 5637 :.. :"-.. J. i ....... j~' ! ......JO I"l i'4 :-..7 ';' Ci i',i ~ :~..? ~.., :i: i....x. ~ ~..! :7!< C 1._ i!~. !:-: i,{ ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 4, 1985 Mr. C. V. Chatterton Commi s s ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-14 Dear Mr. Chatterton: Enclosed is a copy of the 2D-14 Well History to include with the Well Completon Report, dated 02/12/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU4/L207 Enclosure & Gas Cons. Anchorage C'Ommissiort ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office BO'x~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2D-14 Dear Mr. Chatterton' Enclosed is a Well Completion Report and revised Well History (Completion Details) for the subject well. If you have any questions, please call me at 263-4944. Sincerely, ', ~ A Gruber Associate Engineer JG/tw GRU4/L206 Enclosures MAR o 8 t9G5 ~as_l~. 0il & Gas Cons. Commission _. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC__.,VIlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-159 ~. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21183 4. Location of well at surface 9. Unit Or Lease Name 647' FNL, 184' FEL, Sec.26, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1317' FSL, 1567' FWL, 5ec.26, T11N, RgE, UM 2D-14 At Total Depth 11. Field and Pool 1119' FSL, 1407' FWL, Sec,26, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 126' RKBI ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 116. No. of Completions 11/24/84 1 1/~0/84 1 2/25/84I 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 8300'MD,6227'TVD 8171' MD ,6125 ' TVD YES I~ NO [] 1881 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/Cal/FDC/CNL, Gyro (GCT), CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 2Ob, sx Col d Set. I I 9-5/8" 36.0# J-55 Surf 3905' 12-1/4" 918 sx AS Ill 7" 26.0# J-55 Surf 8256' ~-1/2" .275 sx C]a~ G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7992' - 8046' w/4 spf, 120° phasing ~-1/2" 7805' 7776' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER~BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATEDiI~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr} Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ~aska 0ii & Gas Cons. Form 10-407 GRU4/WC51 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC'MARKERS _ :--. FoRMATioN.TEStis . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTF GOR, and time of each phase. Top Upper Sand 7897' 5915' N/A Base Upper Sand 7912' 5926' Top Lower Sand 7945' 5951 ' Base Lower Sand 8102' 6071' . 31. LIST OF ATTACHMENTS Rev,.' _~ed We! ! Hi _~tory (Completio.n ~et~_~ ~_ s) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed ~ ~ ~ Title Associate Engfneer Date INSTRUCTIONS . General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production t~rom 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 ADDENDUM WELL: 2D-14 12/03/84 12/18/84 3/21/85 8171' PBTD On 12/02/84, pmp'd 25 bbls 10.1NaC1/NaBr dn 9-5/8" x 7" ann, followed by 5 bbls diesel. On 12/3/84, pmp 65 bbls of crude oil dn 9-5/8" x 7" ann for freeze protection. This annulus is not Arctic Pak'd to date. 8171' PBTD, SI Rn CBL f/8150' (Log TD) to 6288'. Rn gYro f/TD to surf. Log well w/CCL/Temp tl f/8034'-7720', lost tl. Will fsh after flowing well. RECEIVED APR 1 7 1985 · ask~ Oil & Bas Cons. C onlmissio~ -Anchorage Dr il linZg ~uperintendent ~Date ARCO Alaska, Inc. Post Office B6"x~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 13, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-14 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the 2D-14 Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L147 Enclosures RECEIVED F E B ! 5 1985 Alaska 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA',-~.~:- AND GAS CONSERVATION CC-,:__MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] :~. Name of Operator 7. Permit Number ARCO Alaska, Inc. , 84-159 ~3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-2118:3 4. Location of well at surface : £r-,~-,~:_-:~- 9. Unit or Lease Name 647' FNL, 184' FEL, Sec.26, T11N, RgE, UN ~ Kuparuk River Unit At Top Producing Interval / ~i 10. Well Number 1317' FSL, 1567' FWL, 5ec.26, T11N, R9E, UM 2. urf.~, 2D-14 At Total Depth - .. 11. Field and Pool 1119' FSL, 1407' FWL, Sec.26, T11N, RgE, UM Kuparuk RiVer Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 126' RKBI ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore I 16. No. of Completions 11/24/84 11/30/84 12/25/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 8300'MD,6227'TVD 8171 'MD,6125'TVD YES [] NO [] 1881 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D I L/S FL/CR/SP/Ca ]/FDC/CNL, Gy re ((;CT), CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24.. 204 sx Col d Set I I '- 9-5/8" 36.0# J-55 Surf 3905' 12-1/4" 918 sx AS Ill & 500 sx!Class 7" 26.0# J-55 Surf 8256' 8-1/2" 275 sx Class G . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7992' - 8046' w/4 spf, 120° phasing 3-1/2" 7790' 7776' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A _, I 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) · Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr} - Press. 24-HOUR RATE I~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska 0it 8, Gas Cons. CommisSion Anchorage Form 10-407 GRU3/WC49 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ 30. GEOLOGIC MARKERS : . FORMATION TESTS _- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7897' 5915' N/A Base Upper Sand 7912' 5926' Top Lower Sand 7945' 5951' Base Lower Sand 8102' 6071' 31. LIST OF ATTACHMENTS w~ ~+ .... I~n~,,a~ =aa~n~,,,,~ n ...... ~,~ ~ ...... y (2 copies) ............ ,.~ ', .......... ~ ........... · · ~,./ ..... I" · ~ 32. I hereby certify that the foregoing is true and correct to~ I~;st of my knowledge Signed ~ ~ .~-d-,j~t-) Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a comPlete and correct well completiOn report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separatelY produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 12/18/84 2D-14 8171' PBTD, SI Rn CBL f/8150' (Log TD) to 6288'. Rn gyro f/TD to surf. Drillin~ Superintendent Alas~ Oil & Gas Cons, Cornmismon Anchorage Date ARCO Oil and Ga "Company 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. "F(naf ReporF° should be submitted also when operations are suspended for an indefinite or appreciable length of [imm On workovers when an official test is not required upoe 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. District ICounty or Parish I Alaska Field ~hease or Unit I Kuparuk River Auth. or W.O, no. JTitle I AFE 802891 Roll'N 4 Operator J AR.Co. W.I. ARCO Alaska, Inc. Spudded or W.O. begun Date Complete Date and depth as of 8:00 a.m. Old TD Released rig 12/26/84 Complete record for each day reported North Slope Borough ADL 25658 JAccounting State COSt center code Alaska IWell no. 2D-14 Completion API 50-029-21183 r'rotal number of wells (active or inactive) on this Jcost center prior to plugging and j 56.24% Jabandonment of this well I JHour J Prior status if a W.O. 12/23/84 I 2330 hrs. 7" @ 8255' 8171' PBTD, RR Crude Oil w/Diesel Cap , Accept ri~ @ 2330 hrs, 12/23/84. ND wellhead, NU & tst BOPE. RU Gearhart & perf 8026'-8046', 8006'-8026', 7992'-8006' w/4", 4 SPF/120° phasing. RIH w/6-1/8" gage ring, set dn @ 7992', RD Gearhart. RIH w/188 jts, 3½", 9.3#, J-55 EUE IPC tbg. PU SSSV nipple, rn w/3½" tbg w/TT @ 7790'. MU tbg hgr, lnd tbg. Press tbg to 2500 psi, set pkr, shear PBR, re-lnd tbg. Tst ann to 2500 psi. Set BPV. ND BOPE, set BPV. NU tree, pull BPV, tst pack-off; OK. Tst tree to 5000 psi. Pull tst plug, circ 35 bbls diesel, followed by 240 bbls crude. SI tbg press = 600 psi. Tst SSSV, Shear out ball, bled tbg to 700 psi. Set BPV. RR @ 0330 hrs, 12/25/84. Standby w/crews, wait on weather. SSSV @ 1881' - PBR @ 7762' - FHL Pkr @ 7775.65' D Nipple @ 7792.48' - TF @ 7804.61' IDate JNew TD PB Depth 8171' PBTD Kind of rig 0330 hrs. 12/25/84 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Tj~tir~ C ~ Production ' ! % , ~,= ~} I O ~ o~/esF Gas per day Pump size, SPM X length Choke size T.P.C.P. Water % GOR Gr - - ~J~o .~.~1~ Effective date corrected ...... ~. m ~a8 ~0~8. C0~J8810~ Anch, rao~ The above is correct Signature ~ IDate JTitle 1/24/85 For form preparation and distribution, see Procedures Manual, Section 10, Orilling, Pages 86 and 87. Drilling Superintendent Dally Weir HIstory - lnithl- Report_ = Alaska IWell no. 2D-14 · i Alaaka North Slope Borough Kuparuk River ADL 25658 ~ or W.O. no. : Ai~ 802891 Drill, Complete & Perforate Parker 191 ARCO Alaska, Inc. Spud6s<l or W.O. I~gun Date, and depth ,i~ of 8:00 i.m. 11/25/84 AP1 50-029-21183 11/28/84 [Hour Complete record for each day reported rA.R. Co'e W.I. P~or ~,. a w.o.56 ' 24Z 9-5/8" @ 3905' 3931', (3821'), Bump plug Wt I0.I, PV 19, YP 18, PH 9, WL 12, Sol 14 Accept rig @ 0630 hfs, 11/24/84. NU diverter sys. Spud well @ 1200 hrs, 11/24/84. Drl, DD & surv 12¼" hole to 3931', POOH to 2314', hole tight. Wsh & rm f/2314'-2508', POOH slow, BHA balled up v/clay. GIR, ta$ bridge @ 2503', wsh & rm to 3931', C&C, sweep hole w/hi-vis pill. RU & rn 97 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3905', FC @ 3827'. M&P 950 sx AS III w/1/2#/sx cellophane flake, followed w/500 sx C1 "G" w/2% S-1 & .2Z D-46. Displ using rig pmps, bump plug. Good rtns. 513', Assumed vertical 668', 4.8°, S39W, 668 TVD, 6 VS, 5S, 4W 1121', 21.7°, S49W, 1107 TVD, 110 VS, 75S, 1420', 31.5°, S46W, 1374 TVD, 244 VS, 166S, 1794', 39.8°, S46W, 1675 TVD, 465 VS, 321S, 2469', 48.1°, S49W, 2151T~rD, 943 VS, 639S, 3307', 48°, 3891', 47°, 80W 178W 337W 694W S5IW, 2711 TVD, 1566 VS, 1035S, 1176W S50W, 3104 TVD, 1998 VS, 1308S, 1510W 9-5/8" @ 3905' 4089', (158'), Drlg Wt 9.0+, PV 6, YP 1, PH 9.5, WL 12, Sol 3 LD lnd'g jr, ND 20" riser & diverter sys. RU & perform top job on 9-5/8" x 16" ann w/40 sx AS I. NU 11" csg head, NU BOPE & tst to 250/3000 psi. RIH to FC, tst csg to 1500 psi f/15 min; OK. DO flt equip & 10' new formation. Conduct formation tst to 12.8 ppg EMW. POOH, LD bit. PU Neyrfor turbo drl & 8½" BHA, RIH, turbo drl f/3941'-4089'. 9-5/8" @ 3905' 7128', (3039'), Drlg w/Turbo Drl Wt 9.3, PV 15, YP 11, PH 10, WL 8, Sol 9 Drl w/turbo drl & surv to 7128'. 4658', 46-1/2°, S50-1/2W, 3629 TVD, 2556 VS, 1663S, 1941W 5596', 45-1/4°, S48W, 4278 TVD, 3233 VS, 2104S, 2455W 6621', 45.5°, S44.5W, 4994 TVD, 3966 VS, 2610S, 2986W 11/29/84 The a~ is corr~ot Oats 12/10/84 DrillinK Superintendent Gas CompanY Daily Well History-final Report ami ~it tl~ "FIaM Relief' De_ Itle'fldll-Wed~tesday afte~ 811owa~e hal ~ ~ or well il Plu~. Ab~, or ~ld. ~ ~ ~ ~ ~ o~~ ~ for ~ Jn~flite or apP~i~e I~ of fiN. On wo~ when ~ oaclll t~ il ~ ~~ ~ c~ ~4 ~~ ~ dM~ in bl~ period. The "F~ ~' fo~ m~ ~ u~ for m~lng the ~tlm District Alaska Field Kuparuk River Auth. or W.O. no. AFE 802891 ICou.~ o. Pa,~ North Slope Borough Lc.. or Unit ADL 25658 Title Drill, Complete & Perforate Parker 191 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun i1/30/84 Date and depth as of 8:00 a.m_ 12/01/84 thru 12/03/84 Complete record for each day reported lAccountlng cost center code State Alaska lWell no. 2D-14 AP1 50-029-21183 I TcOtal number of wells (active or inactive) on tl~is~ Dst center prior to plugging and I labandonment of this well Hour I Prior statue if a W.O. 9-5/8" @ 3905' Alaska 8300', (1172'), POOH on short trip 01/ ~ b'a$ CONs Wt: 9.9, PV 15, YP 8, Pti 9, WL 6.2, Sol 10 ' ~C/~orage' Drl w/turbo drl to 7815', POOH, LD turbine. PO new BHA, TIH, drl to 8300', C&C f/logs, short trip to log hole. 7115', 45°, S41.5W, 5342 TVD, 4315 VS, 2867S, 3225W 7740', 41.6°, S37.5W, 5794 TVD, 4740 VS, 3198S, 3500W 7" @ 8255' 8171' PBTD, ER 10.1 ppg NaC1/NaBr Fin short trip, C&C mud f/logs, POOH. RU Schi, log ~DIL/SFL/GR/SP/CAL/CNL f/8278'-3902', RD Schl. RIH to 8155', wsh & rm to btm, hole tight & packing off. Circ @ 8300', POOH, LD DP & BHA. Chg rams to 7", tst to 3000 psi. RU & rn 206 jts + 2 mkr jts, 7", 26#, J-55 butt csg w/FC @ 8171', FS @ 8255'. Circ 7" csg & cond mud. Pmp 45 bbls 3000 Spacer. M&P 275 sx Cl "G" w/3% KC1 w/.8% D-60 & .2% D-46. Switch to rig pmp & displ w/313 bbls, 10.1NaC1/NaBr. Bump plug; flts held. tIP @ 0600 hfs, 12/2/84. ND BOPE, set 7" csg slips, displ NaC1/NaBr f/top 120' of 7". Instl 11",3000# x 7-1/16", 5000# tbg head w/upper seal assy, tst pack-off to 3000 psi. NU companion flange. RR @ 1200 hfs, 12/02/84. Well not Arctic Pac'd. Old TD New TD IPB Deplh 8171 , PBTD 1 Released rig Date [Kind of rig 1200 hfs 12/02/84 I Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single~ Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data ~f,;~ll 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 ,o see Procedures Ma~ual,~ectlon 10, Drilling, Pages 86 and 87. IDate ]Title 12/07/84 Drilling Superintendent $ UB-S URFA CE DIRECTIONAL SURVEY ~-~ UIDANCE F~ONTINUOUS Company Well Name Field/Location Job Reference No. 69954 Lo~]~ied By: MCBIDB ATLANTIC RICHFIELD COMPANY 2D-14 (647' FNL, $84' FEL, S26, T11N, R9E, UM) KUPARUK, NORTH SLOPE~ ALASKA RECEIVED 1985 Date 11-JAN-85 '?~'"~"~'omputed By: STEVENS ~ S~HLU~B~R~R * ~CT ~I~ECT~G~AL CusTO~IEP LISTINC FnR ~RCO ALASK~o I"C' ~D-14 KUPARUK NORTM SbnPE, AbASKA ?Oh~L bOC~T~O~t TA~GENT[~b= evereo~d dev~at[on and azimuth ~NVE~POL~T~ON~ LIQUEUR VMRmlCAI, SECT)OW~ HORTZ' OIST,' PROJECTED ONtO A TARGET ~Z)MUTH OF SOUTH 49 DEG 44 M)N WEST ARCO aEASKA, TNC. K[!PaRUK NOR?H SLOPE. AbASKA TRUE SUR-SE~ COURSE MERSURED VERTICAL VEPT~CRb DEVTATION AZIMUTH DEPTH D~P?H nEPTH D~G MTN DFG ~N DATE 07 SURVEY= ~7-DEC-84 ~ELLY ~USHTN~ Eb£V~T~ON~ ENGTN~E~I MCBRIDE INTERPOLATED VALUES FOR EVE. 100 FE~T OF MEASURED D~PTH VERTTC~L DOGLEG RECTANGULAR COORDINATES HOR[Z, DEPARTURE SECTION ~EVERI?Y NORTH/SOUTH E~$T/WEST DIST, F~E~ DEG/IO0 FE~T ~E~T FE~T 1~,65 26.56 45.~8 o.ooo.oo -~..o o o. o o ~ 100.00 100.00 '26.90 0 23$ 43 50 W ~oo.oo ~oo.oo ~.~o o ~ ~ ~ ~ . ~oo oo ~.~.~~.~ o 2~s ~ ~ w ~oo:oo ~.~. ~.~ o~ ~ ~ o w 600.00 5q~[~a 473,14 2 49 ~ ~2. 0 w 70.0.00 699,6~ 579,~5 5 49 S 39 40 W 800.00 798.79 67].q8 9 19 S 44 59 W aO0.O0 806.91 770.11 ~3 2 ~ 47 K W .~.~. ~ s~ ~ ~ ~ w ~,.~o 1~44,07 27 29 $ 46 27 W 184.77 1231,39 30 3? R 45 3a W 23~.41 131~.11 ~3 44 S 45 3P W 286.45 1197,03 ]6 7 $ 45 24 W .]43.~3 1477,65 ~8 6 ~ 45 5~ W 404.{0 155~,]6 ]9 59 S 46 21 W 466,~7 1631.05 41 42 S 46 36 w 53?.?7 1000.00 903 4~ 1100.00 10~8 1200,00 11m0 1300,00 ~270 87 1400 O0 1358 19 1~00 O0 144~ 91 1600 O0 ~. 7~ 1700 O0 1604.45 1~00 O0 1682,16 1900 O0 17~7,8~ '~ooo oo ~8{l 4~ ~o4 ~ ~ ~6 2100~00 1902~5~ 1775~71 45 4q 2200 nO 1971,4~ 1~44,62 47 3 ~oo:oo ~o~.~ ,~,~ ~ 4~ ~ ]~oo.oo ~,o~.7~ ~o7~:~, ~7 ~7 oo 2gO0 O0 2373,.62 224~.~2 aS 13 2900 O0 2440.26 2313.46 a~ 15 S 47 0 w 599.91 S 47 57 w 670.95 $ 48 20 w 742.70 S 48 54 W 816.18 K 49 3g w 890.00 S KO 7 w 964.25 $ ~0, lq W 1038.67 ~ 50 34: W 111~.~5 S 50 3~ W 1!.87.~0 S ~0 57 W 77 2~79.q7 aB 19 ~ ~1 22 w 1336.03 10 244'A.39 48 2~ ~ 51 53 W 1411.59 63 2~17.~3 48 10 $ ~1 53 W 1486.90 27 257a 47 a8 0 ~ 51 45 w 1560.~5 10 2646:30 48 6 $ 51 31 W 1634.94 80 2713.00 48 lO S ~1 26 W 1709.36 61 2770,~1 a7 51 ~ 51 19 W 1783,69 85 2~4~,05 47 39 S 51 17 W 1~57.63 34 2~14.54 a7 24 $ ~0 54, W 1031.~6 2~ 2087,43 a6 55 R 50 4a W 200d.73 126.80 FT 3000.00 250~ 3100 O0 ~57 3200:00 2639. 3300.00 ~06 3400,00 73 3500,00 2839 3600 O0 ~906 3700i00 2973 3~00 O0 3041 3o00.00 3109 o.00 0,00 0.00 ~! 0 O0 E 0,00 N 0 0 E 0.72 0.37 0,1~ $ 0:14. w 0,22 S 38 15 W ~.01 0.14 0,73 S 0,71W 1,01 S 44 12 w 1.~5 0.04 1,36 $ 1,27 W 1,86 S 43 I W 2.72 0,0~ 1.90 S 1.87 w 2,73 S 43 19 W ].71 0.77 2.75 S 2.53 w 3,74 S 42 35 W 6.31 '3,3~ 5.00 S 4.0{ W 6.41 S 3~ 40 W 3,14 11,07 S 8,4~ W 13,92 S 37 20~ .... 3.37 20,59 S 17,27 W 26,87 S 39 58 t 4,05 ]3,7~ $ 31,13 W 45,94 S 42 39 w 3.9~ 51,04 ~ 50,4~ W 71.7~ S 44'4i W 3.27 72.12 S 74.82 W 103.99 $ 46 3 W 3 ~. ~ 16o 1,~ s 17o.oo w 23~.~ s 4~ 42 w 3,3~ 1~70{ S 208,21W 2~6 65 S 46 34 W 2,0? 2]7 41S 2~9,11W 344 12 S 46 22 W 2.04 279 55 S 292.32 W 404 47 S 46 ~6 ~ 1.61 323 12 S 317.72 W 467 40 S 46 15 W 1.63 368 11S 385.12 W 532 75 S 46 17 W 2.24 414.51 $ 4~ 39 w 600 43 S 46'20 W 1.63 462.00 $ 4-u:31 W 670 77 S 46 28 W 0.92 510,38 S 540,25 W 743 20 S 46 37 W 0,48 558.95 S 595,38 W 816 64 S 46 48 W 0,75 607,11 ~ 651,3~ W 890 40 S 47 0 W 0,29 654.88 S 708,20 W 964,5~ S 47 ]4 W .3 9 702,5! $ 765,41 w 1038,93 $ 47 27 W ,4n 750.02 S 822~95 w 1113,45. $ 47 39/- 0,02 797,35 S 8~0,60 W ilg7 95 S 47 5~ 0.2e 844,50 S 9]8,36 W 1262:49 S 4~ 0.39 891 36 $ 996 51 W 1336,90 S 48 11 W 0 37 1.029 80 $ 1172 66 W 1560 65 S 4~ 42 W 0:30 1075 97 S 1210 90 W 1634:95 S 48 50 w 0 lO li22 38 ~ 1289 2~ w 1709,3~ S 48 57 W 0~4~ 1168.79 S 1347 43 w 17~3,77 S 49 3 W 0~15 1215,0~ $ 1405 1~ W 1857,6~ S 49 8 ~ 0,53 1261,36 ~ 1462 67 w 1931,43 S 49 13 W i,5~ 1307,78 S 1519,55 W ~004.83 S 40 17 W ARC~ ~E~S~A, TNt. 20-14 KUPARUK NORTH SI, OPE, AhASKA COMPUTATION DATE: g-J~N-85 PACE 2 DATE OF SURVEY: 17-DEC-84 ~ELbY BUSHTNG EbEVhTIONt 126,80 FT ENGINEER: MCB~InE I.TERPO[,ATED VALUES FOR EVEN 100 FEET OF HE~SIJRED DEPTH TRUE SUR-SEh HE~SURED'VERTICAL VE~T~C~b DEVTATION AZIMUTH DEPTH D~PTH ~EPTH D~G MTN DEG 4000.00 ]178,1" 3051.~8 46 1~ 4100.00 3247.44 3120.64 46 17 4200.00 3316.56 3180.76 46 18 4~00.00 3395,64 3~5~.~4 ~6 2~ 4400.00 3454,45 3327,~5 46 40 4~00.00 ~5~3.11 3~96.~3 463~ 4600,00 ~591,96 3465.16 46 2~ 4700.00 3660,§0 3534.09 46 16 4~00.00 3730.14 3603.34 46 5 4900,00 ~709,30 3672,50 46 20 5000.00 3868 29 3741.48 46 24 9937 29 3910.49 46 1.6 5100.00 5200,00 4006 5300,00 a076 5400.00 a146 5~00.00 4216 5600,00 42R7 5700.00 4358 5,00,00 44~8 5900.00 4497 63 3~70,,3 45 59 33 3940.53 45 36 44 4010,~4 45 2~ 80 4090,00 45 1~ 49 4160,6~ 44 55 2~ 4231,43 45 0 17 4301,37 46 18 30 4370,50 46 11 VEETICAL DOflLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NnR~H/SOU~H E~ST/WEST DIST, AZIMUTH F~ET ~E~/lO0 FEET S 50 13 W 2077.13 $ 49 56 W 214~.24 S 49 38 W 2221.50 ~ 49 23 W 2293.79 ~ 49 10 W 2366.35 S 48 3° W 2430.04 S 48 5 W 251!.58 $ 47 47 ~ 2584,02 S 47 24 W 2656.13 S 47 4 W 272~.35 S 46 56 W 2800.72 S 46 4" W 2,73 04 ~ 46 3, W 2045:05 S 46 29 W 303.016'71 87.05 S 46 17 w ~ 46 1~ w 315R.04 ~ 45 56 W 39..29.61. S 45 48 W 3300,19 S 45 40 W 3~71.57 $ 45 35 W 3443.73 6000 00 4566 59 4439,78 46 9 S 45 27 W 351~.73 6100 00 4636 06 4500,~6 45 5~ S 45 21. W 3587.53 S 45 16 W 3659.30 ~ 45 1! W 373!.93 S 44 5~ W 3903 72 S 44 31 W 3,75:03 S 44 13 W 3946.60 S 43 4, W 4017.82 S ~3 4 W 408~,70 ~ 42 29 W 4~59.~7 6~00 O0 i~ 56 4578,76 45 57 6300 O0 89 464,.09 46 14 6400 O0 4844, 14 4717,34 46 7 6~00 O0 4913 5~ 4786,75 45 5~ 6600 O0 4983..1~ 4~56,38 45 44 6700,00 5053~13 4926,33 45 2~ 6~00.00 5193,,36 4~96.56, 45 lg 6900,00 5103,89 5067,0~ 45 ~ S 42 0 W 4229.65 S 41 20 W 4300,06 S 40 38 w 4370.12 S 40 24 w ' 443o.51 $ 39 55 w 4508.38 K 39 23 w 4576.45 $ 38 4R w 4643.ql s ~8 23 w 471o.50 $ 37 43 W 4775.99 S 38 47 W 484~.19 7000,00' 5264 40 5137,60 45 .7100.00 5334 7~00.00 5405 63 5~78.n3 44 30 7300°00 $476 9~ 5350,11 44 20 7400.00 ~548 60 5421.09 43 55 7500.00 5671 13 5494 33 43 21 7600.00 5604 05 5567~5 42 5n 7700 O0 ~767 70 5640,o0 42 13 7~00~00 5842 26 571~,46 .7000,00 ~917.08 5790,)8 0.64 0.47 0.27 0,30 0.36 0.79 0.41 0.54 0,67 0.33 0.25 0,41 0.06 0 4~ O' ,37 0.32 0,26 0,19 0,30 0.2! 0,45 0.14 0.2! 0 4~ oi 0,61 0,70 0,31 0,38 0 56 0.62 0.62 0,46 0 95 1!09 0 79 1.26 13~3,84 S 1575,45 W 2077,24 $ 49 19 W 1400,20 $ 1630,71 w 2149,36 S 40 20 W 1740, 7203'~I i ~I~ , , 49 .67 i '795'~~ : 7366'439. i 49 , ~0~2.1 2656 24 S 49 ~4 {703.11 g 9065,16 W ~7~$~41 S 49 1832,40 S ~118.11 w 7800 18~1,9~ S ~170.9~ W 2873 1931,36 $ 2223,37 W ~945 19~0,64 S 2275.46 ~ 301.6 w 7128,01 S 24.~9.40 W 32~9 2177,23 S 2480,10 W 3300 72~7,06 $ ~53~,34 W 3371 ~277,51S 7583,07 W 3443 ~3~8 2378 ~479 2530 258i 2633 9736 ~7~8 2840 96 '$ 31~4 ~803 84 S 31~1' 32~8 3273 ?947 3000 3053 3106 3159 321.2 3265 3317 70 S 49 8 W 09 S 49 4 W 00 $ 49 I W 73 S 48 57 W 97 S 4, 54 W 95 S 48 50 W 69 S 48 47 W 19 S 48 43 w 57 S 4~ 39 W 74 S 48 35 W 04 S 2634,53 W 35~'5,75 S 4, 32 w 53 S 26~5,74 W 35,7,56 S 48 28 W .09 ~ ~736,86 W 3659,36 S 48 ~4 W 84 $ 2788.02 w 3731,3! S 48 20 W 81S 2839,08 W 3803 33 S 48 17 W 94 S 2889, 75 W 3875:18 S 4~ 1.3 W 24 S 2939.9~ W 3946i 80 S 48 8 W 60 $ ;989;64 W 4018 O~ S 4~ S" 31 ~ 303~. 57 W 4089,04 S 47'59( 47 s 300:67 W 4159,70 S 47 54 'W 26 W 4230 20S 47 48 W 52 W 4300 74 S 47 42 W 00 $ O0 w 4370 97 S 47 36 W 47 $ 49 W 4440 56 S 47 29 W 64 S 3318 45 W 4509 64 S 47 22 W 73 $ 3362 43 W 4577 96 S 47 !5 W 8~ $ 3405 57 W 4645 70 S 47 8 W 68 $ 344.7 80 W 47~2,60 S 47 I W 5 S ~488 8~ w 4778,44 S 46 53 W 7 S 3599,8~ W 4844,09 S 46 46 W ARCO ALASKA, TNC. 2n-]4 KUPARUK NORTH SLOPE, ALASKA COMOUTATInN DATE: 9-JAN-85 PAGE 3 DATE OF SURVEYt ]7-D~C-84 KELLY ~USHTN~ ELeVaTION: 1~6,80 FT I~TERPOT..A?ED VALUES FOR EVEN 100 FEET OF HE~SURED D~PTH TRUE SIJB-SER C0URSF MEaSUReD V~RTICAL VERTZCab D~VTA?ION A~I~UTH DEPT~ D~PTH ~EPTH DEG M~N D~G M~N VERTTCRL DOGLEG R~CTANGULaR COOrDiNaTeS HORZZ, DEPARTURE $~CTI~N ~EVERITY NORTH/SOUTH EAST/WEST D~ST, FEET DEC/lO0 FE~T ~E~T ~E~T ~EC 8000,00 ~902,84 596~ 04 40 6 8100,00 6069,81 594_.~01- ]9 4 8~00,00 6148,30 6021.50 ]7 58 8300,00 6227,1~ 6100,~2 ]7 58 S 39 ~ W 4905.54 S 38 44 w 406~.45 S 39 i w 5020.51 ~ 39 I W 5090.17 1,16 2,00 0,00 0,00 417,65 S 3611,1~ W 4971,97 S 46 ~4 W 3465 8~ $ 3650,0ta W 5033,39 $ 46 28 W ~5~3:63 S 36~,83 w 5094.4? $ 46 ~.3 W ARCh ALASKA, ~NC. 2D-14 KUPARIIK NORTH SLOPE; ALASKA CONPUTATION DATES 9-JAN-85 TRUE SUB-SEA COURSE ~EASURFD VERTICAL., VEST,CAb DEVTATION AZIMUTH DEPTH DEPTH DEPT~ D~G M~N DEG ~N PAGE 4 DATE OF SURVEYt t7=DEC-84 KELLY gUSHTN~ ELEVATIO~t ENG~N~E~= MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASU~ED DEDT VERTTCAL DOGLEG RECTANGULAR COORDINATES HORTZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZTMUTH FEET DE~/~O0 FEET FEET FEET DEG ~I~ 0,00 3.9~ 2.24 0.64 0,2~ 0.45 0.3~ 1,16 ~ 0 0 E 0.00 ~ 49 4 W 7~.60 S 47 0 W $ 5! 2~ W $ 46 56 W 2800.72 S 45 27 w 35t5.73 S 42 O W 4~29.65 S ~9 7 W 4905.54 0.00 O.On -126.Q0 0 0 100o.00 903,49 n66.68 ~6 57 2000.00 1831,46 17o4,66 43 36 3000.00 2506.77. 2]79.07 48 4000,00 3178.I~ 3051.]8 46 5000.00 3868.2~ 3741,48 46 24 6000.nO 4566.5~ 4430.78 46 7000,00 5264.40 5137.&0 45 19 800.0.00' 59g2.84 5R66.o4 ~0 6 126,80 FT 0.00 q 0.00 £ 0.00 N 0 0 E 51.04 S 50.48 w 71,78 S 44 41W 4{4,51 $ 434.39 W 600,43 S 46 ~0 W 8q1.36 $ 996.5] W 1316.99 S 4~ ii W 1353.84 S {575.45 W ~077,24 S 49 ~9 W 1812.49 $ 2118.11 W 9800.7~ S 4~ 8 W ~3~8,04 $ 7614.53 W 35~5.75 S 48 32 W 9840.9A S ]I]4.26 W 4230,20 S 47 48" ]367.9~ $ 3571.0~ W 4908,7~ S 46 40( ARCO 2P-14 KUP~RUK, NORTH SLOPE, COMPU?A?InN DATE= 9-J~N-85 PACE 5 DATE OF SURVEYI 17-DEC-84 KELLY qUSHTNG £bEV~TION= 126,80 FT E~GTN~E~ MCBridE INTERPOLATED VALUFS FOR EVEN 100 FEET OF SUR-SE& DEPTq TRUE ~UB-$E~ COU~$~ MERSI.{RED VERTI~Ab VErTiCAL DEV?ATXON AZIMUTH DEPT, D~PTH ~EPT, D~G M~N D~G 0.00 0.00 -126.~0 0 0 N 0 0 £ 0.~0 26.80 26.80 -lOn. O0 0 5 , 88 58 E 0.00 126,80 1~6,80 0,00 0 27 $ 48 38 W 0.42 O0 0 2~ ~ al 13 w ~26.~1. 276,80 lO0, 326.R! 3~6,80 ~00.00 0 20 $ 44 15 W 426 ~1 426 80 )00.00 0 3~ ~ 42 17 W ~.86 526~m2 5~6~80 400,00 1 4 $ )6 ii W 4,13 ~26.90 6~6,80 ~00.00 3 37 ~ 33 39 W ?.79 727,31 7~6.80 60n.O0 6 3q ~ 41 3~ W 16.58 ~28.42 876,80 70o.00 10 13 $ 46 4 w 030.76 9~6'80 ~On,O0 14 1) ~ 47 47 w lO34.97 1076,8~ o00'00 18 16 $ d9 7 w 8~ 19 1141.90 11~6,80 lo00~00 21 55 S 49 ~ W ll~:B5 1~50 72 12~6 80 1100,00 ~5 36 $ ~7 36 W 167.72 1363~73 ~3~6 80 l~O0.nO ~9 35 ~ 45 lO w 1480,67 1476 80 1300,o0 33 6 S a5 54 w ~7~.78 1607.~7 15~6 80 1400,00 ]6 10 $ 45 2~ w 34~,36 728,~2 16~6 80 l~On,O0 ~8 ]7 S a6 5 w 421.~0 ~58,60 17~6 80 160o,00 40 5~ s 46 31 w 504,91 199],~9 18~6 80 1700,o0 ~3 2~ S a6 5u'w 59~.51 '2134,o8 !9~6 80 1~00,00 ~6 14 S aB 3 W 698.42 2781.~9 20?68o 100o,00 a7 2~ s 48 4~ w 2429,03 ~1~6 80 2000,00 ~7 5] ~ a9 5~ w o1~.18 2579,~9 ~2~680 210o,o0 a8 ~ ~ 50 16 w 1023.49 2729 74 23~6 80 2~00 oO 48 1~ 5 50 35 w 1138.44 2870~78 ~4~6 80 2~00~00 48 13 ' S ~0 5~ W 1~47.75 3030 15 ~5~6 80 2400.00 ~8 20 S 51 35 W 1350.44 3~80~70 26~6 80 2500.00 48 1~ S ~1 53 W 1471.g0 3330.67 ~7~6 80 2600,00 48 3 ~ 51 41 W 1583.41 3480,51 ~8~6 80 2700.00 48 10 S 51 2~ W 1694.86 3630.05 ~9~6 80 2BO0,O0 ~7 46 S ~1 17 W 180~,92 377~.~0 3026. 80 2qO0,O0 a7 ~9 $ ~1 1 W 1915,54 3925,64 3126 80 3000,00 46 39 S 50 38 W 2023.39 4070 ~7 3226 80 3100,00 a6 10 ~ 49 56 'W 2127.71 4714:83 33~6 80 320n,00 a6 18 S a9 35 W 2~37.~2 4359.75 3426 '80 3300,00. 46 33 S 49 23 W 2337.10 4505,33 35~6 80 340n,00 &6 31 .~ 48 36 W 2442.01 4680,60' 3696 80 3~00,00 46 27 $ a7 56 W 2~48.76 479n ~9 37~6 80 3600,00 46 5 $ 47 25 W 265~.67 493~:84 ]826 80 3700,00 46 21 ~ a7 0 W 2757.15 VERT~CAb DOGLEG RECTANGULmR COOgDTNATE$ HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, ~ZXMUTH FEET DE~/100 FEET ~EET FEET DE~ MI~ 0.00 0.00 N 0,00 0.27 0,00 N 0.00 0,23 0,31 S 0.29 0,03 0,90 $ 0,85 0,04 1,52 S 1,47 0,1i 2,16 S 2,04 1,35 3,09 $ 2,78 2,79 6.30 R 4,84 3m 3.3~ 13,37 $ 10,69 3.60 23,93 $ 20, 0,00 N 0 0 E 0,00 N 90 0 E 0.42 S 42 47 W 1,24 $ 43 38 W 2,0a S 43 5 W 2,97 S 43 16 W 4.16 S 41 ~9 W 7,94 S 37 30~" 16.8~ S 3~ 56~ 31,63 S 40 50 W 3.76 3,67 3,3~ 67 O~ 1,70 2 17 2~21 38 71 $ 57 147 ln9 238 291 349 36,49 W 53,20 S 43 18 W 6 S 58,49 W ~2,34 S 45 15 W 7 $ 86,19 W 118,95 S 46 26 W 03 $ 119,06 W ~62,80 S 46 89 W 37 S 157.06 W 215 38 S 46 49 W 58 $ 200 57 W 275 97 S 46 ]7 W 48 $ 250:20 W 345 68 S 46 22 w 88 $ 305:07 W 492 19 S 46 16 W 30 S 365 2] W 505 37 S 46 16 W 5i S 4~1,1~ w 596 0] S 46 20 W 1 21 0 50 0 59 0 20 0,80 0,26 0,56 0.08 478,83 S 550,035 621,44 S 668 692,82 S 753 764,12 S 840 835,00 $ 996 905,40 S 1014 974,88 S 1102 1043,92 8 1190 1113,3~ ~ 1277 505 02 W 695 94 S 46 31 W 585 17 W 803 10 S 46 46 W 27 W 912 56 S 47 4 W 7 2 w 1023 76 S 47 ~4 W 10 W 1135 6? S 47 42 W 65 w 1247 36 S 47 13 W ~359,49 S 4~ 14 W 65 W 1471.,8~ 54 W 1583,41 S 48 451 9~ w ~604,8T S 48 56 W 0 0 54 1 58 0 39 0 27 0 33 0,67 0,26 0,68 0.3~ 1182 70 1251~39 $ 1480 15~4 1319,60 13~6,34 ~ 16~4 !453,78 S 16 4 1592,01 $ 1773 1.591,2] ~ 1853 !661,43 S 1932 17Il 70 $ ~009 1802:79 S $ 1364 81 W 1805 96 $ 49 5 W 36 W 1915 60 $ 49 12 W O0 W 2023 49 S 49 1,7 W 23 W ~127 83 S 49 20 W 09 W ~212 36 S 49 21 W 76 W ?3'37 25 S 49 22 W 78 W 9443 08 S 49 21 W 34 W 9548 39 $ 49 18 W 59 W 9652 7~ S 49 14 W 28 W ~757 23 S 49 10 W COMMUTATION DA?E: g-jAN-B5 PAGE 6 ARC~ AbRSKA, TNt, DATE OF SURV£YS l?-DEC-84 2~-~4 KELbY ~USHTNG EbEVRT~ON~ KUPaRIIK NOR?H St, OPE, ~bRSKA ENGTN~ERI M~B~IDE INTERPOLATED vALUES FOR EVEN 200 FEET OF SU~-SER DEP?U TRUE HUH-SEa COURSE VERTTCAb DOGLEG RECTANGUbRR COORDINATES HORIZ, DEPARTURE MEASURED VER?ICAL.YE~T~CAb DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH D~PTH nEPTH D~G M~N 5084.~1 39~6.80 3~O0.nO 46 572q.02 40~6.80 3900.00 45 53 5372.01 41~6.B0 4nO0.O0 45 26 55~4.17 42~6.8~ 4100.00 45 565~.56 43~6.80 4~On O0 44 57 5798.02 44~6,80 4300:00 46 5949,~2 4526.80 4400.00 46 9 6086.&9 46~6,80 4KO0.O0 45 59 6~30,57 47~6,80 4600,00 46 6174.~9 4876.8~ 4700,00 46 7 65.19 05 4926 80 4~00.00 45 55 666~:43 ~096 80 4000,00 45 34 ~04.89 5126 46.70 52~6 708~.52 53~6 7~29,72 8476 7~69,58 55~6 80 5000,00 45 17 80 5100.00 45 2 80 5~00,00 45 lO 80 5~00.00 44 34 80 5400,00 44 4 80 5500.00 43 20 8o 5600,o0 42 37 80 5700,00 ~1 3~ '7919,92 8044.79 8172.73 8299.59 8300.00 599.6.80 5900,00 41 7 60~6,80 5900,00 39 48 61~.6,80 6000.00 37 5, ~2~6,80 610~,00 37 5~ A2~.7.17 6100.,2 37 5~ DEG MIN FEET S 46 4q W 286~.06 8 46 36 w 2965.q0 8 46 lq W 3068.03 $ 46 1~ W 316~.98 ~ 45 50 W 326~.~2 $ 45 49 w 3370.14 S 45 39 w 3474,44 ~ 45' 2~ W 3577.~7 S 45 ~4 w 368~.24 S 44 5M w 3785.~ 8 44 26 W 388a.68 S 44 1 W 3q91.12 $ 43 2 W 409~.16 S 42 12 W 4192.~.3 ~ 41 34 W 4291.98 S 40 25 W 4t90,76 $ 40 6 W 4487,49 $ 39 20 W 458]..75 S 38 39 W 467~,66 S 37 51 W 4762,52 $ 38 58 W 4~49.57 S 38 57 W 4933 ~8 S 39 ~ W 5017:~7 ~ 39 1 W 5089,92 S 39 1W 5090,~7 9E~/lO0 126,80 FT 0.3? 0.48 0,24 0,15 0,23 0,43 0,25 0.34 0,31 0,51 1874.44 $ 2162.91W 2862,12 $ 49 5 W ~945,69 S 2238,54 W 2965,93 S 49 0 W 20~6,07 S ~312,66 W ~068,05 $ 48 55 W 2085,92 $ ~385.67 w 3168.9~ $ 48 50 W 2155,34 S ~457,58 w 3268 8~ $ 48 44 W ~296.06 $ 95~0.39 W ~370 la $ 49 ~9 N 9299.05 $ ~605,03 W 3474 45 $ 48 34 W 3[ 25'8.06 $ 9896,35 W 37~5 3~ $ 49 '8 W 0,24 0,54 0,6~ 0,31 0,55 0,36 0,73 0,58 0,36 1,01 ~591,71 S 2899,34 W 3888 ~665 31. $ ~971.04 W 3991 ?738 28]2 9887 2962 3037 31S0 3183 3254 .~4 S 3040,93 W 4092 93 S 3108,93 w 41q2 74 $ 3176,12 W 429 2 96 $ 3241,54 W 4391 45 $ 3304,86 w 44~8 88 $ 3365,84 W 4503 47 $ 3424,47 w 4675 30 S 34~0,4~ W 4764 85 $ 48 12 w 36 $ 48 6 w 50 S 47 59 W 6? $' 47 51 W 65 S 47 43 W 66 $ 47 34 W 68 $ 47 24 W 2~ $ 47 15 W 59 $ 47 5 W 90 S 46 55 W 113 1~20 5.89 0,00 0,00 3323,98 S 3535.15 W 4852 44 S 4~ 4~ W 3390.08 S 35R8.92 W 4936:90 S 46 3. w 3452,79 S 3639,5~ W 5016,76 $ 46 30 W 3513.44 S 36~8.67 W 5094,17 S 46 23 W 35~3,63 S 36"8.83 W 5094,4~ S 46 23 W FEET FEET FEET DES MIN ARCO ALASKA, INC. 2D-14 KUPARIIK NDR?H SLOPE, ALASKA ~A~K~R TOP UPPKR SAND BASK [!PPEP SAND TOP LOWFR S~ND B~SE LOWER SAND PRTO TOT~b DEPTH COMPUTATION DATE= 9-JAN-85 PAGE 7 DATE OF SURVEY! 17-DFC-84 KELLY gU~HTNG KbEVATION: 196.80 FT ENGYNEEP: MCBRIDE INTERPOLATED VALUKS FOR CHOSEN HORIZONS M~ASUPED DEPTH BELOW KB SUPFACE LOCATION ORIGIN= 647' FNL, 184' FES, SEC ~6, TllN, R9E, U TVD RECTANGULAR COO~DINA FRO~ KB SUB-~EA NOPT~/SOUTH E~ST/WEST 7B97 O0 7912 O0 7945 OO gln2 O0 ,~171 O0 n300 On 5914.82 57~8,0} 33X5.$2 S 3528.57 ~ 5926.1! 5799.3~. 3)2].52 $ 3534.77 5q51 O0 58~4.2n 3340.]! S 3549 45 ~ 6125.44 5998.64 3a51.~7 S 3~3R.85 W 6227.12 61~0.32 351~.63 S 3688,P3 W( ARC~ ALASKA, TNC. KUPARUK NOR?H SLOPE, ALASKA COMPUTATfON DATES g-dAN-B5 PAGE 8 DATE OF SURVE¥{ iT-DEC-g4 KEY, bY RUSHTNG ELEVaTiON= 126.80 ET ENGTNEER= MCBRZDE ~APK~R TOP UPPER SAND B~SF UPP£R SA~D B~SE [,OWE~ ~A~D P~TD TOT~L DFPTH MEASURED DEPTH REt,OW ~B FROM KB TRUE SUB-SEA MEAStlRE~ VERTICAL VERTTCAL DEPTH DEPTH DEPTH ~3no,on 6227.f, 2 6100,3~ SURFACE LOCATION AT ORYGYN= 647' FNL, 184' FEb. SEC 26, '!'{.iN, R9£, U TVn RECTANGULAR COORD! SUB-SEA NORTH/SOUTH E~ST/WE~T 7Sq7.00 59t4.~2 5798.02 3315.,2 S 3528.57 7912.00 5o26,{1 5799.31 3323.~2 S 3534.77 7945,00 5051..00 5824,20 3340.31S 354~ 45 ~102,00 6071.36 $94.4.5~ 3419,63 S 3611~91 nl?l,0o 6i25.44 5908,64 3451,97 S 3~3~,~5 ~300.00 6~27.12 ~160.3~ 3513.~3 $ 368~.n3 HORIZONTAL DEPARTURE FEET DEG MTN 5094.42 S 46 23 W SCHLUMBERGER ARCO ALASKA. INC. 20- ~4 KUPARUK NORTH SLOPE, ALASKA . DECEMBER ]?, 1984 TVW PLOT FROM OCT DATA ,JOB REFERENCE G99S4 WELL: 2D-14 SURFACE LOCATION' 647' FNL, 184' FEL, S26, T11N, .R9E, UM -~000 -1000 0 '0 N£ .... T"T"T"?-'!'"?T'T'"? V. ERTI CAL PROJECTION 6000 PROJECTION ON VERTICAL PLANE OF AZIMUTH 22B SCALED IN VERTICAL BEPTHS HORIZ SCALE = 1/1000 IN/FT WELL: 2D-14 SURFACE LOCATION' 647' FNL, 184' FEL, S26, T11N, R9E, U.H HORIZONTAL PROJECTI ON NORTH ] 000 REF' 69954 SCALE : 1/1000 IN/FT -~-~--~-i--~--~-.~--~-~- 4--~-~--~-~-.~.-~--;--~, ..-~-~--4---;- i ; ; ~ ~ ~ ~ ~-~-'~--~-'~'~-~--~+-"?'~"'~" '"?~"','"?t"-~"'~'"~'-'~ ..... +'"~-"?'~'~'"~'-~-~'"~ ..... ~ ...... ~.--r-t---~--.~.m-~-+--- ---h~--?i-'ti'-h~'l-ht'-?l'-'ht' i-~-'h?"t'~-'~"-~-i-t-~-~-~t'~-"~'-'hr"t-'~'??l"t-~"'~ !--~---~ "~"i"-h h ? i'"~ ?'i ? 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'' ._Registered Survey Plat y~ 7_.~/./_~._ Inclination Survey '~/F~ ~-~ "' : ' .... ~/~ · Directional Survey ye~.--~ Drill Stem Test Rep~ rts ./~/~ --~ -" ~ : -~~ AlasKa, inc. Post Office r'"-x 360 Anchorage~_.-~ska 99510 Telephone 907 277 5637 Date: 1/03/85 Transmittal No: 4949 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B P.O. Box 100360 'Anchorage, AK 99510 ' ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. / - OH LIS .Schlu~:beTgcT.. -.'.~'- . __ #69826 2W-9:' 12/01/84 #69827 2DJ14 -/'11/3o/84 : Run 1 3522 - 7935.5. Run 1 3871.5-8314 #69823 2X-11 ~1/28/84 Run 1 3078.5-6492.5 /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M D..rill~'ng Geology' Mobil NSK Ops. DISTRIBUTION W. Pasher G. Phillips Sohio Phillips Oil Union J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary O! AllanticRichfieldCompany ARCO Alaska, Inc...,.~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 11, 1984 Mr. C. V. Chatterton Commi s si oner 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' 2D-14 2W-5 2X-11 2D-15 2W-6 2X-12 2D-16 2W-7 2X-13 2E-14 2W-8 15-9 2E-15 2W-9 Also enclosed is a Well Completion Report for 2B-14. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L03 Enclosures RECEIVED AJaska 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 0~ AND GAS CONSERVATION COI~.~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 647' FNL, 184' FEL, Sec.26, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 127' RKB, 90' Pad ADL 25658 7. Permit No. 84-159 8. APl Number 50-- 029-21183 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1200 hfs, 11/24/84. Drld 12-1/4" hole to 3931'. 8-1/2" hole to 8300' as of 11/30/84. Ran OH logs. Ran 7" csg. well & RR @ 1200 hfs, 12/02/84. Ran 9-5/8" csg. Drld PBTD = 8171'. Secured 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 3905'. Cmtd w/918 sx AS III & 500 sx Class "G" cmt. 7" 26.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 8256'. Cmtd w/275 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run D IL/SFL/GR/SP/Cal/FDC/CNL f/8278' - 3902' RECEIVED DEC 1 6. DST data, perforating data, shows of H2S, miscellaneous data NONE Gas Cons. Con,mission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo 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 10404 DRN/MR83 Submit in duplicate MEMORANDUM State of Alaska ~s~.~ o~- ~ ~ ~o~$~v~o~ ~o~s~o~ TO: C. V~,'/'~~terton OATS: November 29, 1984 ~RU:.~ Lonnie C. ~mztn / .... -'g Co~ssioner - FROM: Bobby Fostertc& t Petroleum Inspector FILE NO: TELEPHONE NO: SU BJ ECT: D.31.71 Witness BOPE Test ARCO's 2D-14, Sec. 26, TllN,R9E,UM, Permit No. 84-159. Monday, November 26, 1984: I traveled this date to ARCO's Kuparuk Field'~el~~ N0~--'2D-14 t~ Witness the upcoming BOPE test. Tuesday, November 27, 1984: The test began at 1:30 pm and was ~nc'lu~e~'~'a~- 3:00 Pm.~ '~ ~S the attached BOPE test report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 2D-14. Attachment 02-00IA(Rev. 10/79) O&G #4 5/84 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date //- ~~ ~ ~/ ~r~n~ Contractor ~~~ ~//~asing Set @ ~/-]~ ft. Ri~ #1~/ Representative~~ Location, General ~%>~ Well sig~ General Housekeeping~_~Rig ~ Reserve Pit ~/~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure 1~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ACCUMULATOR SYSTEM Full Charge Pressure ~~r~ psi~ · Pressure After Closure' ]~~ psig Pump incr. clos. pres. 200 psig __ Full Charge Pressure Attained: Controls: Master Remote~~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower KellM Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Choke Manifold ~ Test Pressure ~-~ No. Valves ~ No. flanges Adjustable Chokes Hydrauically operated choke / Test'Time / hrs. Test Results: Failures sin ~sec. min~ sec. Repair or Replacement of failed equipment to be made within ~,~ days and Inspector/ Commission office notified. Remarks:. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Septem. ber 13, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2D-14 ARCO Alaska, Inc. Permit No. 84-159 Sur. Loc. 647'F~-~L, 184'FEL,.Se¢. 26, TllI~, R9E, UM. Btmhole Loc. l168'FSL, l146'FWL, Sec. 26, TltN, RgE, l~%. Dear Mr. Kewin: Enclosed is the approved application for permit to drill th~ above referenced well. If coring is conducted, a One cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska arid their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may pe contacted by a representative of the Department of Environmentaz COnservation, To aid us in scheduling field work, please notify this office 24 hours, prior to commencing installation of the blowout prevention Mr. Jeffrey B. Kewin Kuparuk River Unit 2D-14 -2- September 13, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. W~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandor~ent, please give this office adequate advance notification so that we may have a witness present. Very truly pours, C. V. Chatterton Chairman o f Alaska Oil and Gas Conse~ation Commission BY ORDER OF THE COM~ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. ! . i ARCO Alaska, Inc. Post Office b"~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-14 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2D-14, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on November 21, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewin~ Area Drilling Engineer JBK/JG'tw GRU8/L112 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA"~.~L AND GAS CONSERVATION CC~-~_.<MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 647' FNL, 184' FEL, 5ec.26, T11N, R9E, UM At top of proposed producing interval 1375' FSL, 1383' FWL, Sec.26, T11N, R9E, UM At total depth 1168' FSL, 1146' FWL, Sec. 26, T11N, R9E, UN EXPLORATORY [] DEVELOPMENT OIL E~X DEVEL ~3~_~E~NT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 9. Unit or lease name Kuparuk River Unit 10. Well number 2D-14 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) J 6. Lease designation and serial no. RKB 127' PAD 90' J ADL 25658 ALK 2584 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW. of Deadhorse 2D-15well 60' ~ surface feet 16. Proposed depth (MD & TVD) 8407' MD, 6210' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 647 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 47 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 11/21/84 2724 psig@_ 80°F Surface 3127 psig@. 6074 ft. TD (TVD) SIZE Hole 124" i12-1/4" Casing 16" 9-5/8" Weight 62.5# 36. O# !8-1/2" 7" ,26.0# 22. Describe proposed program: CASING AND LINER Grade I CouplingI Length H-40 / Wel~ J-55 HF]ERW BTC/ 3809' J-55 HF]ERW BTC~ 8371' SETTING DEPTH MD TOP TVD 80' 37' I 37' I 37' 37' I I 36' I I 36' MD BOTTOM TVD 117' I 117' 3846' 3107' 8407' I 6210' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 900 sx Arctic Set III & 500 sx Class G 300 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8407'MD (6210' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2724 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 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2D-14 will be 60' away from 2D-15 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 (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space belo~or C;m~use ~- ' CONDITIONS OF APPROVAL DATE Samples required Mud Icg required I Directional Survey required APl number []YES ~.LXIO []YES ~[NO Ii j~YES [-INO 50-- Permit number Approval date I SEE COVER LETTER FOR OTHER REQUIREMENTS GRUS/PD49 APPROVED BY Forrri 10-401 ,COMMISSIONER DATE September 13, 1984 by order of the Commission Submit in triplicate Permit to Drill 2D-14 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd 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 location, this well will be fracture stimulated. Gas Co~$, ^nchorago t.~' F!ELO. 3000 _ 4000 _ 50.QO. ............. 6000._ .ZOO0 0 KOP. TVQ~500.. TL",Q~ 51~O. DEP=O I~I. ItLD ,.3 DEO . .B~L~EL .P~PJDSI. _ TVD= 1502. rPfl~= t 555 4.5' EOC TVD=i1900 THD=2071 DEP=611 , TOP UONU SND$ TV~-21;~;r THD=2420"DEP=866 .... : AVER/~GE ANGLE ........ 4-Z--DEO .... r--MtN i i : ~ i TDP W SAK SNDS TVD=2727 THD=3287 DEP=1502 ' K-12 TVD=305? TMD*3772 DEP=1857 · ' ' C,~13-' PT' "TVD~.~1'OT'-TMD~3i~-46 DEP= 1 9l 1 . : K-5 TVD-4877 TlqO**S4~r oEP'"'3818 TOP UPPR SNDS TvD-5918 THD'7977 DEP=49~9 .TAEGET CNTR ~TVD-5996 TMD=8092 DEP-5023 BASE ~UP SNDS TYD~6074 TMD~820T DEP-5107 TD (LOG PT) TVD~6210 TMD=8407 DEP-5254 1000 I 2000 3000 4000 : VERTtCAL-~SEOTtON--- - : I I 5000 6000 · , ! , Hf i t~' ' ~ON:TAL PROJECT ! SO~U-£:I I#, = 100~ FEET '----T-- ...... T ....... : · !- ............ _1.0013.___ __2OO0_. _ ................ tOQQ___ ........... L ..... 5DOL i ..~ [ EASTMAN WHIPSTOCK. , : , · ; t 5000 ~000 , .................. i s.48 i 5023' REVI ;ED PROPOSAL ALASKA 1~000 WEST-EAST- -- 2000 I )EG 44 MI N w (TO TARGET) O~INO PT) TARGET CE#TER Tl"ID=8~2 UEST 3776 .1000 o 1 ooo I SURFACE: LOCAl' I ON, 647'' FNL, 184' FEL SEC. ~. T11N. RGEE: SURFACE TARGET LOCAT I OM.'~ !320' FSL. 1320' FWL SEC- 26. TIIN. R~E I Q :~00 _ i 500 : ,~ . . ~00 , · i~oo , · ! _~00 '.~ ,1 O0 ......... ~'~C[l AL ~--'-'"KA, ........... ~NC. ~' ............... PAD '~D. WELL NO~, 13-14-15-16 REVISED PROPOSALS ........ _K_U_?.6.R. UK .F.~. E_.L_D. :__ N__O_R_! _M__S_L_._O_~_E_, A.L__AS__K.&__ _ EASTMAN 'WHIPSTDCK, INC. NOTE, WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW . .__LQQ ........... 2_0O ..... 1~ Alaska Oil & Gas Co~. .... : . : : _~i~ ........... ~~ __. / i . i ~ ~ " lO0 25OO 2600 27OO 2800 2900 3000 3100 3900 :~-~-----.---...~ NORTH 3800 //~700 3600 35'1:~,,,. 3400 3300 3200 s]oo ~000 2900 ,,/,,,,, %,, , , ,, , ~~ ~ ~'~ --! / ~ ( ARCO ALASKA. ~INC. ~ ' PAD 2D. NELL NO 14 PROPOSED Surface Diverter System 16"-2000 psi Tankco starting head. Tankco qu)ck connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 ps( drilling spool n/lO" side outlets. lC" ball valvess hydraulically actuated~ w/lC" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary~ manually override and close ball valve to upwind diverter line. Do not shut in ~ell under any circumstances. 16" Conductor r DIAGRAM ~1 !3-5/8" 5000 PS] RSRRA BOP STACK !~3 2 1. lB' - 2000 ~si Tankco s:a~ing hea~ 11' - 3000 psi casing hea¢ 3. 11' - 3000 psi x 13-5/8' - 5000 psi s=acer soool 4. 13-5/8* - 5000 psi x 13-S/8' - 5000 psi Oriiiing spool S. 13-S/8' - $000 psi pipe rams 6. 13-5/$' - 5000 psi drilling spool w/Choke and kill lines 7. !3-5/8' - 5000 psi' pipe ran~ 8. !3-5/$' - 5000 psi blinU 9. 13-5/8' - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WiTH HYDRAULIC fLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WiTt~ 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE RDwIAINING AFTER /:4.L UNITS ARE CLOS:"D Wi194 Ci,6~RGING PbgMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND i200 PSI RDwLAiNING PRESSURE. !3-5/8' BOP STACK TEST .... 1. F:ILL 50P STACK AND ~ILI~IIFOLD WITH AR~IC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY R-~PJtCT- ,,~. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLNE, kD. RUN iN LOCK DOWN 5CROWS IN HEAO. ,q. CLOSE ANNULAR PREVENTER AND L:AJ~'v~S TLJ'D~! Ol: ~I~S. '> DON~T TI~ST AC~kINST C:IJE)S~ CI-)D~S ~. TEST ALL C~PONENTS TO ZS0 PSI AND HO~'FOR MINUTES. S. .INCREASE PRESSURE TO 1800 PSI AHD HOLE POR l0 .MINUTES. BLEED TO ZERO I~SI. ~ 1 ~. OPEN ANNULAR PREVENTER AND CLOSE TOP ,ET OF RAJAS. 7. iNCREASE PRESSURE TO 3000 ~Si AND HOLD FOR 10 B. T z]-?P ssu DO ST OF SOLXTIO V.~q~L¥1~S. TO ZERO PSI TO TEST VALVES. TEST RE~A!NING uNTESTED .~NIFOL~.VALVES, iF ANY, WITH 3OD0 PSi UPSTREA~ OF VALVE AND ZERO PSi DOWNSTREAm. BLEED SYST:-~, TO ZERO PSI. g. OPEN TOP SET OF PiPE RAJaJ AND CLOSE DOTTOM .ET OF PIPE RAJAS. 10. INCRE. A~E PRESSURE TO 3000 PSi AND HOLD FOR MINUTES BLEE~ TO ZERO PSi. 11. OPEN BOTFC)~ SET OF PIPE RAP.S. BACK OFF RUNNING JOINT AND PULL OUT 0F HOLE. CLOS~ BLIND ~S AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED T0 :~R0 PSI. 12. OPeN BLIND ~ ~D RECOVER TEST PLUG. ~ SURE ~NIFOLO ~D LINES ARE ~LL OF ARCTIC ~ES~L AND ALL VALVE5 ARE S~ iN DRiLLiNG POSITION. 13. T~ST STANDPIPE VALVES T0 3000 PSi. ~ F.-~ ~ [ ~ TEST K~LLY COC~ AND INSIDE BOP T0 3000 PSi FO~ SIGN AND SEND ?0 DRILLING SUPERVISOR. ~,~O 0 ~} i~[~ 1~ PERFD~ C~PL~ BOar TEST ONCE A wEEK AND FUNC- ~:'~ ~,: . -. TION~LT OPE~T[ BOP[ DAILY. Alaska 0~1. & g~s Co~s. ARCO Alaska, In¢ Post Office -,.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 2D Pad Wells 1-4, 13-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L25 Encl osure J U L 1 z~!aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ',I. DRILL IT£ 2. D CONDUCTORS ' t AS- BUILT LOCATIONS ~]lJl WELL | Y: 5,954,045.15 Lot, 70017'07.8822'' . _ ; X = 529, 129.90 Long. 149¢45'51.288'' ~ ~ 153' FNL, 656'FEL EL. 89.7',G~ 86.1' , , .-. , ~ WELL 2 Y =5,954,082.31 L0,.70°~7'08.5185,' [ ~ X = 5~9~089.~4 Long, 1490~5'5Z.468'' [ ' . ~' 109' F NL ~ 677'FEL EL BD.6', O.G. 86.~' '~' WELL 3 Y = 5,954,153.42 L~t. 70°17~08.7~8'' , ~ X= 5~9~048.58 Long. 149045'53.64B'' ......... 65' FNL, 71T'FEL EL. 89.7', O.G. 86.1' , .__ , , ... WELL 4 Y= 5,954,177,42 Lot, 2' X= 5~9~008.~ L~.t49°45'54.822'' Z~ .... 21' FNL;7~7'FEL .. EL. X= 529~6~4.74 D.S 69~' FNL, t44' FEL EL. 89.6 WELL 14 Y, 5,953,552.61 Lut. 70°17'0~.0g~4'' X= 529~584.2~ L~. t49°~5'~8, r08'' 647'FNL, I~'FEL EL. 89.8',0.~, 86 WELL I5 y = 5,953,596.~ L~t. 70el7'03.4564'' X = 5~9~545.57_ Lo~. 149°~5'~9.287 603' FNL, 225'FEL EL. 89.6', O.G 87. I' ~-ELL ~6 Y · 5,953,640,81 L~t. 70°~7'05.89t0'' X = 529, 503.~ L~g. 149°45'40.464" j 559'FNL, 265'FEL EL. 89.5', 0.G.86.5' - , i ~l _ _ . . · I.L.~ CONDUCTORS l-~& i3-t6 AS B.U LOCATED IN PROTRACTED SECTION 26 ,JUL I i ~ :A BASIS OF ELEVATION IS TBM 3D-18~ BASIS IS ~NUMENT$ ~O NORTH a ZDSOUTH PER LHO ~ ~ ELEV. TAKEN AT TOE OF PAD~S.W. OF WELL .... DAVID FILUCCI 527G- ................. ~ I H~REBY C[RTIFY THAT ...... [ ' ' --~ ~ ~ D ~ ~ACTICE LAND SURVEYING IN THE ~ATE OF ARCO Alosko, Inc. .s.z-~ ~~~~ ~NDUCTOR AS' BU J LT ~ATIONS i i i i O,S. ~-D LOC~TION O~t~on~ J.~. ~ ~.n~=N~ 9.05~"' Lease & Well No. /~_ CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE (1) Fee ~~- ~- ¥-~% / (2) Loc ( thru 8) (3) Admin -' ~ - q~ ~ ( 11) (10 and (4) Cas~ ~,~# ~'-~-o~r'~/' (12 thru ~0) . . 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. YES NO Is the permit fee attached ......................................... Is well to be'located in a defined pool ....................... Is well located proper distance from property line .................. Is well located proper distance from other wells ............... Is sufficient undedicated acreage available in thi; ;o;{ .. Is well to be deviated and is well bore plat included ............... ~._ __ Is operator the only affected party .................... Can permit be approved before ten-day wait . Does operator have .a bond in force .................................. Is conservation order needed a ... .................................. Is administrative approval needed ................................... 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 .... [ [ . .. l/U-Il Will all casing give adequate safety in collapse, tension and burst.. #~7~ Is this well to be kicked"off from an existing wellbore ............. H~ Is .old wellbore abandonment procedure inclUded on 10-403 ............ 11 b d ~-/~ Is adequate we ore separation propose ................ ........... REMARKS (21 thru 24) 21. 22. 23. 24. Is a diverter system required ..... ........ ~ Are,necessary diagrams of diverter and BOP equipment'attached . Does BOPE have sufficient pressure rating - Test to 3/D-D-D psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: ~T~ ~-~-~ 25. Additional requirements ............................................. ~/~ · Additional Remarks: R2~A "%~)-/~ ~/~ ~- ~)~;2.~-~ ,,~,E',~,~'z~,~,~, ,,~ ~-/~ ~-/~ ~/~ ~ 0 ~'~ O3,--3 I--I Geology: Enmineerinm: WVA ~ JKT~ HJH ~ J,AL ~~ / '' rev: 12/08/83 6 .CKLT INITIAL GEO. UNIT ON/OFF · POOL CLASS STATUS AREA NO. SHORE ~,~,~o ~v /-~,'[ $~- i11~,o 0,,u 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. 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