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182-201
• • Q N11 N N � � >, O . . . . . . . r r r r r r r r CO N U o > � � 3 � � o > h ro 0 Iow- � � _Y o o v E v u a` a c o + v o a.) c s +-) ro +-, to 'E +_ 'o a = 3 H st ❑ o o v T co Q 0 -1 w o co 0o co co 0o o co co 0o co co 0o 0 00 +., O Oa a m J 0 r _c a) U Q i- O a ra w R > to m CO Al R R 03 R (Ta R E -O 0 Z Q t r-- M M t0 h 00 O O N M . 1n .- O O . . . . . . r '13 cz QZ Q 0 v a, E u O C F 1- ( u +' to O 000000000000000 C L aJ 0 L. a0 J J J J J J J J J J J J J J CA C `�- O y W W W W W W W W W W W W W W W N C F- LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL ,„ a) al a) 73 Q J J J J J J J J J J J J J J J Q' > Y Cl.) I- Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q a) 0 C ZZZZZZZZZZZZZZZZ Z Ut0 CU N `- 0 LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL K _0 c >> TO > v I L CO p z Q HI -" O C m ° ~ o o p I i5 v d _ Q ai a tr, C a N v LL 3 cq 0 o p t Q a o 0 d a _, a � a `t c 0 LLO H '� J a J i Kgtt • • pris Regg, James B (DOA) From: Buck, Brian R <Brian.R.Buck@conocophillips.com> g I IQ Sent: Saturday, April 28, 2018 12:01 AM 1 To: DOA AOGCC Prudhoe Bay Cc: Doyon 14 Company Man; CPA Wells Supt;Ward, Dusty K; Eller, J Gary Subject: Notification of BOP use on Doyon 14 on 4.26.18 Attachments: 1G-07 BOPE Letter 4 26 18.doc Please see the attached document in response to Bulletin 10-003 in order to document the use of BOP equipment on 1G-07. Please let me know if you have any questions. Thank you, Brian Buck Completions and Workover Supervisor office:907-265-6826, cell:907-223-6320,fax:918-662-6213;700 G St.,ATO-1340;Anchorage,AK 99501 SCANNED ,, 1 Nov IP • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 27,2018 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003,this letter is to follow up the email notification of BOPE usage on Doyon 14 with a written report.This report is being submitted for completeness in order to close out the original email notification on 4/26/2018. Time of BOPE Use: 4/26/2018 at 16:12 hours Well Location: 1G-07 API Number: 50-029-20872-00 PTD Number: 182-201 Rig Name: Doyon 14 Operator Contact: Brian Buck. (o)907-265-6826.(c)907-223-6320.Brian.r.buck@conocophillips.com Operations Summary: On 4/26/18 at 16:12 hours,the annular was shut in to bullhead 9.1 ppg brine in order to kill the well that was showing indications of flow. The initial casing pressure was 80 psi. Final casing pressure built to 120 psi. Pressure was bled,resulting in a 6.2 bbl gain. The well was shut in and pressure built to 20 psi in 10 minutes. The well was then bled off,resulting in a 5.4 bbl gain. The well was shut in a third time,resulting in a 15 psi pressure build in 10 minutes. When the pressure was bled, a 5.2 bbl gain was realized. The well was shut in once more and pressure again built to 15 psi. The pressure was bled and 4.7 bbls were gained. While this was happening, the fluid system was weighted up to 9.2 ppg. Then at 18:30 hours,9.2 ppg fluid was circulated and the well was observed to have 11 bbl/hour losses. At this point,the rig resumed pulling the fish out of the hole. The annular was retested on 4/27 when the fish was pulled to surface. It was tested to 250 psi and 2500 psi. BOPE Used: Annular Reason for BOPE Use: The annular was closed to determine if we had wellbore breathing. Actions To Be Taken: The annular was retested on 4/27/2018 from 0500 to 0715,and the fluid was weighted up from 9.1 ppg to 9.2 ppg. If you have any questions or require any further information,please contact me at 265-6826. Sincerely, Brian Buck Completions and Rig Workover Supervisor CPAI Drilling and Wells • Regg, James B (DOA) From: Doyon 14 Company Man <doyon14cm@conocophillips.com> Sent: Thursday, April 26, 2018 6:10 PM To: DOA AOGCC Prudhoe Bay Cc: Buck, Brian R; Eller,J Gary;Ward, Dusty K; CPA Wells Supt Subject: 1 G-07 Closure of Annular for deciphering Breathing All, At 16:12 hrs on 4-26-18, Doyon 14 shut in the Annular to attempt determine if the Kuparuk A/C sands were ballooning, do to intermittent well flow after completion retrieval. When The fish is recovered we will test the Annular at 250/ 2,500 psi Randy Dolcater/ Robert Finkbiner Doyon 14 Rig Supervisor Office/Doghouse: 907-670-6130 1 tiOF Tit • I//yy.s THE STAT9 Alaska Oil and Gas ���►.`��i�l, OfA AS K ^ Conservation Commission 333 West Seventh Avenue ,�;, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF"�++mrr" Q. Main: 907.279.1433 .ILAS� Fax: 907.276.7542 www.aogcc.alaska.gov Dusty Ward Sr. Wells Engineer scow . ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-07 Permit to Drill Number: 182-201 Sundry Number: 318-099 Dear Mr. Ward: 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, P Cathy . Foerster Commissioner v�- DATED this 2- day of March, 2018. 3BDMS..0MAR 232018 • • RECEIVED STATE OF ALASKA MAR ALASKA OIL AND GAS CONSERVATION COMMISSION 3.ri 23 APPLICATION FOR SUNDRY APPROVALS O C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 ' Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 0 ,Cve, Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill E Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: CTD Setup/Cement❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inca Exploratory ❑ Development 0' 182-201 ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-20872-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? N/A ' KRU 1G-07 ' Will planned perforations require a spacing exception? Yes ❑ No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25640 . Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ✓S Plugs(MD): Junk(MD): 8,851' 7,024' 8231 6598 1976psi NONE 8357 Casing Length Size MD TVD Burst Collapse Conductor 49' 16" 79' 79' Surface 2,457' 10 3/4 2,487' 2,367' Production 8,808' 7" 8,836' 7,013' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7894-7946,7978-8013,8217- 6356-6394,6417-6443,6588- 3.500" L-80/J-55 8,097' 8238.8253-8273' 6602.6613-6627 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER FHL RETRIEVABLE PACKER MD=5493 TVD=4514 • PACKER-BROWN HB RETRIEVABLE PACKER MD=7723 TVD=6229 • PACKER-BAKER FB-1 PERMANENT PACKER MD=8066 TVD=6481 • 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service 0 14.Estimated Date for 4/7/2018 15.Well Status after proposed work: A , '% Commencing Operations: OIL J • WINJ ❑ WDSPL ❑ Suspended �CJ[*2\1\ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Contact Name: Dusty Ward Authorized Title: Sr.Wells Engineer Contact Email: Dusty.Ward@cop.com �j Contact Phone: (907)265-6531 Authorized Signature: / Wf Date: 3 '" 2.- b I S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J — D Plug Integrity ❑ BOP Test IV Mechanical Integrity Test ❑ Location Clearance ❑ • Other: Ldp r- i- to Z 5b0 r5� t5� to ? r,0 o �='.S 5 ,f} - v/e r pre v e"vi�`r� Post Initial Injection MIT Req'd? Yes ❑ No V Spacing Exception Required? Yes ❑ No V Subsequent Form Required: ,do 4,0 7, APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: 3 _2:2. ...13 1 .3,�13 X147((f 0-2-3'201 G I N A RBonns.Y' MA Form 10-403 Revised 4/2013 MI 0 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 9 March 2018 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 76 Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Producer 1G-07(PTD#182-201). Well 1G-07 was drilled and completed in January of 1983 by Parker 141 as a Kuparuk A/C1 sand producing well. The A-sand was stimulated with a fracture treatment in July of 1984.In September of 1988,the upper completion was pulled and replaced to perforate the Kuparuk C3/4-Sands.The well was shut-in January of 1993 due to high water cut,then was returned to production in September of 1997.In February of 1998,a permanent patch and a 2.25"nipple reducer was set due to a tubing leak across GLM#5.In 2001,the production flowline was twinned with 1G-08.This was removed in 2015 after a PPROF verified no A-sand production.The well failed a proactive T1FL in May of 2016 which led to a HEX plug being set and tubing leaks identified at 5,670'MD and 7,198'MD leaking at 1 BPM.The well was worked over in October 2016 to replace the leaking tubing.Due to pulled tubing condition and casing scale concerns,a packer was conservatively stacked high at 5,493'MD with 3-1/2"tubing ran down to previously placed packer at 7,723'MD.In 2018,scale build up in the tubing and a caliper showed an apparent hole in the lower producing 3-1/2"tubing at approximately 8023'MD. This well is a CTD candidate and a cemented 4-1/2"liner is desired for kickoff points in the old lower selective of the C sands around 7900 MD.The planned workover scope includes pulling the entire 3-1/2"completion down to the pre-rig cuts,setting a 7"bridge plug across the entire casing,and then re-completing the lower section with a 4- 1/2"cement scab liner from approximately 8023' MD up to a packer set around 5500'MD.Final upper 4-1/2" tubing will be completed with gas lift completion to surface. If you have any questions or require any further information,please contact me at 265-6531. Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells gorQ o� � „tet( h¢s droti rc� r 0 0 ''ty C��Cd�. rroctvch'o^ f' 406.4 aK� CO- dt g776 p rr err afi Cyc/y T ' c.-e/( h rte#17011 r�,f (.4/, fog fe r, Shaka vPry ri—r( brncfrt . / re COvt,r) *0'4 T`C /4e 1/S4 � • 1G-07 RWO Procedure • Kuparuk Producer CTD Setup PTD#182-201 Remaining Pre-Rig Work 1. Chem cut the tubing just above the composite at 8,022'. 2. Chem cut the tubing nominally at 7732' MD in the middle of the first joint below HB packer. 3. Pull the DV from GLM#4 at 5421' RKB. 4. Check and grease tree valves within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU on 1G-07. 2. Record shut-in pressures on the T& IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT.Verify well is dead. 3. Set BPV, ND Tree, NU BOPE and test to 250/2,500 psi.Test annular 250/2,500 psi. Retrieve Tubing, Packers,and Blast Ring Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2"tubing to first packer(5479' MD). 6. Pull first packer with 3-1/2"tubing down to second packer(7706'). 7. Pull second packer and tubing down to second pre-rig cut(7732). 8. Washover tubing section blast rings to clean up. 9. Pull 3-1/2"tubing and blast ring section down to first pre-rig cut(8022') Clean out hole and set 7" Bridge Plug 10. Perform a Cleanout run. 11. Set 7" Bridge Plug as low as possible above the first pre-rig tubing cut(-8020'). Install and Cement in 4-'A"Tubing for CTD Set Up 12. MU 4%2" lower completion with packer. RIH and correlate completion so Kick Off Joints are at correct depth. Confirm new tubing tail is at least 5'above 7"bridge plug to allow adequate cement circulation. 13. Prepare cement job per cement contractor procedure.Pump 15.8 ppg class G cement job into the inner annulus between the 7"bridge plug(-8023')and the packer( 5493). Bump plugs.Set packer.Clean up cement. 14. Install 4-1/2"upper completion from newly set packer("'5493)to surface with gas lift configuration. 15. Pressure test tubing to 3000 psi for 30 minutes on chart. 16. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 17. Confirm pressure tests,then shear out SOV with pressure differential. 18. Install BPV. 19. ND BOPE. NU Tree. Uninstall BPV. 20. Freeze protect well. 21. RDMO. Page 1 of 1 • • 1G-07 Proposed RWO Schematic for CTD Setup 16"65#H-40 shoe @ 79' MD PRG. .;OMPLETION 4-1/2" 12.6#L-80 tubing 4-1/2"x 1"KBG-2 gas lift mandrels as needed 4-1/2"x 7"ZXP Liner Top Packer @-5499'MD Flex Lock Liner Hanger 10-3/4"45#K-55 shoe _ Baker SBE @ 2487' MD DB landing nipple(3.813"ID)(w/Centralizer) CTD KO joints 7884'-7966'(assumes 40'jnts) A4U 4-1/2" 12.6#L-80 tubing (10' pup w/Centralizer) 5 4-1/2"Landing collar(w/Centralizer) e 4-1/2"Float collar(w/Centralizer) " " 4-1/2"Float shoe(w/Centralizer) rid „ , KOP@7900'MD Q a ofi 'S5, 1 ..o`r 7”Bridge Plug 8020' MD ',VI* � �b� REMAINING 1988 COMPLETION LEFT IN HOLE ` a`; 1Baker FB-1 Packer @ 8066' MD(4" ID) Baker SBE @ 8069'MD (4" ID) C-sand perfs d) — — 7s 4 as a y.;N=;.. 7894'-7946' MD — — Camco D landing nipple @ 8084'MD (2.75" ID) 7978' 8013' MD - — -Currently Nipple Reducer installed (2.25"min ID) a.' x 1 mmammummige 30;0 7"13P A-sand perfs ;uoaed)E %ei��� .••ea 8217'-8238' MD 8253'-8273' MD "„""„ 7"26#K-55 shoe @ — 8836'MD KUP INDfix 1G-07 ConocoPhiliaps �, Well Attribut Max Angle TD II Wellbore API/UWI Field Name Wellbore Status ncl(1) MD(ftKB) Act Btm(ftKB) Alaska)I t lir 500292087200 KUPARUK RIVER UNIT PROD 47.15 8,600.00 8,851.0 CorroKnPFtillips Comment H2S(ppm) Date Annotation End Date KB-GM(ft) 'Rig Release Date ... SSSV:NONE 55 11/20/2016 Last WO: 10/20/2016 I 29.99 1/14/1983 15-07,3/8/2018 925:42 AM Last Tag Verppalaphamaac(,actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag.SLM 8,231.0 10/28/2016 pproven HANGER,23.7 - Last Rev Reason illi Annotation End Date Last Mod By „,,,,,,,,,,,“,..u..o..,.r..,.uu.yr, 6, ,I'g ."Rev Reason H2S,"apparent split/multiple holes"in joint 240 1/11/2018 pproven Casing Strings ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 30.0 79.0 79.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -,....CONDUCTOR;30.0-79.0- SURFACE 10 3/4 9.950 29.7 2,487.0 2,367.0 45.50 K-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 28.0 8,836.1 7,013.5 26.00 K-55 BTC • Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(IWft) Grade Top Connection TUBING-Upper Gas 3 1/2 2.992 23.7 5,490.5 4,512.2 9.30 L-80 EUE 8rd SURFACE;29.7-2,487.0. Lift Completion Ai Completion Details GAS LIFT;2,895.8 Top(TVD) Top not Nominal 111 Top(ftKB) (ftKB) C) Item Des Com ID(in) I 23.7 23.7 0.02 HANGER Cameron 7 1/16 x 3 1/2 Gen IV N-FBB Tubing Hanger 2.992 5,477.9 4,502.6 40.63 LOCATOR Locator 3.000 ii 1315 5,478.9 4,503.4 40.63 SEAL ASSY 'Baker 80-40 Seal Assembly 3.000 GAS LIFT;3,975.2 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft...Set Depth(WD)(...Wt(1Wft) Grade Top Connection Stacked Packer 3 1/2 2.992 5,479.8 7,717.6 6,225.7 9.30 L-80 EUE 8rd Assembly Completion Details GAS LIFT;4,887.8 C; Top(TVD) Top Incl Nominal Top(ftKB) (ftKB) (°) Item Des Corn ID(in) 5,479.8 4,504.0 40.62 PBR Baker Polish Bore Recptical 4.000 I ; 5,493.1 4,514.2 40.54 PACKER Baker 3%x 7 FHL Retrievable Packer Pinned to shear @ 60k 2.960 GAS LIFT;5,421.5 _ 7,655.9 6,179.5 41.43 NIPPLE Camco 2.813"DS Nipple 2.813 7,704.9 6,216.2 41.64 LOCATOR Locator 3.000 II 7,705.7 6,216.8 41.64 SEAL ASSY Baker 80-40 Seal Assembly 3.000 LOCATOR;5,477.9 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft...Set Depth(WD)(...Wt(lb/ft) Grade Top Connection SEAL ASSY;5,478.8 - ORIGINAL LOWER 41/2 2.867 7,708.8 8,097.2 6,503.1 9.20 J-55 BTC PBR;5,479.9 COMPLETION PACKER;5,493.1 _ Completion Details Top(TVD) Top not Nominal Top(ftKB) (ftKB) (°) Item Des Com ID(in) 7,708.8 6,219.1 41.65 SBR BROWN PRB(PINNED FOR 30K SHEAR) 2.813 GAS LIFT;5,548.8 111 7,722.5 6,229.4 41.67 PACKER BROWN HB RETRIEVABLE PACKER 7"x 3 1/2" 3.000 7,888.9 6,352.8 43.06 BLAST RINGS 59'BLAST RINGS 2.867 7,953.2 6,399.5 43.57 BLAST RINGS 44'BLAST RINGS 2.867 8,039.9 6,462.1 44.15 NIPPLE OTIS X NIPPLE 2.813 8,063.8 6,479.2 44.32 SEAL ASSY BAKER SEAL ASSEMBLY w/5'SEALS 3.000 8,064.7 6,479.8 44.32 LOCATOR BAKER LOCATOR 3.000 8,066.0 6,480.8 44.33 PACKER 'BAKER FB-1 PERMANENT PACKER 4.000 _ 8,069.4 6,483.2 44.36 SBE SEAL BORE EXTENSION 4.000 :4"-ii. ` 8,084.5 6,494.0 44.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,096.2 6,502.4 44.54 SOS BAKER BALL SEAT SHEAR SUB,ELMD TTL @ 8100 during 3.000 PPROF on 4/19/2006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCATOR;7,704.9 IMP op(WD) Top loom _ Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) SEAL ASSY;7.705.7 1 7,848.0 6,322.8 42.49 HOLE IN FROM CALIPER"apparent split/multiple holes"in joint 1/10/2018 0.000 SBR,7,708.8 TUBING 240 pp p p PACKER;7,722.5 $,6$4.4 6,493.9 44.46 NIPPLE NIPPLE REDUCER 2/6/1998 2.250 PRODUCTION;7,780.3 REDUCER 8,357.0 6,685.6 45.93 FISH A-2 Blanking Plug 8 Junk Basket Left in Tailpipe below 9/5/1988 0.000 PRODUCTION;7,839.9 Lt.-1(11'<y milled up PKR; See HandOver Form 9/6/88 HOLE IN TUBING;7,848.011Perforations&Slots Irr Shot Y Dens ry Top(TVD) Btm(WD) (shotstft APERF;7,894.0-7,9480 Top(ftKB) Btm(ftKB) PCB) (ftKB) Zone Date ) Type Com 7,894.0 7,946.0 6,356.5 6,394.3 C-4,C-3,1G-07 9/1/1988 12.0 APERF 120 deg.Phasing I APERF;7,978.08,013.0 7,978.0 8,013.0 6,417.5 6,442.8 C-1,10-07 9/1/1988 16.0 APERF 12 @ 120 deg 4 @ 90 8,217.0 8,238.0 6,587.7 6,602.5 A-4,1G-07 1/14/1983 12.0 IPERF 120 deg Ph;GeoVann TCP Aff 8 8,253.0 8,273.0 6,613.0 6,627.0 A-3,1G-07 1/14/1983 12.0 IPERF 120 deg Ph;GeoVann TCP PRODUCTION;8,030.7 Mandrel Inserts NIPPLE;8,039.9 St ati SEAL ASSY;8,063.8 - on Top(WD) Valve Latch Port Size TRO Run LOCATOR;8,084.7 NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn _ 1 2,685.8 2,511.9 Camco MMG 1 1/2 GAS LIFT 'GLV RK 0.188 1,274.0 10/24/2016 PACKER;8,066.0 - SBE;e,089.4 I 2' 3,975.2 3,412.8 Camco MMG 1 1/2 GAS LIFT 'GLV RK 0.188 1,271.0 10/23/2016 NIPPLE REDUCER;8,084 4Mk NIPPLE;8,084.5, A.W 3 4,887.8 4,063.9 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 10/23/2016 SOS;8,096.2 4 5,421.1 4,459.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/19/2016 (PERF;8,217.0-8,238.0-, 1 5 5,546.6 4,554.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/19/2016 I I !PERF;8,253.0-8,273.0- ( I 6 7,760.3 6,257.6 MERLA TPDX 1 1/2 PROD DMY RM 0.000 0.0 2/25/1993 close d FISH;8,35/.0 1 1 .' 1 7 7,839.9 6,316.8 MERLA TPDX 11/2 PROD CV RM 0.000 0.0 7/26/2007 Open 8 8,030.7 6,455.5 MERLA TPDX 11/2 PROD CV RM 0.000 0.0 7/26/2007 Open PRODUCTION;28.0-8,836.1- KUP POD • 1G-07 ConocoPhillips z • At .Inc. co/WO/I-Alps ..••- 1 G-07,3/8/2018 8:25:43 AM Verticals homaNF(aohal)....... HANGER;23.7 I:.. /,:1 Notes:General&Safety End Date Annotation 9/5/1988 NOTE:WO -".."-•CONDUCTOR;30.0-79.0 ],„6--......6/9/2001 NOTE:CVs @ 7840'8 8031 RKB slightly eroded 2/7/2011 NOTE:View Schematic w/Alaska Schematic9.0 10/20/2016 NOTE:WO 10/28/2016 NOTE: UNABLE TO PASS 7821'SLM WITH 2.67"MAGNET.MADE 2.74"LIB RUN TO SAME 1 10/29/2016 NOTE:(INCONCLUSIVE IMPRESSION)....RETURN AT LATER DATE TO TROUBLE SHOOT OBSTRUCTION SURFACE;29.7-2,487.O-.. GAS LIFT;2,885.8 GAS LIFT;3,975.2 M114 GAS LIFT;4,887.8 7.4 GAS LIFT;5,421.0 MIN LOCATOR;5,477.9 WM SEAL ASSY;5,478.8 PBR;5,479.8 .aaw.a PACKER;5,493.1 -'U II GAS LIFT;5,548.8 gli MB LOCATOR;7,704.9- WM SEAL ASSY;7,705.7` SBR;7,708.8 PACKER;7,722.5 ■ I PRODUCTION;7,780.3 I ill PRODUCTION;7,839.8 111 A HOLE IN TUBING;7,848.0 I I ¢ APERF;7,894.0-7,948.0- f _. 1 � APERF;7,978.0-8,013.0- • I I I AIM PRODUCTION;8,030.7 NIPPLE;8,039.9 •�_' SEAL ASSY;8,063.8 ®• LOCATOR;8,084.7 II PACKER;8,086.0 SBE;8,069.4 �-+, r NIPPLE REDUCER;8,084.4 NIPPLE;8,084.5 .J,'.47_ OM SOS;8,098.2 ;,gip;; IPERF;8,217.0-8,238.0---. lip IPERF;8,253.0$,273.0 FISH;8,357.0 PRODUCTION;28.0-8,838.1 S • Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Monday, March 19,2018 9:13 AM To: Loepp,Victoria T(DOA) Cc: Coberly,Jonathan Subject: RE: [EXTERNAL]KRU 1G-07(PTD 182-201, Sundry 318-099) Plug Perforations Follow Up Flag: Follow up Flag Status: Flagged Victoria, After conferring with engineers who've been in this role much longer than I on your questions,suspended would be the correct status.Yes,this well is planned for a CTD sidetrack(re-drill)approximately a month after we're on it by the current schedule. Thank you. Please let me know if you have any other questions or need anything else from me. Good day. Dusty Ward Senior Wells Engineer Office:907-265-6531 Cell:503-476-2519 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, March 16,2018 10:52 AM To:Ward, Dusty K<Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]KRU 1G-07(PTD 182-201,Sundry 318-099) Plug Perforations Dusty, This looks like a plug for redrill since all perfs will be plugged(abandoned)at the conclusion of this work. Is a CTD planned for a sidetrack(KRU 1G-07A)?The well status after this plugging would be"suspended". Is this correct? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 •R .440 • a, . . . . . . a 0 z o > co re a) O L E. C7 po v _c @ O +- co ✓ �o X - — .— � r � u +'' E > ' •- �- co +c.+ O + v LO a C c a� o ) Y 75 ypi o v a Q a E o 0- m 0 Q 0 ,_ 0 CO 0 0 0 CO co co v u L J < �_ p ,t .Q a _6 $ ri $ $ _6 E +4 -a 0 N J '" a) a) a) a) a) a) a) a) (p LA w 7 LL LL LL LL LL LL LL LL C co C u -c a) H 61 e- N M e} IA c0 h Co O a"' L C cjy Z .4 u 'o co o +.' u Z a v > E v C '- O C i co v 73 v, u 0 0 0 0 0 0 0 0 0 C L a� p LU J J J J J J J J J C O } W W W W W W W W W U f- LL LL LL LL LL LL LL LL LL +-, a) a) o -0 Q _0 > L aJ a < QQQQQ QQQ T C4�- OG < ZZZZZZZZZ v t a) 04 LL LL LL LL LL LL LL LL LL CC -0 c > E E a) u a v u s.•-3 V Z c o c >a' cyv .. z C. d' c H > u aa)) O 0 r-1 0. p o C co a, o 0 CC u °C Q a) a v, C o. U m < u^` d L L __I `° rn yy W a) a7 a7 a) a1 N.4 PI Sr c' 0 LL a a p — U c .G fU J O F' O U 2 - m ctO O J U o) O Q- H \ W v ro ` v = u ate. v o (,0 o�n 00 Ix, 0 ....,1 13 O Nu V 4421224 2-4> 0 z axo V d J J J J J J J J J CC0 o za c...- CZ 2.6 w I le r CLIYCLCLCLWCLCLce EE LU W W LU W LU LU LU W 3 O, w > > > > > > > > > s 0' Z Y Y Y Y Y Y Y Y Y > > > > > > > > > C - a' 2' a' Q' a' a' Q' d' 4 a) Y Cti W Q Q Q Q Q Q Q Q Q L >. O� �y. a a a a a a a a a m a oCD 1 ' MMDDMDDM YYYYYY YYY C O or \ 00 CO 0 O r co O O‘- NNNN N N X N co a N / 1 °C 0 0 0 0 0 0 0 0 0 ECI) E linint �✓ O f o 0 0 0 0 0 0 0 0laU (Ti! CO it ^ r; r• N- r F- r N- v R5 24)2 0 aa 0 0 0 0 0 0 0 0 0 C OI CD E Lu_ eo 0 0 0 0 0 0 0 0 0 c ~! L.t Cr n ! o 0 0 0 0 o O o o Lzr In N In v) - r m (yl O T hW 0) 0) IO) ON) IO) opv) E L O D U N. O; 0 oNNMMOM .QN . NNNNNNNNN L n O) M O) O) O) O) O) M O) a) 7,, QQQR NONNNN NON 'L O O o 0 0 0 0 O O O O O O O O O C It) I[) It) II) II) I() I() It) In Q 0 W t(1 '(p •C) f6 aJ 'O 'a H EI aj r^-I Q In V N N V N 4) aZ I'!) Z el'. N a+ E a) '" N J LL 2 V' r0 L °- _ = a. Q O N W: M M 0 0 2 2 N = £ Z H Y '_ Ca to ',-1 U n �' Ico CO co O C/3 a IB Q a a Q vezoi WELL LOG TRANSMITTAL DATA LOGGED PROACTIVE DIACINOSTiC SERVICES INC. RECEI@tVlK BEND R JAN 12 2018 To: AOGCC Makana Bender AOGCC 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ( ia5a`: Fi 1) Caliper Report 10-Jan-18 1G-07 1 Report/CD 50-029-20872-00 2) Signed : ��✓ i� / ' '/ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGEt MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx v 0 t'e2:?.0k RIC E 2-' gi8 111 JAN 12 2018 Memory Multi-Finger Caliper ILI IP AOGC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1G-07 Log Date: January 10,2018 Field: Kuparuk Log No.: 16553 State: Alaska Run No.: 1 API No. 50-029-20872-00 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,010 Ft.(MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of Production Mandrel 6 at 7,760 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage prior to whipstock setting operations. The caliper recordings indicate an apparent split in the tubing along with multiple holes in pup joint 240.2 from—7,848 feet to—7,855 feet,where the caliper also recorded a maximum of 66% cross-sectional wall loss. A 3-D log plot of the caliper recordings from 7,750 feet to 7,870 feet, highlighting the damage to the tubing is included in this report. The remainder of the tubing logged indicates no other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. MAXIMUM RECORDED WALL PENETRATIONS : Description PC.ffent V_;il t t rre[ 3riorr < i. _.':t"I Apparent Split/Multiple Holes 100 240.2 7,850 Ft. (MD) No other significant wall penetrations(> 16%)are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: L _sc3"lotion r t rco n':1 U U en; Jour ,, Apparent Split/Multiple Holes 66 240.2 7,850 Ft. (MD) No other significant areas of cross-sectional wall loss(>3%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. D. Henley C. Waldrop E. Zemba Fkkt F.4"1omernr(c) ;\ i:yst(s) \ t , ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 S • ril) ': •S PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips (Alaska), Inc. Field : Kuparuk Well : 1G-07 Date : January 10, 2018 Description : Detail of Caliper Recordings From 7,750 Feet to 7,870 Feet Across Split Tubing. Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map i -- I smissmir, ENNI , 1ft 100ft 0 % 100 2.5 inches 3.5 141° 0° 90° 180° 270° 0° Maximum I.D. 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 i r..tiv t _-- t — .--. c Joint 238 7755 f .., 7760 .,. Production Mandrel 6 Production Mandrel 6 7765 I ll ilk.,I- 7770 r-------- I I 1 ..._. Pup Joint J Pup Joint 7775 Iit — 4'41 if _____ I 7780 1 Ii 1 7785 i 7790 Joint 239 7795 11 f. I, • _ 7800 i' 7805 S • t 11111411111 7810 1111111111111111111617i......a 111111111111111111111 IL • -i. 11111111•11111,i 11111111•1111111M ----- 11111MMIIIIIS t IIIMMIIIIMI .4- INIIIIIIIIIMINIIIIIM111111•11111 t 7815 ••• t• •• MIIIIIIIIIIMIlt WM11111E11111 — IIIIIIIIMIIIIII ill111111111111111 , .,,,-_ 111111•11111111t1111111•11111M1 __=.414E 1111111111111111111t 1111M11111111111 7820 immit 1111111111 1111 ,...!: 11111 Joint 240 7825 IIIIIIIIIIIIIIIIIIV IIIIIIIIIIIIIIIIIII 11111•1111•11€ill1M11111111111 -... 111111111111110fft MI1111111•11111 .,. , IIIIIIIIIIIIIIIIII _.... 7830 1111111111141111111111 --: , IIIIIIMIIIIIIIIMI t 1111•11111•111 _ — ' IIIIIIIII IIIIII'm moo - , 7835 111111111111111111 111111111•1111111 , — 111.1111.11 1111•111111111•11 111111•1111•111€11111111111111•1111 •111111•111111€MIIIIIIMMIIIIII MIIIIIIIIIIIPIV mollimmtlilli = ` 7840 prodntdicnt:107n 7845 illipilipiiiii ,Production Mandrel 7 1111111111111•11111mum ."'"' - go AIIIIIIIMMIIIIIIIIIMili Z-Z=MMUMINIIIIIMIIIIIM. 7850 PJ t IlliiiiirinIthiL 77:12-72mic NMI up oinma , Apparent Split Mbing 111111111.11110.1111111.1111 al IIIIMEMINUri ipsdimmoom , 44 Multiple Holes — INEMAIMEri =- .. ' 66%Wall Loss 7855 Pup Joint 11111/1111111.11111111111 III IIIIIIIIIIIIIIIIIII INNII1111111.1111•11111•111111 .- smismort- ....,..0 - Nimmimmilemommi _ moommost IIIIMIIMIIIIIIN 7860 1111111111111Elt 11111111111111111011111 -,,_ . IIIIII1Apparent Split in Joint 241 the Pup Joint 7865 111111 mBealnodwreProductionMIIIIIMIIIIII -- , -,f-- n•vrt Minimum I.D. I I 2.5 inches 3.5 Maximum LD. I I 2.5 inches 3.5 Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map I I i ift:looft 0 % 100 2.5 inches 3.5 141° 0° 90° 180° 270° 0° • i Correlation of Recorded Damage to Borehole Profile IM Pipe 1 3.5 in (-9.0'-8,009.5') Well: 1G-07 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: January 10, 2018 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 -4 25 763 50 1,551 75 2,341 GLM 1 100 3,160 GLM2 s 111 125 gir 3,978 Li- .0 c Q, 150S) GLM 3 4,767 O GLM 4 GLM 5 175 1 5,675 200 6,465 225 7,254 245 7,988 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=245 • • P PDS Report Overview 4-4 00... _ Body Region Analysis Well: 1G-07 Survey Date: January 10,2018 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD 2.992 in. -9 ft. 8,010 ft. Penetration (%wall) Damage Profile(%wall) 300mai Imo Penetration body Metal loss body 0 50 100 250 0.1 200 150 tr- 10 0- -- 49 50ql WI0 0 to 20 to 40 to over GLM 1 (9:30) - 20% 40% 85% 85% 96 Number of joints analyzed(total=265) 264 0 0 1 — GLM 2 (8:30) Damage Configuration(body) 10 - 143 ■ GLM 3 (2:00) 8 ■ ■ ■■ GLM 5( :00) 6 GLM 5 (2:00) - _ ■■■ 180 4 ■ 2 IR 0 ■ Isolated General Line Other Hole/ 230 Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=4) 0 0 3 0 1 Bottom of Survey=245 1110 • illil 4-10. . PDS Report Joint Tabulation Sheet Well: 1G-07 Survey Date: January 10, 2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. -9 ft. 8,010 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 -9 0 0.02 9 2 2.95 Pun R 1 -4 0 0.03 12 2 2.96 •I 1.1 28 0 0.02 6 1 2.95 Pup • 2 36 0 0.01 5 1 2.95 i 3 71 0 0.02 6 1 2.95 4 103 0 0.04 14 3 2.95 5 134 0 0,02 7 2 2.95 a 6 166 0 0.02 8 1 2.95 I 7 197 0 0.01 5 1 2.94 i 8 229 0 0.02 6 1 2.95 a 9 261 0 0.02 6 1 2.94 • 10 293 0 0.02 6 2 2.95 M 11 324 0 0.02 6 2 2.96 12 356 0.04 0.03 10 1 2.95 • 13 388 0 0.02 7 1 2.95 I 14 419 , 0 0.01 5 2 2.94 15 451 0 0.02 6 1 2.95 2 16 482 0 0.02 6 1 2.95 I 17 514 0 0.02 6 2 2.95 r 18 545 0 0.02 6 1 2,95 • 19 575 0 0.02 8 2 2.94 • 20 605 0 0.01 4 1 2.95 i 21 637 0 0.02 8 1 2.95 a 22 669 0 0.02 6 2 2.95 a 23 700 0 0.02 9 2 2.94 • 24 732 0 0.02 6 1 2.95 25 763 0 0.02 7 1 2.95 • 26 795 0 0.01 4 1 2.96 a 27 826 0 0.03 13 1 2.95 as 28 857 0 0.04 15 1 2.95 Shallow Line of Pit. MI 29 888 0 0.02 6 2 2.95 i 30 920 0 0.02 9 1 2.94 • 31 952 0 0.02 9 2 2.95 • 32 984 0 0.03 11 2 2.95 11. 33 1015 0 0,02 6 1 2.94 • 34 1047 0 0.03 11 2 2.94 • 35 1078 0 0.03 12 2 2.95 m 36 1110 0 0,02 7 1 2.94 • 37 1141 0 0.02 6 2 2.95 a 38 1173 0 0.02 6 2 2.94 II 39 1205 0 0.02 8 1 2.95 • 40 1236 0 0.02 9 2 2.95 • 41 1268 0 0.02 6 1 2.96 42 1300 0 0,02 7 1 2.93 • 43 1330 0 0.02 8 1 2.95 • 44 1362 0 0.02 8 2 2.95 • 45 1393 0 0.02 7 1 2.95 • 46 1425 0 0.02 9 2 2.95 I 47 1456 0 0.01 4 2 2.94 i 48 1488 0 0.01 5 1 2.94 Penetration Body Metal Loss Body Page 1 • • Li:31 PDS Report Joint Tabulation Sheet Well: 1G-07 Survey Date: January 10, 2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. -9 ft. 8,010 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 49 1520 0 0.02 6 2 2,95 Ill 50 1551 0 0.01 5 1 2.95 51 1583 0 0.02 6 1 2.94 • 52 1614 0 0.02 6 1 2.95 1 53 1646 0 0.01 5 1 2.95 54 1678 0 0.01 4 1 2.95 55 1709 0 0.02 7 1 2.96 • 56 1741 0 0.02 6 1 2.95 57 1772 0 0.02 6 2 2.95 I 58 1804 0 0.02 7 1 2.95 U 59 1836 0 0.01 5 2 2.96 i 60 1867 0 0.02 6 1 2.95 61 1899 0 0.01 5 1 2.95 1 62 1930 0 0.01 5 1 2.96 1 63 1962 0 0.02 6 2 2.94 64 1994 0 0.01 5 1 2.95 I 65 2025 0 0.02 9 1 2.95 • 66 2057 0 0.01 5 1 2.96 1 67 2088 0 0.02 6 1 2.95 68 2120 0 0.01 4 1 2.95 69 2152 0 0,01 5 1 2.95 i 70 2183 0 0.01 5 1 2.95 71 2215 0 0.02 6 2 2.95 1 72 2246 0 0.01 5 1 2.95 I 73 2278 0 0.02 7 1 2.95 • 74 2309 0 0.02 6 1 2.95 1 75 2341 0 0.03 11 1 2.95 • 76 2373 0 0.02 9 1 2.94 • 77 2404 0 0.02 7 1 2.94 • 78 2436 0 0.01 6 1 , 2.95 79 2468 0 0.02 6 1 2.94 1 80 2499 0 0.01 5 1 2.95 i 81 2531 0 0.01 5 1 2.95 i 82 2562 0 0.02 6 2 2.95 1 83 2594 0 0.01 6 1 2.95 1 84 2626 0 0.02 6 1 2.95 II 84.1 2657 0.05 0.03 13 1 2.94 Pup ma 84.2 2667 0 0 0 0 2.89 GLM 1 (LATCH 0 9:30) 84.3 2676 0 0.04 15 2 2,95 Pup Shallow Line of Pits. 85 2686 0 0.03 10 1 2.94 86 2718 0 0.02 6 1 2.94 1 87 2749 0 0.02 6 1 2.94 88 2781 0 0.02 9 1 2.95 si 89 2812 0 0,02 6 1 2.94 1 90 2844 0 0.03 11 2 2.95 1.1 91 2876 0 0.01 6 2 2.94 1 92 2907 0 0.02 6 1 2.95 V 93 2939 0 0.02 7 1 2.95 II 94 2970 0 0.02 7 1 2.95 s 95 3002 0 0.02 7 2 2.94 i Penetration Body Metal Loss Body Page 2 41-4 PDS Report Joint Tabulation Sheet Well: 1G-07 Survey Date: January 10, 2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. -9 ft. 8,010 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 96 3033 0 0.02 7 1 2.95 1 97 3065 0 0.02 7 1 2.93 • 98 3096 0 0.02 7 1 2.95 • 99 3128 0 0.02 9 1 2.95 • 100 3160 0 0.02 6 1 2.94 • 101 3191 0 0.02 7 1 2.95 • 102 3223 0 0.02 9 1 2.94 103 3254 0 0.02 6 2 2.95 • 104 3286 0 0.02 9 1 2.95 • 105 3317 0 0.02 7 2 2.94 • 106 3349 0 0.02 6 1 2.95 107 3381 0 0.02 7 1 2.94 �• 108 3412 0 0.02 7 1 2.95 • 109 3444 0 0.02 8 1 2.94 • 110 3475 0 0.02 7 1 2.95 • 111 3507 0 0.02 9 1 2.94 • 112 3539 0 0.02 7 1 2.94 I 113 3570 0 0.02 8 1 2.94 '• 114 3602 0 0.02 9 1 2.94 • 115 3633 0 0.02 7 1 2.96 • 116 3665 0 0.02 7 2 2.95 • 117 3697 0 0.02 9 1 2.95 �• 118 3728 0 0.02 6 2 2.95 119 3759 0 0.02 7 2 2.95 • 120 3791 0 0.02 8 1 2.95 11 121 3822 0 0.02 8 1 2.94 • 122 3854 0 0.02 8 1 2.95 • 123 3886 0 0.02 7 1 2,94 • 124 3917 0 0.02 8 1 2.94 • 124.1 3949 0 0,02 9 1 2.88 Pup Lt. Deposits. 124.2 3959 0 0 0 0 _ 2.88 GLM 2(LATCH @ 8:30) ` 124.3 3967 0 0.02 8 1 2.94 Pup 125 3978 0 0.03 11 2 2.94 •• 126 4009 0 0.03 10 1 2.94 • 127 4041 0 0.02 6 1 2.95 • 128 4072 0 0.02 9 2 2.95 • 129 4104 0 0.02 7 2 2.95 • 130 4136 0 0.02 6 1 2.93 Lt.Deposits. • 131 4167 0 0.02 8 2 2.94 • 132 4199 0 0.02 9 1 2.95 U 133 4230 0 0.02 6 1 2,95 134 4262 0 0.02 9 2 2.95 • 135 4293 0 0.02 8 1 2.95 • 136 4325 0 0.02 8 1 2.96 • 137 4357 0 0.01 5 1 2.95 138 4388 0 0.02 6 2 2,95 139 4420 0 0.02 6 1 2.95 • 140 4451 0 0.02 6 1 2.96 • 141 4483 0 0.03 . 10 2 2.95 • 142 4515 0 0.01 5 2 2.96 1 IPenetration Body Metal Loss Body Page 3 • • 11111 tit PDS Report Joint Tabulation Sheet Well: 1G-07 Survey Date: January 10, 2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 WE 8RD Tubing 2.992 in. 0.254 in. -9 ft. 8,010 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 143 4546 0 0.02 7 1 2.95 • 144 4578 0 0.02 7 1 2.95 _ 145 4609 0 0.02 7 1 2.95 -� 146 , 4641 0 0.01 6 1 2.95 I 147 4672 0 0.01 5 1 2.95 148 4704 0 0.01 4 1 2.95 149 4736 0 0.02 6 2 2.95 I 150 4767 0 0.02 6 2 2.94 I 151 4799 0 0.01 4 1 2.95 152 4831 0 0.02 6 2 2.94 • 152.1 4862 0 0.02 9 1 2.95 Pun 152.2 4872 0 0 0 0 2.89 GLM 3(LATCH ®2:00) 152.3 4880 0 0.02 6 0 2.95 Pup 153 4891 0 0.01 5 2 2.95 1 154 4923 0 0.01 5 1 2.95 155 4955 0 0.02 7 1 2.95 156 4986 0 0.03 10 1 2.95 U 157 5018 0 0.02 7 1 2.95 • 158 5049 0 0.03 11 2 2.95 159 5080 0 0.01 4 1 2.95 . 160 5112 0 0.01 5 2 2.95 161 5144 0 0.01 5 1 2.95 162 5175 0 0.01 6 1 2.95 I 163 5207 0 0.02 7 2 2.95 U 164 5238 0 0.02 6 1 2,95 1 165 5270 0 0.02 6 1 2.93 166 5302 0 0,02 7 1 2.94 167 5333 0 0,01 6 2 2.95 168 5364 0 0.02 6 1 2.94 I 168,1 5396 0 0.02 7 1 2.94 Pup 168.2 5408 0 0 0 0 2.89 GLM 4(LATCH ® 1:00) 168.3 5415 0 0.03 10 1 2.95 Pup 169 5426 0 0.02 6 1 2.95 169.1 5457 0 0.03 11 1 2.93 Pup Lt. Deposits. 169.2 5463 0 0 0 0 2.98 BAKER 80-40 SEAL ASSEMBLY 169.3 . 5476 0 0 0 0 2.87 7"X 3.5" BAKER FHL PACKER 169.4 5484 0 0,04 14 1 2.92 Pup Lt. Deposits. 170 5489 0 0.02 6 1 2.95 1;1 170.1 5520 0 0.03 10 1 2.95 Pun 170.2 5530 0 0 0 0 2.89 GLM 5(LATCH ®2:00) 170.3 5538 0 0.03 11 1 2.95 Pun ■ 171 5549 0 0.02 8 2 2.94 • 172 5581 0 0.02 6 1 2.95 173 5613 0 0.02 8 2 2.95 • 174 5644 0 0.02 7 2 2.95 175 5675 0 0.02 8 1 2.95 176 5707 0 0.02 8 1 2.94 • 177 5739 0 0.02 8 2 2.93 178 5770 0 0.01 5 1 2.95 179 5802 0 0.02 6 2 2.95 IPenetration Body Metal Loss Body Page 4 • • PDS Report Joint Tabulation Sheet Well: 1G-07 Survey Date: January 10, 2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. -9 ft. 8,010 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 180 5833 0 0.02 7 1 2,93 11 181 5865 0 0.02 6 1 2.95 1 182 , 5897 0 0.01 5 1 2.94 1 183 5928 0 0,02 7 1 2.94 184 5960 0 0.02 6 1 2.95 185 5991 0 0.02 6 1 2.94 I 186 6023 0 0.02 6 1 2.95 It 187 6054 0 0.02 6 1 2.94 • 188 6086 0 0.02 6 2 2.94 189 6118 0 0.02 6 2 2,94 o 190 6149 0 0.02 7 2 2.94 • 191 6181 0 0.01 6 1 2,96 192 6212 0 0.02 8 1 2.95 U 193 6244 0 0.02 6 1 2.94 194 6276 0 0.02 8 1 2.94 • 195 6307 0.14 0.02 9 2 2.93 196 6339 0 0.02 7 1 2.95 1 197 6370 0 0.02 7 1 2.95 198 6402 0 0.02 8 1 2.94 • 199 6434 0 0.02 9 2 2.95 • 200 6465 0 0.02 9 1 2.95 • 201 6497 0 0.03 11 1 2.95 11 202 6529 0 0.02 7 2 2.94 U 203 6560 0 0.02 6 2 2.95 • 204 6592 0 0.02 8 2 2.94 U 205 6624 , 0 0.02 7 1 2.95 • 206 6655 0 0.02 9 1 2.94 • 207 6686 0 0.02 8 1 2.94 • 208 6718 0 0.02 6 1 2.95 • 209 6749 0 0.03 11 1 2.95 210 6781 0 0.02 6 1 2.94 211 6813 0 0.02 7 1 2.95 U 212 6844 0 0.02 9 1 2.95 • 213 6876 0 0.02 6 1 2.96 214 6908 0 0.02 6 1 2.95 1 215 6939 0 0.01 5 2 2.95 1 216 6971 0 0.02 7 1 2,94 217 7002 0 0.02 7 1 2.95 • 218 7034 0 0.02 6 1 2.95 1 219 7065 0 0.02 9 2 2.94 • 220 7097 0 0.02 8 2 2.95 • 221 7129 0 0.02 7 2 2.93 222 7161 0 0.02 8 2 2.95 • 223 7192 0 0.02 7 2 2.95 • 224 7224 0 0.02 9 2 2.95 • 225 7254 0 0.02 7 2 2.93 Lt.Deposits. • 226 7286 0 0.02 8 2 2.95 ■ 227 7317 0 0.02 9 1 2.94 • 228 7349 0 0.02 7 2 2.95 U 229 7380 0 0.02 8 2 2.95 • Penetration Body Metal Loss Body Page 5 • • 4-111 PDS Report Joint Tabulation Sheet Well: 1G-07 Survey Date: January 10, 2018 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD Tubing 2.992 in. 0.254 in. -9 ft. 8,010 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 230 7412 0 0.02 6 2 2.95 M 231 7444 0 0.02 8 2 2.95 232 7476 0 0.02 9 2 2.95 • 233 7507 0 , 0,02 7 2 2.94 234 7539 0 0.02 6 1 2.95 235 7570 0 0.02 7 1 2.95 1 236 7618 0 0.02 6 1 2.95 U 236.1 7649 0 0.02 9 1 2.95 Pup • 236.2 7660 0 0 0 0 2.81 CAMCO DS NIPPLE 236.3 7660 0 0.01 5 2 2.96 Pup 237 7670 0 0.02 9 2 2.93 Lt.Deposits. ■ 237.1 7702 0 0.03 . 13 0 2.92 Pup Lt. Deposits. 237.2 7709 0 0 0 0 2.96 BAKER 80-40 SEAL ASSEMBLY 237.3 7720 0 0 0 0 2.88 7"X 3,5"BROWN HB PACKER 238 7729 0 0,02 7 2 2.93 l 238.1 7760 0 0 0 0 2.88 PRODUCTION MANDREL 6 (LATCH @ 3:30) 238.2 7768 0.04 0.04 14 2 2.84 Pup Lt. Deposits. 239 7777 0 0.02 9 2 2.92 Lt.Deposits. 240 7809 0 0.02 6 2 2.95 240.1 7840 0 0 0 0 2.86 PRODUCTION MANDREL 7 (LATCH @ 12:30)' . 240.2 7849 0.13 1.22 100 67 2.88 Pup Apparent Split.Multiple Holes. 241 7857 0 0.02 7 2 2.87 242 7890 0 0.03 12 2 2.93 Blast Ring. 243 7919 0 0.02 9 2 2,93 Blast Ring. 243.1 7950 0 0.02 9 3 2.95 Pup 244 7954 0 0,04 16 3 2.93 Blast Ring. U 245 7988 0 0.02 8 2 2.94 Blast Ring IPenetration Body Metal Loss Body Page 6 • • PDS Report Cross Sections ELI O.,�_-. Well: 1G-07 Survey Date: January 10,2018 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin:: 3.5 in. 9.3 ..f L-80 WE 8RD Analyst: C.Waldrop Cross Section for Joint 240.2 at depth 7,850.1 I ft. Tool speed= 52 1— ___ Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=54% Tool deviation=39° 1 Finger= 12 Penetration= 1.215 in. Apparent Split/Multiple Holes 0.12 in.= 100%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections Well: 1G-07 Survey Date: January 10,2018 Field: Kuparuk Tool Type: UW MFC 24 No.218370 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 WE 8RD Analyst: C.Waldrop Cross Section for Joint 240.2 at depth 7,850.130 Tool speed=52 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=33% Tool deviation=39° 111 1 \.* __._____,_/ Finger= 11 Penetration= 1.205 in. Apparent Split/Multiple Holes 67%Cross-Sectional Wall Loss HIGH SIDE=UP • KUP PROD 1G-07 ConocoPhillips Oh Well Attributes Max Angle&MD TD Alaska,Il lr;. Wellbore API/UWI Field Name Wellbore Status lIncl(°) MD(ftKB) Act Btm(ftKB) cmxoeh," 500292087200 KUPARUK RIVER UNIT PROD 47.15 8,600.00 8,851.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-07.11/18/2016 11:15.27 AM SSSV.NONE 60 7/31/2015 Last WO: 10/20/2076 29,99 1714/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ' -- Last Tag;SLM 8,231.0 10/28/2016 Rev Reason:RWO,GLV C/0,PULL HEX PLUG pproven 11/16/2016 HANGER;237 'il='1-R S &RHC PLUG,TAG,SEE NOTES Casing Strings r ""11"""'"'"'""""'""""""""""""""111" dv -','y Casing Description OD(in) ID(in) Top(1KB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L CONDUCTOR 16 15.060 30.0 79.0 79.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 29.7 2,487,0 2,367.0 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(kK8) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 28.0 8,836.1 7,013.5 26.00 K-55 BTC -/1-/�ti CONDUCTOR;30.0-79.046., - ^•'�+�./�Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibkt) Grade Top Connection TUBING-Upper Gas 3 1!2 2.992 23.7 5,490.5 4,512.2 9.30 L-80 EUE 8rd Lift Completion Completion Details Top(ftKB) Top(ND)(ftKB) ToInc! Item Des Com Nominal ID SURFACE,297-2,487.0I P nc(°) 23.7 23,7 0.02 HANGER Cameron 7 1/16 x 3 1/2 Gen IV N-FBB Tubing Hanger 2.992 GAS LIFT,2,685.8 1 "E' 5,477.9 4,502.6 40.63 LOCATOR Locator 3.000 - 5,478.9 4,503.4 40.63 SEAL ASSY Baker 80-40 Seal Assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Mt) Grade Top Connection Stacked Packer 3 1/2 2.992 5,479.8 7,717.6 6,225.7 9.30 L-80 EUE Srd Assembly GAS LIFT;3975.2 1 aOm Completion Details Nominal ID Top(ftKB) Top(ND)(kK8) Top Incl(°) Item Des Com (in) 5,479,8 4,504.0 40.62 PBR Baker Polish Bore Recptical 4,000 5,493.1 4,514.2 40.54 PACKER Baker 3)4 x 7 FHL Retrievable Packer Pinned to shear @ 2.960 GAS LIFT;4887.8 60k 7,655.9 6,179,5 47,43 NIPPLE Camco 2.813"DS Nipple 2.813 7,704.9 6,216.2 41.64 LOCATOR Locator 3.000 7,705.7 6,216.8 41.64 SEAL ASSY Baker 80-40 Seal Assembly 3.000 GAS LIFT,5,421.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..]Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection "" ORIGINAL LOWER 4 1/2 2.867 7,708.8 8,097 2 6,503.1 9.20 J-55 BTC ---- COMPLETION LOCATOR;5.477.9 Completion Details SEAL ASSY;5,478.8, Nominal ID PBR;5.479.8 • Top(ftK8) Top(ND)(ftKB) Top Incl("1 Item Des Corn (in) PACKER;5,493.1 iligili 7,708.8 6,219.1 41.65 SBR BROWN PRB(PINNED FOR 30K SHEAR) 2.813 7,722.5 6,229,4 41.67 PACKER BROWN HB RETRIEVABLE PACKER 7"x 3 1/2" 3,000 -- 7,888.9 6,352.8 43.06 BLAST RINGS 59'BLAST RINGS 2.867 GAS LIFT,5,5466 f �. 7,953.2 6,399.5 43.57 BLAST RINGS 44'BLAST RINGS 2.867 8,039.9 6,462,1 44.15 NIPPLE OTIS X NIPPLE 2.813 8,063.8 6,479.2 44.32 SEAL ASSY BAKER SEAL ASSEMBLY w/5'SEALS 3,000 8,064.7 6,479.8 44.32 LOCATOR BAKER LOCATOR 3.050 8,066.0 6,480.8 44.33 PACKER BAKER FB-1 PERMANENT PACKER 4.000 8,069.4 6,483.2 44.36 SBE SEAL BORE EXTENSION 4.000 8,084.5 6,494.0 44.46 NIPPLE CAMCO D NIPPLE NO GO 2.750 ® 8,096.2 6,502.4 44.54 SOS BAKER BALL SEAT SHEAR SUB,ELMD TTL©8100 3.000 during PPROF on 4/19/2006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl --_ Top(ftK8) MB) (°) Des Corn Run Date ID(in) LOCATOR;7.704.9 8,084.4 6,493.9 44.46 NIPPLE NIPPLE REDUCER 2/6/1998 2.250 1 SEAL ASSY;7,705.7REDUCER SBR;7,708.8 8,357.0 6,685,6 45.93 FISH A-2 Blanking Plug&Junk Basket Left in Tailpipe 975/1988 0.000 PACKER;7,7225 below milled up PKR;See HantlOver Form 9/6/88 PRODUCTION;7,760.3-'fiiiiiii Perforations&Slots Shot Dens PRODUCTION,7,839.9_.. Top(ND) Btm(TVD) (shotsk Top(ftKB) Btm MKS) (kKB) (ftKB) Zone Date t) Type Corn 7,894.0 7,946.0' 6,356.5 6,394.3 C-4,C-3,1G- 9/1/1988 12,0 APERF 120 deg.Phasing 07 APERF;7.894.0-7,946.0- 7,978.0' 8,013.0 6,417.5 6,442.8 C-1,1G-07 9/1/1988 16.0 APERF 12 @ 120 deg 4 @ 90 i 8,217.0 8,238,0 6,587.7 6,602.5 A-4,1G-07 1/1471983 12.0 IPERF 120 deg Ph;GeoVann • TCP APERF;7.978.0-8,013.(7-_ 8,253.0 8,273.0 6,613.0 6,627.0 A-3,10-07 1/14/1983 ' 12.0 IPERF 120 deg Ph;GeoVann TCP li PRODUCTION;8,030.7 Mandrel Inserts NIPPLE;8039.9 St ati on Top(ND) Valve Latch Port Size TRO Run SEAL ASSY;8,063.8 • N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn LOCATOR;8.064.7 1 2,685.8 2,511.9 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,274.0 10(24/2016 PACKER;8,066.0 2 3,975.2 3,412.8 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,271.0 10723/2016 SBE;8,069.4 W NIPPLE REDUCER;8,084.4 3 4,887.8 4,063.9 Camco MMG 11/2 GAS LIFT OV RK 0.250 O.0'10723/2016 NIPPLE;8,0845 :'/,i$:. - 4 5,421.1 4,459.6 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10!19/2016 SOS;8,096.2 - __ 5 5,546.6 4,554.9 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/19/2016 IPERF;8,217.0-8.238.0--• 6 7,760.3 6,257.6 MERLA TPDX 11/2 PROD DMY RM 0.000 0.0 2/25/1993 closed IPERF;8,2530-8,273.04------.7 W. 7 7,839.9 6,316.8 MERLA TPDX 11/2 PROD CV RM 0.000 0.0 7/26/2007 Open FISH;8.357.0-46ag 8,030.71 6,455.5 MERLA TPDX 1 1/2 PROD CV RM 0.000 0.0 7/26/2007 Open PRODUCTION:28.0-8.836.1- • KUP PROD 1G-07 ConocoPhillips it Alaska,Inc. cv�ocePhtups '•• 1G-07.11/18201611'15.29ANI Vertical schematic(actual) HANGER;23.7 /ABAjt Notes:General&Safety o,,,,.,..,./...am,,,,,u,,u.u„mmuma,, End Date Annotation 9/5/1988 NOTE:WO 6/9/2001 NOTE:CVs®7840'&8031 RKB slightly eroded 2/7/2011 NOTE:View Schematic w/Alaska Schematic9.0 10/20/2016 NOTE:WO Mn CONDUCTOR;30.0-79.0 .' N 10/28/2016 NOTE: UNABLE TO PASS 7821'SLM WITH 2.6T MAGNET.MADE 2.74"LIB RUN TO SAME 10/29/2016 NOTE:(INCONCLUSIVE IMPRESSION)....RETURN AT LATER DATE TO TROUBLE SHOOT OBSTRUCTION SURFACE;29.7-2,487.0 l GAS LIFT;2885.8 E mf GAS LIFT;3,975.2 t qI{Ida GAS LIFT;4,887.8 GAS LIFT;5.127.0 ti LOCATOR;5,477.9 SEAL AP8B89;::4477,111N 5,478.8,478.8 , PACKER;5,493,1 1111- GAS LIFT;6,546.6 LOCATOR:7705.7 SEAL ASSY;7,708.81 SBR;7,708.8 1 PACKER;7,722.6 PRODUCTION;7,760.3 PRODUCTION;7,839.9 ,( APERF17,894.0-7946.0 T yl APERF;7,978.0-8,013.0-f .} PRODUCTION;8,030.7 .. NIPPLE;8,039.9 . •'. SEAL ASSY;8,063.8 -- LOCATOR;8,064.7 PACKER;8,088.0Ott SBE;8,089.4 NIPPLE REDUCER;8,084.5, NIPPLE;8,084.5 SOS;8,098.2 8,098.2 (PERF;8,217.0-8,238.0--� (PERF;8,253.0-8,273.0-- FISH;8.357.0 PRODUCTION;28.0-8,838.1- RECEIVED ' STATE OF ALASKA NOV 1 8 2016 ALA"OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon E Plug Perforations r Fracture Stimulate E Pull Tubing F Operations Shutdown , Performed: Suspend E Perforate la Other Stimulate n Alter Casing E Change Approved Program Plug for Redrill i' Perforate New Pool E Repair Well IF Re-enter Susp Well E 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory I 182-201 3.Address: 6.API Number: Stratigraphic n Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-20872-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25640 KRU 1G-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8851 feet Plugs(measured) None true vertical 7024 feet Junk(measured) 8357 Effective Depth measured 8231 feet Packer(measured) 5493, 7722, 8066 true vertical 6598 feet (true vertical) 4514,6229, 6481 Casing Length Size MD TVD Burst Collapse CONDUCTOR 49 16 79 79 SURFACE 2457 10 3/4 2487 2367 PRODUCTION 8808 7 8836 7013 Perforation depth: Measured depth: 7894-7946, 7978-8013, 8217-8238,8253-8273 True Vertical Depth: 6356-6394,6417-6443,6588-6602,6613-6627 VW t��1 i{{��' (Z1',17, St, 4.i'V MAP, LA0 8 Tubing(size,grade,MD,and TVD) 3.5, L-80/J-55, 8097, MD,6503 ND Packers&SSSV(type,MD,and TVD) PACKER =BAKER FHL RETRIEVABLE PACKER @ 5493 MD and 4514 TVD PACKER= BROWN HB RETRIEVABLE @ 7722 MD and 6229 TVD PACKER=BAKER FB-1 PERMANENT PACKER @ 8066 MD and 6481 TVD SSSV:NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 70 40 2249 1125 160 Subsequent to operation 330 105 2900 1164 181 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service Stratigraphic E Copies of Logs and Surveys Run n 16.Well Status after work: Oil F Gas E WDSPL E Printed and Electronic Fracture Stimulation Data r. GSTOR r WINJ fl WAG I- GINJ E SUSP fl SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Sara Heskin a 265-1027 Email Sara.Heskin@conocophillips.com Printed Name Sara Heskin Title Assoc. Wells Engineer Signature VMJ Phone:265-1027 Date 1 I /1 7 1 ( 10 JV�J\..J1J1 �"�i� 11 Form 10-404 Revised 5/2015 V-ii- -27/("//�RBDNIS L v NOV 2 8 2016 Submit Original Only X7,7 =' Operations Summary (with Timelog Depths) 0 t 1G-07 conoco4hitUps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/15/2016 10/15/2016 6.00 DEMOB 'MOVE MOB P Dissconnect interconnects,blow down 0.0 0.0 12:00 18:00 steam and water,Split complexes transport boiler motor pumps rock washer and pits t/1G pad, Dissconnect trucks return t/1L Pad 10/15/2016 10/16/2016 6.00 MIRU MOVE MOB P Pull sub off well,Load shop and camp, 0.0 0.0 18:00 00:00 1 Load pipe sheds,Transport sub and complexes to 1G pad,Stage and spot sub over well,Begin spotting complexes. 10/16/2016 10/16/2016 9.00 MIRU MOVE MOB P Move rig and modules over well.Spot 0.0 0.0 00:00 09:00 support equipment. Rig accept 09:00 hrs 10/16/2016 10/16/2016 2.00 MIRU WELCTL RURD P Begin loading SW into pits,R/U hard 0.0 0.0 09:00 11:00 line to choke and kill tank.Test pumps and R/U floor equipment. 10/16/2016 10/16/2016 1.50 MIRU WELCTL MPSP P R/U lubricator and test to 1000 psi. 0.0 0.0 11:00 12:30 Pull BPV.Tubing pressure=300 psi RD lubircator.. 10/16/2016 10/16/2016 1.00 MIRU WELCTL RURD P Complete filling and R/U hard line to 0.0 0.0 12:30 13:30 celllar and Tiger Tank.Test line to 2500 psi. 10/16/2016 10/16/2016 1.50 MIRU WELCTL KLWL P Begin reverse circulation 4 bpm for 42 0.0 0.0 13:30 15:00 bbls.Stop pumping,strap tank. Being pumping down the tubing 295 bbls @ 5 bpm/600 psi.slow pump rate to 2 bpm/180 psi for last 30 bbls. 1:1 returns during kill. 10/16/2016 10/16/2016 1.00 MIRU WELCTL , OWFF P Monitor the well for 15 mins.Tubing 0.0 0.0 15:00 16:00 on a vac, IA still blowing slightly with diesel/gas combo. Suck out Tiger tank with Vac truck before pumping more volume. 10/16/2016 10/16/2016 1.25 MIRU WELCTL -KLWL P Pump additional 100 bbls @ 3bpm 0.0 0.0 16:00 17:15 down tubing.Observe well for flow f/ 30 min well static 10/16/2016 10/16/2016 0.50 MIRU WHDBOP MPSP P Install BPV and PT t/1000 psi f/10 0.0 0.0 17:15 17:45 min,R/D and blow down circ lines 10/16/2016 10/16/2016 2.75 MIRU WHDBOP NUND T N/D tree in cellar,observe flow from 0.0 0.0 17:45 20:30 around BPV threads,N/U tree,test hanger seals,Pull BPV inspect valve good,Reinstall valve, R/U circ lines PT BPV in direction of flow t/1000 psi f/10 min good no leaks. 10/16/2016 10/16/2016 1.50 MIRU WHDBOP NUND T N/D Tree,Observe threads on bpv 0.0 0.0 20:30 22:00 begin leaking,N/U tree,test void,IA 0 psi minimal flow around BPV threads in tubing 10/16/2016 10/16/2016 1.50 MIRU WHDBOP CIRC T Circulate surface to surface 4 bpm 0.0 0.0 22:00 23:30 700 psi,no gas observed at bottoms up,observe well static 10/16/2016 10/17/2016 0.50 MIRU WHDBOP MPSP T Set BPV test in direction of flow U 0.0 0.0 23:30 00:00 1000 psi f/10 min 10/17/2016 10/17/2016 2.00 MIRU WHDBOP NUND P N/D tree adaptor flange,clean threads 0.0 0.0 00:00 02:00 on hanger Install blanking plug 10/17/2016 10/17/2016 2.00 MIRU WHDBOP NUND P N/U adaptor flange and BOP,choke 0.0 0.0 02:00 04:00 line 10/17/2016 10/17/2016 2.00 MIRU WHDBOP RURD P R/U t/test BOP,weld 9"on riser 0.0 0.0 04:00 06:00 Page 1/3 Report Printed: 10/20/2016 0 110 ' Operations Summary (with Timelog Depths) 0. 1G-07 ilii n irka Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/17/2016 10/17/2016 3.00 MIRU WHDBOP NUND P -Test BOPE w/3.5"test jt w/250/2500 0.0 0.0 06:00 09:00 psi,test choke valves 1-14,Auto and Man IBOP,Hcr andMan Choke and Kill,4"Kill Line Demco TIW and Dart, Upper Lower and blind rams,Annular, Test gas alarms and Flow and pit sensors,Accumulator test 200 psi 39 sec full pressure 178 sec,State Inspector Lou Grimaldi Waived witness of test. 10/17/2016 10/17/2016 1.00 MIRU WHDBOP RURD P R/D Test equipment,blow down lines, 0.0 0.0 09:00 10:00 Pull Test plug and BPV 10/17/2016 10/17/2016 1.00 COMPZ1 RPCOMP RURD P R/U to pull hanger M/U landing Jt to 0.0 0.0 10:00 11:00 hanger and top Drive,BOLDS 10/17/2016 10/17/2016 . 0.25 COMPZ1 RPCOMP PULL P Pull hanger to floor,hanger pulled free 0.0 0.0 11:00 11:15 @ 60k string free @ 140k hook load 10/17/2016 10/17/2016 1.25 COMPZI RPCOMP CIRC P Circ.Bottoms up 4 bpm 200 psi, 0.0 0.0 11:15 12:30 monitor well,well static 10/17/2016 10/17/2016 0.50 COMPZ1 RPCOMP PULL P LID hanger and landing jt,B/D top 0.0 0.0 12:30 13:00 drive and install stripping rubber and air slips. 10/17/2016 10/17/2016 7.00 COMPZ1 RPCOMP PULL P POOH L/D 3.5"tubing f/7693't/ 7,693.0 0.0 13:00 20:00 surface,33 of 34 SS Bands recovered, Tubing cut was unsucessful seals recovered, 10/17/2016 10/17/2016 1.00 COMPZ1 RPCOMP BHAH P Clean and clear rig floor/M/U floor 0.0 0.0 20:00 21:00 valve 10/17/2016 10/17/2016 0.50 COMPZ1 RPCOMP PRTS P PT 7"Casing t/2500 psi f/10 min. 0.0 0.0 21:00 21:30 10/17/2016 10/17/2016 1.75 COMPZI RPCOMP WAIT 'T Wait on tools coming from dead horse, 0.0 0.0 21:30 23:15 simops perform work orders and maintenance. 10/17/2016 10/18/2016 0.75 COMPZ1 RPCOMP SLPC P Slip and cut drilling line 0.0 0.0 23:15 00:00 10/18/2016 10/18/2016 0.50 COMPZ1 RPCOMP SLPC 'P Finish Slipping and cutting drilling line. 0.0 0.0 00:00 00:30 10/18/2016 10/18/2016 0.50 COMPZ1 RPCOMP RURD P Mobilize hanger and equipment to rig 0.0 0.0 00:30 01:00 floor 10/18/2016 10/18/2016 0.50 COMPZ1 RPCOMP SVRG P Service rig and top drive 0.0 0.0 01:00 01:30 10/18/2016 10/18/2016 2.50 COMPZ1 RPCOMP WAIT T Wait on jewelry from camco,Rig move 0.0 0.0 01:30 04:00 in dead horse holding up the trucks 10/18/2016 10/18/2016 0.75 COMPZ1 RPCOMP RURD P Load jewelry in pipe shed strap and 0.0 0.0 04:00 04:45 put in order 10/18/2016 10/18/2016 6.50 COMPZ1 RPCOMP RCST P RIH w/3.5 stacker packer completion 0.0 7,683.0 04:45 11:15 as per detail.t/7683' 10/18/2016 10/18/2016 2.75 COMPZ1 RPCOMP HOSO P Slack of pumping f/7683't/ 7714.46' 7,683.0 7,714.0 11:15 14:00 Tagging up,unable to get deeper, work 1 round of torque into string attempt to get into PBR Unable to get in 10/18/2016 10/18/2016 4.00 COMPZ1 RPCOMP PULL T POOH standing back and L/D 7,714.0 0.0 14:00 18:00 completion jewelry f/7714 t/surface 10/18/2016 10/18/2016 - 0.50 COMPZ1 RPCOMP OWFF T Observe well for flow well static 0.0 0.0 18:00 18:30 10/18/2016 10/18/2016 1.50 COMPZ1 RPCOMP BHAH T M/U Clean Out BHA as Per Baker to 0.0 0.0 18:30 20:00 run in on tubing Page 2/3 Report Printed: 10/20/2016 =` Operations Summary (with Timelog Depths) 0 r 1G-07 ConocoPhiilips d,hrA� Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/18/2016 10/18/2016 2.75 COMPZ1 RPCOMP TRIP T RIH t/7698' 0.0 7,698.0 20:00 22:45 10/18/2016 10/19/2016 1.25 COMPZ1 RPCOMP WASH T Wash down f/7698'to 7714'2 bpm 90 7,698.0 7,724.0 22:45 00:00 psi set down 5 k close bumper sub weight fell off,wash down t/7724'and nogo, Pump 30 bbl hi vis sweep around @ 8 bpm while working scraper up and down 30'stroke, approx 15 gal of sand recovered on bottomos up 10/19/2016 10/19/2016 0.50 COMPZ1 RPCOMP OWFF T Observe well for flow well static 7,724.0 7,724.0 00:00 00:30 10/19/2016 10/19/2016 3.00 COMPZ1 RPCOMP TRIP T POOH w/Clean out f/7724'to 36' 7,724.0 36.0 00:30 03:30 10/19/2016 10/19/2016 1.00 COMPZ1 RPCOMP BHAH T L/D BHA and Clean and Clear floor 36.0 0.0 03:30 04:30 10/19/2016 10/19/2016 4.50 COMPZ1 RPCOMP RCST T RIH w/Completion as per detail from 0.0 7,716.0 04:30 09:00 derrick t/7716' 10/19/2016 10/19/2016 1.00 COMPZ1 RPCOMP HOSO P P/U t/7712'wash down w/pumps 1 7,716.0 7,726.0 09:00 10:00 bpm observe pressure increase @ 7714'shut off pumps slack off t/7726' No go 10/19/2016 10/19/2016 3.25 COMPZ1 RPCOMP CRIH P P/U U 7712'Circ 200 bbls CI Fluid 2 7,726.0 7,725.0 10:00 13:15 bpm 100 psi Slack off into seals t/ 7725' 10/19/2016 10/19/2016 1.50 COMPZ1 RPCOMP PACK P Pressure up t/2500 psi f/10 min t/set 7,725.0 7,725.0 13:15 14:45 packer,bleed down tubing U 2000 psi test IA and Packer top t/2500 psi f/10 min verify packer set,bleed off tubing 10/19/2016 10/19/2016 1.75 COMPZ1 RPCOMP HOSO P L/D 3jt M/U Space outjts and Hanger, 7,725.0 7,725.0 14:45 16:30 M/U Landing jt,Drain Stack,Land on Hanger RILDS 10/19/2016 10/19/2016 1.00 COMPZ1 RPCOMP PRTS P Pressure test tubing to 3000 psi f/10 7,725.0 7,725.0 16:30 17:30 min,Bleed down tubing to 2000 psi, Pressure up IA U 2500 psi f/30 min, bleed off tubing shear SOV 10/19/2016 10/19/2016 0.25 COMPZ1 RPCOMP MPSP P Set Back Pressure valve and test in 7,725.0 0.0 17:30 17:45 driectoion of flow t/1000 psi 10/19/2016 10/19/2016 2.00 COMPZ1 WHDBOP SVRG P Between wells maintenance on BOP 0.0' 0.0 17:45 19:45 Stack 10/19/2016 10/19/2016 0.75 COMPZ1 WHDBOP NUND P N/D BOP Stack and rack back 0.0 0.0 19:45 20:30 10/19/2016 10/19/2016 1.50 COMPZ1 WHDBOP NUND P N/U Adaptor flange and tree Test void 0.0 0.0 20:30 22:00 to 5000 psi f/10 min,Test tree to 5000 psi f/5 min,Pull BPV 10/19/2016 10/19/2016 1.00 COMPZ1 WELLPR FRZP P R/U t/freeze protect well spoty in LRS 0.0 22:00 23:00 10/20/2016 10/20/2016 2.00 COMPZ1 WELLPR FRZP P Allow well to utube,Blow down and 00:00 02:00 R/D Lines 10/20/2016 10/20/2016 1.00 COMPZ1 WHDBOP SEQP P Install Blind flanges secure wellhead 02:00 03:00 for rig move Rig Realeased @ 0300 hrs Page 3/3 Report Printed: 10/20/2016 KUP IllD 1G-07 ConocoPhillips 4 Well Attribut Max Angle&MD TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status ncl d MD(ftKB) 'Act Btm(ftKB) Cara000�itNllips 500292087200 KUPARUK RIVER UNIT PROD 47.15 8,600.00 8,851.0 L --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-0711/18/201682807 AM SSSV:NONE 60 7/31/2015 Last WO: 10/20/2016 29.99 1/14/1983 Vardcatschemadc(actual) Annotation Depth((tKB) End Date Annotation Last Mal By End Date Last Tag:SLM 8,231.0 10/28/2016 Rev Reason:RWO,GLV C/O,PULL HEX PLUG pproven 11/16/2016 HANGER;23.7 C: ,..,t &RHC PLUG,TAG,SEE NOTES Casing Strings u;,�•, .,n,,,,,,,;,,,,,,,,,,,,,.,....,. 't „ t,_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread aCONDUCTOR 16 15.060 30.0 79.0 79.0 62.50 H-40 WELDED ° Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 29.7 2,487.0 2,367.0 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7, 6.276 28.0 8,836.1 7,013.5 26.00 K-55 BTC ten.CONDUCTOR;30.0.79.0- Tubing Strings Tubing Description String Ma...ID(in) Top IftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-Upper Gas 31/2 2.992 23.7 5,490.5 4,512.2 9.30 L-80 EUE 8rd Lift Completion Completion Details Nominal ID SURFACE;29.7.2,487 0-..• Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 23.7 23.7 0.02 HANGER Cameron 7 1/16 x 3 1/2 Gen IV N-FBB Tubing Hanger 2.992 GAS LIFT;2,685.8 5,477.9 4,502.6 40.63 LOCATOR Locator - 3.000 5,478.9' 4,503.4 40.63 SEAL ASSY Baker 80-40 Seal Assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..)Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection .1 Stacked Packer 3 1/2 2.992 5,479.8 7,717.6 6,225.7 9.30 L-80 EUE 8rd Assembly GAS LIFT;3,975.2 Z.- Completion Details 1.1 Nominal ID Top((KB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) AL 5,479.8 4,504.0 40.62 PBR Baker Polish Bore Recptical 4.000 GAS LIFT;4,887.8 ! 5,493.1 4,514.2 40.54 PACKER Baker 3%x 7 FHL Retrievable Packer Pinned to shear @ 2.960 Ii 60k I 7,655.9 6,179.5 41.43 NIPPLE Camco 2.813"DS Nipple 2.813 7,704.9 6,216.2 41.64 LOCATOR Locator 3.000 in GAS LIFT;5,421.0 IF= 7,705.7 6,216.8 41.64 SEAL ASSY Baker 80-40 Seal Assembly 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ibtrt) Grade Top Connection il TUBING-ORIGINAL 41/2 2.867 7,708.8 8,097.2 6,503.1 9.20 J-55 BTC AB LOCATOR;5,477.9 4=1 Completion Details SEAL ASSY;5,478.8 Nominal ID PBR;5,479.8 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des corn (in) 7,708.8 6,219.1 41.65 SBR BROWN PRB(PINNED FOR 30K SHEAR) 2.813 PACKER;5,493.1 7,722.5 6,229.4 41.67 PACKER BROWN HB RETRIEVABLE PACKER 7"x 3 1/2" 3.000 7,888.9 6,352.8 43.06 BLAST 59'BLAST RINGS 2.867 RINGS GAS LIFT;5,5466 r i 7,953.2 6,399.5 43.57 BLAST 44'BLAST RINGS 2.867 RINGS 8,039.9 6,462.1 44.15 NIPPLE OTIS X NIPPLE 2.813 J 80638 64792 44.32 SEAL ASSY BAKER SEAL ASSEMBLY w/5'SEALS 3000 80647 64798 44.32 LOCATOR BAKER LOCATOR 3000 8,0660 64808 4433 PACKER BAKER FB-1 PERMANENT PACKER 4000 8,0694 64832 44.36 SBE SEAL BORE EXTENSION 4.000 8,084.5 6,494.0 44.46 NIPPLE CAMCO D NIPPLE NO GO 2750 8,096.2 6,5024 4454 SOS BAKER BALL SEAT SHEAR SUB,ELMD TTL @8100 3000 during PPROF on4/19/2006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) ((KB) (°) Des Com Run Date ID(n) LOCATOR;7,7049 8,084.4 6,493.9 44.46 NIPPLENIPPLE REDUCER 2/6/1998 2.250 SEALASSY;7,7057,SBR;7,708.8 8,357.0 6,685.6 45.93 FISH A-2 Blanking Plug 8 Junk Basket Left in Tailpipe 9/5/1988 0.000 below milled up PKR; See HandOver Form 9/6/88 PACKER;7,7225 PRODUCTION;7,7803 I Perforations&Slots ' ; Shot Dens Top(TVD) Btm(ND) (shots/ PRODUCTION;7,839.9 Top(ftKB) Btm(ftKB) (ftKB) _ (MB) Zone Date ft) Type Com I. 7,894.0 7,946.0 6,356.5 6,394.3 C-4,C-3,1G- 9/1/1988 12.0 APERF 120 deg.Phasing 07 APERF;7,894.0-7,948.0 r7,97$.0 8,013.0 6,417.5 6,442.8 C-1,1G-07 9/1/1988 16.0 APERF 12 @ 120 deg 4 @ 90 8,217.0 8,238.0" 6,587.7 6,602.5 A-4,10-07 1/14/1983 12.0 IPERF 120 deg Ph;GeoVann TCP APERF;7,978.0-8,013.0- • I_ i7 8, 253.0 8,273.0 6,613.0 6,627.0 A-3,1G-07 1/14/1983 12.0 IPERF 120 deg Ph;GeoVann 'AV TCP PRODUCTION;8,030.7 - Mandrel Inserts NIPPLE;8,039.9 IL 7.:: a t i Aon Top(TVD) Valve Latch Port Size TRO Run SEAL ASSY;8,063.8 --_- N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com LOCATOR;8,064.7 `` 1 2,685.8 2,511.9 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 10/24/2016 Rd PACKER;8,086.02 3,975.2 3,412.8 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,271.0°10/23/2016 SBE;8,089.4 1' -- 3 4,887.8 4,063.9 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 10/23/2016 NIPPLE REDUCER;8,084.4 NIPPLE;8,084.5 {I r.:. - _ 4 5,421.1 4,459.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/19/2016 SOS;8,096.2 ®, 5 5.546.6 4,554.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/19/2016 IPERF;8,217.0-8,238.0--. -I I I 6 7,760.3 6,257.6 MERLA TPDX 11/2 PROD DMY RM 0.000 0.0 2/25/1993 close d IPERF;8,233.0-8,273.0- I I 7 7,839.9 6,316.8 MERLA TPDX 11/2 PROD CV RM 0.000 0.0 7/26/2007 Open FISH;8,357.0 8 8,030.7 6,455.5 MERLA TPDX 11/2 PROD CV RM 0.000 0.0 7/26/2007 Open PRODUCTION;28.08,836.1- KUPD • 1 G-07 €OnnocOPhiliipS Alaska,Inc. caEwoo`4hi6ips ••• 10-07,11/18/20168:28.07 AM Vertical schemata(actual) HANGER;23.7 Notes:General&Safety • n :1 Date Annotation 9/5/1988End WO 6/9/2001 NOTE:NOTE:CVs @ 7840'&8031 RKB slightly eroded 2/7/2011 NOTE:View Schematic w/Alaska Schematic9.0 10/20/2016 NOTE:WO CONDUCTOR;30.0-78.0 10/28/2016 NOTE: UNABLE TO PASS 7821'SLM WITH 2.67"MAGNET.MADE 2.74"LIB RUN TO SAME (INCONCLUSIVE IMPRESS! SURFACE;29.7-2,487.0 • GAS LIFT;2,685.8 GAS LIFT;3,975.2 111 GAS LIFT;4,887.8 (' I®I GAS LIFT;5,421.0 Mk LOCATOR;5,477.9 SEAL ASSY;5,478.8 PBR;5,479.8 PACKER;5,493.1 'a GAS LIFT;5,546.6 LOCATOR;7,704.9 i SEAL ASSY;7,705.7 �=_�s:l SBR;7,708.8 =+ PACKER;7,722.5 PRODUCTION;7,760.3 N' 'a PRODUCTION;7,839.9 ` -E7'4 1 APERF;7,894.0-7,946.0-. IMF APERF;7,978.0-8,013.0 I '. 11.1 PRODUCTION;8,030.7 _ NIPPLE;8,039.9 SEAL ASSY;8,083.8 LOCATOR;8,084.7 PACKER.8,086.0 _ SBE;8,089.4 61;W- NIPPLE REDUCER;8,084.4 Pill NIPPLE;8,084.5 (-J,/- SOS;8,086.2 I 1 IPERF;8,217.0-8.238.0 IPERF;8,253.0-8,273.0--. FISH;8,357.0 PRODUCTION;28.0-8,838.1 - L9 O • O I I I CA 60M I- N 0 R () ONW a t „, O a+ 1 ' 0 J(4m Dp +J >. 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I s °` y p` N • �= , ri :g• w C aJ R tn C51 LD F- a a C age Project Well History File Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No.. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by [] Poor Quality Originals: large scanner OVERSIZED (Non-Scannable) [] Other: NOTES: ~ Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: tsl Scanning Preparation x30= ~ BY: BEVERLY BREN VINCENT SHERYL(~ LOWELL -I' TOTAL PAGES Production Scanning Stage1 PAGE COUNT FROM SCANNED FILE: '(~/ ,,ATC.ES .U,,.E. ,. SCA.. .G PREP^RAT,O.: YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES (SC~NING IS COMPLETE AT THIS POINT UNLESS 8PECI~ A~ENTION 18 REQUIRED ON ~ INDI~DUAL PAGE ~818 DUE TO QUALI~, G~YSC~E OR COLOR IMAGES) NO NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked fao.el 05/09/06 Schlumberger NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth '1l' / , '. 'i' ¡&~\~\¡;r .JVì\~ J.. 10 ~t¡.;,'~~ \¡; "........ Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman " 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ;)..¡O \ Field: Kuparuk \ Cð~'" Well CD Job# Log Description Date BL Color 1 Y -29 11213739 PRODUCTION PROFILE WIDEFT L"ir~- (..C\ , 04/28/06 1 3M-25A N/A SHUT IN 8HP ¡ C\(.. - aG<O 04/23/06 1 2N-303 N/A LDL Ç) .;: () - I ~C; 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT \~1-t\3 04/25/06 1 3F-07 N/A INJECTION PROFILE / 'Í("';- - 94f...- 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT IC '-1- n7,;"'} 04/04/06 1 38-15 11213741 INJECTION PROFILE j4(£.,- - {-- ~.....- 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT I oC{ if - ~t' \ 04/19/06 1 1 A-20 11235356 PRODUCTION LOG W/DEFT /(."10 - (/';d 04/26/06 1 1 H-18 N/A INJECTION PROFILE Ie; -~ - h:lb 04/24/06 1 1 R-12 11213738 PRODUCTION LOG W/DEFT I ~~ -0'1 ~ 04/27/06 1 1 Y -13 11213740 INJECTION PROFILE I~~ - C" \ Ç" . 04/29/06 1 2N-318 11213742 LDL dDO -100 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE 1&';-1- -;,c,"2, 05/02/06 1 1G-01 11213744 INJECTION PROFILE IYd-- t~b 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT íc,C~ -1i-["'1- 05/04/06 1 1 R-26 11258705 INJECTION PROFILE 'j c') I - ('1~ '::;t 05/05/06 1 2A-04 11249902 INJECTION PROFILE ¡ ~L.I_ (~<~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE I ~? - ;:)..4.~ 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE 1"'(2..'" -\ (...., 05/07/06 1 1G-14 11249904 INJECTION PROFILE 1~3'- ¡';'{I 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e Re: FW: Kuparuk Well testing requiremement-lG-07 & IG-08 /&'2.'-' zð I ) ) Subject: Re: F\V: Kuparuk Well testing requiremement-lG-07 & 10-08 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 23 Aug 2005 11 :24:36 -0800 To: "Kovar, Mark" <Mark.Kovar@conocophillips.com> CC: John Hartz <jack_hartz@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us> Mark, Further to Jack's reply. According to our records, 1 G-08 was plugged back for sidetrack in late June 2004. The correct well name reference should be 1 G-08A which was completed July 24, 2004. Tom Maunder, PE AOGCC John Hartz wrote, On 8/23/2005 11 :03 AM: Mark, Thanks for the reminder. Your request appears to be an operational necessity for a short period until the parts are available and repair work can be done on the divert valve. Your proposal to produce IG-07 and IG-08 until divert valve repairs are completed is acceptable. Notify me if the repairs will be significantly delayed beyond October 1. Thank you for the notification. Jack Hartz, P.E. Sr. Reservoir Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave. Suite 100 Anchorage AK 99501 907-793-1232 Fax: 907-276-7542 (,e-,' ø"~ ,.Ii~ [¡Ioj ~~ h';;;_.~_ L'ì! ,«,:' r: ~I) ~ lì ..~ 2 0 D ì.~ O~' n~I~~~~~ ,)Jl_t r;)' _,. -"" ~c Kovar, Mark wrote: I don't know if you received my email below so just following up on it. Thanks. Mark Kovar Kuparuk Drillsite Engineer ConocoPhillips Alaska, Inc. 700 G Street, A TO 1280 Anchorage, AK 99501 Office: (907) 265-6097 -----Original Message----- From: Kovar, Mark Sent: Wednesday, August 17, 2005 7:19 AM To: 'jack hartz@admin.state.ak.us' Cc: CPFl Prod Engr Subject: Kuparuk Well testing requiremement-1G-07 & lG-08 10f2 8/29/2005 10:33 AM Re: FW: Kuparuk Well testing requiremement-lG-07 & IG-08 ') ) CPAI requests a waiver from the 30-day well testing requirement for wells 1G-07 and 1G-08. These wells share a production flowline and are twin tested. The divert valve to the test separator is not operational and requires replacement. We are waiting on parts and expect to have the work complete by or before October 1, 2005 at which time we will commence with twin well testing. Please let me know if this plan is acceptable, or give me a call if you wish to discuss it in further detail. Mark Kovar Kuparuk Drillsite Engineer ConocoPhillips Alaska, Inc. 700 G Street, A TO 1280 Anchorage, AK 99501 Office: (907) 265-6097 20f2 8/29/2005 10:33 AM Re: FW: Kuparuk Well testing requiremement-l G-07 & 1 G-08 ') r ~~ .)-d-C) \ .: . :. ..... .. ... ..... ..............:< :... ......:....:. .... ... . ..... :. .... ... .. '..... ... IX~::. ..... .. . §~.~ l~.çt:....R.~.:....F."'Mf.:·.·.~p~~~··.ri.~I.l.·~est~ng...~~.~I~~rFl'l1.~rpent~..·1.(j-~..07·.:&·.·1 C1~º~ ~..'.'.. ~f~1t);·..~?~n·.·.~~rt~.:)J·.~ç~~p~~Z($~4¥1-ill;·s~~t.~.;..âk;·\l.~¿ Qte:1'lle;23~ug200$11:()3:41i~()800 ...... Mark, Thanks for the reminder. Your request appears to be an operational necessity for a short period until the parts are available and repair work can be done on the divert valve. Your proposal to produce 18- 07 and 18- 0 8 until divert valve repairs are completed is acceptable. Notify me if the repairs will be significantly delayed beyond October 1. Thank you for the notification. Jack Hartz, P.E. Sr. Reservoir Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave. Suite 100 Anchorage AK 99501 907-793-1232 Fax: 907-276-7542 SC1\1\INE[) 1\\. H~ ~~ :i 2005 Kovar, Mark wrote: I don't know if you received my email below so just following up on it. Thanks. Mark Kovar Kuparuk Drillsite Engineer ConocoPhillips Alaska, Inc. 700 G Street, A TO 1280 Anchorage, AK 99501 Office: (907) 265-6097 -----Original Message----- From: Kovar, Mark Sent: Wednesday, August 17, 2005 7: 19 AM To: 'ìack hartz@admin.state.ak.us' Cc: CPF1 Prod Engr Subject: Kuparuk Well testing requiremement-1G-07 & 1G-08 lof2 8/23/2005 11 :09 AM Re: FW: Kuparuk Well testing requiremement-lG-07 & IG-08 ') ) CPAI requests a waiver from the 30-day well testing requirement for wells 18-07 and 18-08. These wells share a production flowline and are twin tested. The divert valve to the test separator is not operational and requires replacement. We are waiting on parts and expect to have the work complete by or before October 1, 2005 at which time we will commence with twin well testing. Please let me know if this plan is acceptable, or give me a call if you wish to discuss it in further detail. Mark Kovar Kuparuk Drillsite Engineer ConocoPhillips Alaska, Inc. 700 G Street, A TO 1280 Anchorage, AK 99501 Office: (907) 265-6097 20f2 8/23/2005 11 :09 AM STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMM,,.~SION 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 4. Location of well at surface 1206' FSL, 616' FWL, Sec. 29, T12N, At top of productive interval 1505' FSL, 1430 FEL, Sec. 29, T12N, At effective depth 1110' FNL, 850' FEL, Sec. 29, T12N, At total depth 1120' FNL, 862' FEL, Sec. 29, T12N, 12. 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R10E, UM R10E, UM R10E, UM R10E, UM Present well condition summary Total Depth: measured 8 83 6' true vertical 7023' feet feet Plugs (measured) 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-7 Producer 9. Permit number/approval number 85-201/7-547 10. APl number 50-02~)-20872 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 8 786' true vertical 6888' feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 82' 16" 2687' 10 3/4" 8836' 7" measured 7978'-8273' true vertical 6410'-6610' Cemented 300 X 1300 Sx Measured depth True vertical depth 80' 80' 2687' 2680' 730 Sx 8836' 7023' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 8096' Packers and SSSV (type and measured depth) Camco TRDP-1AE @ 1987'; Baker HB @ 7817; BOT 2-B 8061' 13. Stimulation or cement squeeze summary Intervals treated (measured) "',o-Ka 0il & 8as Anchorage Treatment description including volumes used and final pressure 3000 gal, 12% HCL 14. Prior to well operation (producing) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 331 1 26 1087 1 103 489 129 679 1118 16. Status of well classification as: Water Injector__ Oil ~X Gas Suspended Service Tubing Pressure 262 222 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /,'~./[,n.,~{,., Title Sr. Operations Engineer Form 1~-404- R~v(~:)~/17/8~ SUBMIT IN DUPLICATE "ARCO Alaska, In'~ O Subsa~iary of Atlantic Richfield Company WELL SERVICE REPORT WELL iPBDT J FIELD - DISTRICT- STATE REMARKS ~ '. Z-'-~oc~:::),"~'T q ~ g. I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK RWeepa°thrter 1Temp'°~: Ich''lFact°' Iv'''b'''ty"FI mileslwlndv,l' knotslSlgned ~ · ~ STATEOF ALASKA ALASKA LAND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' 1. Status of Well OIL~ GAS :~1 SUSPENDED ~ ABANDONED ~] SERVICE [] Classification of Service Well 2. Name of Operator ?.0. Bu~ 100360. A,,c;,orag: AK 99510-0360 4. Locat,on oT well at surTace s 1206' FSL, 616' FWL, 5ec.29, T12N, R10E, UN At Top Producing Interval 1505' FSL, 1430' FEL, 5ec.29, T12N, RIOE, UN At Total Depth 1120' FNL, 862' FEL, 5ec,29, T121~ 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' 12. Date Spudded 113. Date T.D. Reached 17. Total D~th (M D+TVD) ~ 18. Plug Back Depth (M~D) I 8851 ~MD/702~ 'TVD I 8784MD/~978 ~/TVD 22. Type El~tric or Other Logs Run 23. , R10E: UM 6. Lease Designation and Serial No. ADL 25640 AIK 2571 14. Date Comp., Susp. or Aband. fl1/!~_!83' 19. I~iectional Survey YES~ NO [] 7. Permit Number 82-201 8. APl Number 50- 029-20872 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1G-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 15. Water Depth, if offshore I16' No. of Completions N/A feet MSLI 1 20. Depth where SSSV set I 21. Thickness of Permafrost 1804' feet MD I 1%(Wl' (n?prnw) _ 1311 /C;[~l /c;p/[~nc/C~l /('=1 R~..T C.P/Cl:ll r. wrn -(~A~fl~, LINER AND CEMENTING RECORD CASING SIZE 16" ,q a '") I1,11 WT. PER FT. ,,.,, ~..· -/ir 45 5# 2G GRADE I.I I, fl Ii'-ru i/ ~¢- K-SS SETTING DEPTH MD TOP BOTTOM "'-Ff ~"' · .~u uu .5UFf -~u'" ..... ~ .SUFf 0836' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 7894'-7946'MD/6357'-6394'TVD w/12 spf 120° phasing 7978'-8013'MD/6417'-6442'TVD w/4 spf 90° phasing 8217'-8238'MD/6588'-6603'TVD w/12 spf 8253'-8273'MD/6613'-6627'TVD w/12 spf 27. N/A Date First Production HOLE SIZE : hi. ii /-'-I- 13-I/2" O-~/ '-I' 25. SIZE 3-1/2" CEMENTING RECORD 730 ~ Cia~s G &~u~ ~^ 26. DEPTH INTERVAL (MD) 8149'-8151 ' 7873 ' -7875 ' PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) %MOUNT PULLED S i AS I TUBING RECORD DEPTH SET (MD) J PACKER SET (MD) 8370' I 7722', 8066', & 8335' ACID, FRACTURE, CEMENT SOUEEZE, ETC. I AMOUNT& KIND OF MATERIAL USED 400 sx Class G 600 sx Class G Date of Test Hours Tested Flow Tubing Press. Casing Pressure IPRODUCTION FOR IOIL-BBL TESTPERIOD eI CALCULATED ~IO,L-BBL 24-HOUR RATE '~' I GAS-MCF GAS-MCF 28. CORE DATA WATER-BBL WATER-BBL ICHOKESIZE JGAS-OILRATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None NOTE: Workovers performed 7/12/84 and 9/6/88 (add perf). Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 7893 801 3 8191 8355 TRUE VERT. DEPTH 30. FORMATION TESTS 6356' 6443' 6570' 6684' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LiST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 1'6, 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 (D.F, 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 STATE OF ALASKA AL/-,,_.,A OIL AND GAS CONSERVATION COMMI5._. ,JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate m Plugging __ Pedorate Pull tubing ~ Alter casing m Repair well ~ Pull tubing __ Other -X- WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1206' FSL, 616' FWL, Sec.29, T12N, R10E, UM At top of productive interval 1505' FSL, 1430' FEL,-Sec.29, T12N, R10E, UM At effective depth 1146' FNL, 903' FEL, Sec.29, T12N, R10E, UM At total depth 1120' FNL, 862' FEL, Sec.29, T12N, R10E, UM 5. Type of Well: Development X- Exploratory ~ Stratigraphic __ Service ~ 6. Datum elevation (DF or KB) RKB 90 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-7 9. Permit number/approval number 82-201/8-504 10. APl number 50-- 029-20872 11. Field/Pool Kuparuk River 0il Pool 12. Present well condition summary Total depth: measured 8851 'MD true vertical 7024 ' TVD Effective depth: measured 8784 ' HD true vertical 6978 ' TVD Casing Length Structural Conductor 80 ' Surface 2457 ' Intermediate Production Liner Perforation depth: feet Plugs (measured) feet measured feet Junk (measured) feet Size Cemented 16" 300 sx AS II 10-3/4" 1300 sx AS III & 250 sx AS I None 373' Vann Gun fish Top of fish (~ 8379' Measured depth True vertical depth 8808' 7" 80'MD 80'TVD 2487'MD 2367'TVD 730 sx Class G & 250 sx AS I 8836'MD 7014 ' TVD 7894'-7946'MD, 7978'-8013'MD, 8217'-8238', 8253'-8273' true vertical 6357'-6394'TVD, 6417'-6442'TVD, 6588'-6603'TVD, 6613'-6627'TVD Tubing (size. grade, and measured depth) 3-1/2", J-55, tbg w/tail ~ 8370' Packers and SSSV (type and measured depth) Brown 'HB' pkr @ 7722', Baker 'FB-I' pkr @ 8066', B0T '2-B' pkr @ 8335', Camco 'TRDP' 5SSV @ 1804' 13. Stimulation or cement squeeze summary 14. .,^ RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure ...... n:, ~. ~ f'.nnn. C0fn~[SS[0~ . Representative Daily Average Production or Injection Data :, ~chora~e N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ' TubingPressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run .~_. Daily Report of Well Operations ~ 16. Status of well classification as: Oil _~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed & (/)~ ~, ~t,LL~¢../~. Title Form 10-404 Rev 06/15/88 ~ - *WORKOVER WELL HISTORY Associ ate Engi neet (Dani) SW03/035 Date SUBMIT IN DUPLICATE feet ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish or borough NORTH SLOP__]~ or Unit ADL: 25640 WORKOVER Field ARCO Alaska, Inc. KUPARUK RIVER UNIT 1G-07 ]Well no. Auth. or W.O. no. AK3404 API: 50-029-2087 Operator ARCO IDate 08/20/88 IHour 1345 HRS RCO W.I. 6.0000 ~t-'JJu~ ~'; w.o, Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 08/21/88 ( TD: 8851 ?B: 8784 SUPV:DS 08/22/88 ( TD: 8851 PB: 8784 SUPV:DS 08/23/88 ( TD: 8851 PB: 8784 SUPV:DS 08/24/88 ( TD: 8851 PB: 8784 SUPV:DS 08/25/88 ( TD: 8851 PB: 8784 SUPV:LP 08/26/88 ( TD: 8851 PB: 8784 SUPV:MD/LP 08/27/88 ( TD: 8851 PB: 8784 SUPV:MD/LP Complete record for each day reported NORDIC I KILL WELL W/ 10 PPG BRINE MW:10.1 NACL/NABR ACCEPT RIG AT 1345 HRS, 8/20/88, RU WL, RIH TO PULL DV (UNSUCCESSFUL), POH, RIH (HIT ICE BRIDGE AT 56'), POH, PUMP 50 BBLS OF HOT DIESEL, RIH AND PULL DV FROM 7756', POH, LOADED HOLE WITH FRESH WATER, BEGIN KILLING WELL WITH 10 PPG NACL/NABR BRINE DAILY:S57,400 CUM:$57,400 ETD:S57,400 EFC:$716,000 ND TREE MW: 9.6 NACL/NABR CONT. PUMPING 10 PPG BRINE DOWN TBG (GETTING 25-50% CRUDE/WTR RETURNS), CUT FLUID WEIGHT TO 9.8 PPG, RU HALLIBURTION, PUMP 30 BBL TEMPBLOK 120 PILL, DISP WITH 40 BBLS BRINE, ATTEMPT TO CIRC DOWN TBG UNSUCCESSFULLY, FILL ANN. W/ 30 BBLS WTR, CUT FLUID WEIGHT TO 9.6 PPG, PUMP BRINE DOWN TBG, TAKING RETURNS OUT ANNULUS DAILY:S108,671 CUM:$166,071 ETD:S166,071 EFC:$716,000 RIH WITH PKR RELEASING TO MW: 9.6 NACL/NABR SET BPV, ND TREE, NU BOPE, TEST BOPE TO 3000 PSI, POH WITH 3-1/2" TBG CHANGING COUPLINGS TO BUTT AB MOD, MU PKR RELEASING TOOL AND RIH ON 3-1/2" DP DAILY:S66,426 CUM:$232,497 ETD:S232,497 EFC:$716,000 RIH WITH OS ON TBG MW: 9.4 NACL/NABR RIH WITH OS ON DP, CIRC. AND COND. MW 9.4 PPG, LATCH PACKER AND PULL FREE WITH 210 M LBS, POH WITH PACKER, LD PACKER AND DAILY:S33,906 CUM:$266,403 ETD:S266,403 EFC:$~6~0 POH WITH FISH MW: 9.4 NACL/NABR I~F~ RI. WIT. OVERSHOT O, TBG, RI. WITH OS O, SLIC~I,E ~"S~C\' ~ -~ ~""~" TBS, RECOVSRED FIS. (C~.ZC~ COTTER), RD SLICU, INE, LATC. TUBI,~ STUB WIT. OS, ~ULL FREE, C~RC. AND COND.~o~ ~"-~R~a~& ~S C0nS.- :~~0~m~SS'0~ WITH FISH DAILY:S41,889 CUM:$308,292 ETD:$308,292 EFC:$716,000~[~[~l~ NU BOP STACK MW: 9.4 NACL/NABR POH WITH 3-1/2" TUBING STUB, RIH AND SET RBP AND STORM PACKER, ND BOPE STACK, RELEASE SURFACE AND PRODUCTION PRESSURE, ND 3000 PSI TBG HEAD, NU 5000 PSI TBG HEAD, NU BOPE DAILY:S37,630 CUM:$345,922 ETD:S345,922 EFC:$716,000 RIH W/1-1/4" STINGER MW: 9.4 NACL/NABR NU AND TESTED BOPE, PULLED STORM PACKER, RELEASED RBP, CIRC. BTMS UP, POH WITH DP, LD RBP, PERF 7894'-7946' & 7978'-8013' RIH WITH 1-1/4" STINGER ON 3-1/2" DP DAILY:S88,150 CUM:$434,072 ETD:S434,072 EFC:$716,000 The above is correct Signature ~ I~r f~rrn nr~n~ _ __/Date ITJtle ARCO Oil and Gas Company Daily Well History--Interim Inslructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District lCounty or Parish [Stal~ ARCO Alaska, Inc. l----.-NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT ] 1G-07 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 08/28/88 ( TD: 8851 PB: 8784 SUPV:MD/LP 08/29/88 ( TD: 8851 PB: 8784 SUPV:MD/LP 08/30/88 ( TD: 8851 PB: 8784 SUPV:MD/LP 08/31/88 ( TD: 8851 PB: 8784 SUPV:MD/LP 09/01/88 ( TD: 8851 PB: 8784 SUPV:DS 09/02/88 ( TD: 8851 PB: 8784 SUPV:DS 09/03/88 ( TD: 8851 PB: 8784 SUPV:DS lO) Well no. NORDIC I RIH WITH COMP. ASSEMBLY MW: 9.4 NACL/NA:{R CONT. RIH WITH 1-1/4" STINGER, CLEAN OUT TAIL PIPE, DISPLACE HOLE WITH CLEAN BRINE, POH LD DP AND BH;~, RUN 3-1/2" COMPLETION ASSEMBLY DAILY:S29,643 CUM:$463,715 ETD:S463,715 ~FC:$716,000 RIH W/ COLLAR STOP ON SL MW:. 9.4 NACL/NABR RIH WITH COMPLETION ASSEMBLY, ATTEMP~ TO STAB INTO PKR, NO SUCCESS, RU OTIS SLICKLINE, RIH W/ SA~D BAILER(7 RUNS), ATTEMPT TO STAB INTO PKR, WON'T HOLD PRESSURE, RIH WITH X LOCK, RIH WITH IMPRESSION BLOCK. RI~ DAILY:S41,979 CUM:$505,694 ETD;S505,694 EFC:$716,000 RIH W/ COLLAR STOP PLUG MW: 9.4 NACL/NABR RIH WITH COLLAR STOP TO VERIFY ~EAKS, RETRIEVE CV~ INSTALL NEW CV, SET HB PKR, SHEAR PBR, LAND TBG HANGER, PULL CV, INSTALL DV, SET X LOCK AND PLUG,'"RIH WITH COLLA~ RTQP PLUG TO LOCATE LEAK DAILY:S29,100 CUM:$534,794 ETD:S534,795 EFC:$715,999 RIH W/ PKR PULLING TOOL MW.: 9.4 NACL/NABR CONT. RUNNING COLLAR STOP ON SLICKLINE TO LOCATE TBG LEAY, LEAK AT BTM GLM, POH W/ SLICKLINE, ~Oq WITH 3-!/2" T~G A~,.~ PBR SEAL ASSEMBLY, RIH WITH PKR PULLING TOOL ON 3-1/2" DRILL PIPE DAILY:S59,867 CUM:$594,661 ETD.$S94,~&~ EFC:$716,00~- DISPLACE HEC PILL MW: 9.4 NACL/NABR RIH WITH PACKER RELEASING TOOL, LATCH PBk, ~U AhD SHEAR (PKR RELEASED AT 182 M LBS OF PULL), CBU. POH, LD ?¥~. AMD COMP ASSEMBLY, MU 1-1/4" STINGER AND TEST SIAL ASSEMBLY, RIH, WORK STINGER INTO PKR AND CIRC., STI~G SF,~S INTO ~}~ +/- 2', ATTEMPT TO TEST DP (SEALS LEAKING), PU ABOVE PC~, CBU DAILY:S39,403 CUM:$634,064 ETD~$634,065 EFC:$715,999 POH WITH PKR MILL MW: 9.4 NACL/N~~ PUMP AND DISPLACE HEC PILL TO BTM, PO~, LD SEA~ ASSEMBLY.-- PKR MILL, RIH WITH MILL ON DP, MILL ON PKR FROM 8060'-8~...~ CBU, POH FOR NEW MILL DAILY:S40,490 CUM:$674,554 ETD:S674,554 EFC:$716,000 RIH WITH PKR MILL #3 MW: 9.~ NACL/N~'~: FINISH POH, LD MILL, MU NEW MILL ". R~H, WASH & RE~4 MILL TO 8062' DPM, MILL ON PKR TO 806/.~ [;~'~, POH, LD MILL, MU MILL #3 AND RIH. DAILY:S45,544 CUM:$720,098 ETD' ~,098 E~C:$716,00~ The above is correct Signature JDar e.~_~~~Tille A, SSO C~,TE ENG For form preparatio~ see Procedures Mar~al Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on ""Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Le~aseCOUnty or Parish [SteteAK NORTH SLOPE 1G-07 Field ARCO Alaska, Inc. KUPARUK RIVER UNIT IWell no. Date and depth as of 8:00 a.m. 09/04/88 ( TD: 8851 PB: 8784 SUPV:DS 09/05/88 ( TD: 8851 PB: 8784 SUPV:DS 09/06/88 ( TD: 8851 PB: 8784 SUPV:DS Complete record for each day while drilling or workover in progress NORDIC 1 '5) 6) 7) RIH WITH MILL ~3 MW: 9.3 NACL/NABR RIH WITH MILL ~3, MILL PKR FROM 8062.5' TO 8063', PKR FELL, PU 9 SINGLES AND TAG PKR AT 8329' DPM, PUSH PKR TO 8335' DPM, CIRC OUT GAS BUBBLE, CIRC BTMS UP, POH, LD MILL, MU MILL AND SCRAPER, RIH DAILY:S31,133 CUM:$751,231 ETD:S751,231 EFC:$716,000 RIH WITH COMPLETION ASSEMBLY MW: 9.3 NACL/NABR FIN RIH WITH MILL AND SCRAPER, TAG PKR AT 8335' DPM, CIRC HOLE CLEAN, POH, LD DP, RU ATLAS E-LINE, RUN GR/JB TO 8334' WLM (NEW PBTD), POH (JB CLEAN), MU FB-1 PKR, RIH, SET PKR AT 8066' ELM, POH, RD ATLAS, MU COMPLETION ASSEMBLY AND RIM DAILY:S59,154 CUM:$810,385 ETD:$810,386 EFC:$715,999 REPAIR MUD PUMP MW: 6.8 DIESEL FINISH RIH W/ PKR ASSEMBLY. STING SEAL ASSEMBLY INTO FB-1 PKR, PRESS. TBG TO 500 PSI TO VERIFY. SPACE OUT WITH LOCATOR 1' ABOVE PKR, LAND TBG HANGER. PRESS TBG TO 2500 PSI TO SET HB PKR. SHEAR OUT SUB BLEW OUT AT 2500 PSI. RU SLICKLINE, SET SV IN D-NIPPLE BELOW FB-1PKR, PRESS TBG TO 2500 PSI F/30 MIN. PU AND SHEAR PBR WITH 100 M LBS, RELAND TBG HANGER, RILDS. PRESS ANNULUS TO 2500 PSI, PRESSURE BLED TO 2400 PSI IN 30 MIN. RU SLICKLINE, RIH RETRIEVE DV FROM GLM~7, REPLACE W/ 48/64" CV. TEST ANNULUS&TBG TO 2500 PSI, TEST SSSV, ND BOPE. NU TREE. TEST TREE. DISPLACE WELL TO DIESEL (NOTE: CAMCO 'TRDP' SSSV @ 1804', BROWN 'HB' PKR @ 7722', BAKER 'FB-I' PKR @ 8066', BOT '2B' PKR @ 8335', & TT @ 8370'.) DAILY:S72,879 CUM:$883,264 ETD:S883,265 EFC:$715,999 The above is correct Signature For form preparati~~ see Procedures M~J.j~ual Section 10, Drilling, Pages 86 and 87 Date 1Title /0-5 A,~OCIA'rE ENGINEER 'ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indelinite or appreciable length of time. On workovera when an official teat la not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting Ihe entire operation if space is available. District lCounty or Parish NORTH SLOPE ADL: 25640 WORKOVER t Accounting cost center code 1G-07 IWell no. Field ARCO Alaska, Inc. KUPARUK RIVER UNIT Auth. or W.O. no. AK3404 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. Old TO Released rig 09/07/88 ( 1 TD: 8851 PB: 8335 SUPV:DS Classifications {oil, gas, etc.) Producing method API: 50-029-20872 co. '%.0000 08/20/88 Complete record for each day reported NORDIC I n otal number of wells (active or inactive) on this Dst center prior to plugging and ~ donment of this we11- 1345 FRS ' lPrlor status~w.o. RIG RELEASED ~ MW: 6.8 DIESEL FINISH REPAIRING MUD PUMP, FINISH DISPLACING HOLE WITH DIESEL, PRESSURE TEST CASING TO 3500 PSI, BLED OFF PRESSURE, SET BPV, MOVE RIG OFF LOCATION, RELEASED RIG ~ 1130 }iRS, 9/6/88. PULL BPV. DAILY:S153,929 CUM:$1,037,193 ETD:S1,037,193 EFC:$716,000 tNew TD ~ Depth completion (single, duel, etc.) Potential test data Well no. tDate Pump size, SPM X length The above is correct Reservoir Choke size Producing Interval .~ Water % Signature ~ __ Io-5 For form preparati~ and distn'bution, Test time Gravity corrected Production Oil on teal Gas per day Effective date %SSOCIATE ENGINEER ARCO Alaska, Inc. Date: August 19, 1988 Transmittal #: 7264 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. 1 G- 14 Kuparuk Well Pressure Report 8 - 08 - 88 Amerada 3 H- 1 4 Kuparuk Fluid Level Report 8 o I 2 - 88 Casing 1 G-07 Kuparuk Fluid Level Report 8- 1 3- 88 Tubing I R- 15 . Kuparuk Fluid Level Report 8 - 1 3 - 88 Tubing I C-08 Kuparuk Fluid Level Report 8-1 2-88 Tubing .. Receipt Acknowledged: Anchorage ........................... Date: ............ DISTRIBUTION; D&M State of Alaska Unocal SAPC Chevron Mobil ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7225 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ^TO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. · Please acknowledge receipt and return ~30-15 Kuparuk Fluid Level Report · 30-10 Kuparuk Fluid Level Report t 2 D- 15 Kuparuk Fluid Level Report ~ 2A-06 Kuparuk Fluid Level Report ,, 1 G-07 Kuparuk Fluid Level Report · - 1 G- 08 Kuparuk Fluid Level Report , 1 G-15 Kuparuk Fluid Level Report ~ 31 - 01 Kuparuk Fluid Level Report ~ 31-1 2 Kuparuk Fluid Level Report · 2A-03 Kuparuk Fluid Level Report = 3 H- 14 Post Frac Job Report ' 2 B- 1 6 Bollom Hole Pressure' Survey ,, 3 J-1 0 Kuparuk Well Pressure. Report Receipt Acknowledged: 7-11-88 7-11-88 7-12-88 7-12-88 7-08-88 7-08-88 7-08-88 7-08-88 7-08-88 7-06088 7-09-88 7-03-88 3-08-88 Tubing Tubing Casing Tubing Casing Casing Casing Tubing Tubing Casing AIIo Frac A-10 PBU Amerad --'- ........................ Date: DISTRIBUTION: · D&M State of Alaska SAPC Mobil Unocal Chevron STATE OF ALASKA ALASI,',J..~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program ~J Plugging [] Stimulate ..~ Pull tubing/~Amend order ~ Perforatex Other 2. Name of OperatOr ARCO Alaska, Inc, 3. Address P. 0. 4. Location 1206' At top of 1505' Box 100360, Anchorage, AK 99510-0360 of well at surface FSL, 616' FWL, Sec. 29, T12N, RIOE, UM 5. Datum elevation (DF or KB) RKB 90 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 1(:;-7 productive interval 8. Permit number FSL, 1430' FEL, Sec. 29, T12N, R10E, UM 82-201 At effective depth 9. APl number 1146' FNL, 903' FEL, Sec. 29, T12N, R10E, UM 50-- 029-20872 At total depth 10. Pool 1120' FNL, 862' FEL, Sec. 29, T12N, R10E UM Kuparuk River 0il Pool feet 11. Present well condition summary Total depth: measured true vertical 8851 'MD feet Plugs (measured) None 7024 ' TVD feet Effective depth: measured 8784 ~MD feet Junk (measured) true vertical 6978 ' TVD feet 373' Vann Gun fish Top of fish ~ 8379' Casing Length Size Cemented Measured depth ~ueVerticaldepth Conductor 80' 16" 300 sx AS II 80'HD 80'TVD Surface 2457' 10-3/4" 1300 sx AS I I I 2487'MD 2367'TVD & 250 sx AS I Production 8808' 7" 730 sx Class G 8836'MD 7014'TVD & 250 sx AS I Perforation depth: measured 7978'-8013', 8217'-8238', 8253'-8273' true vertical 6417'-6442', 6588'-6603', 6613'-6627' Tubing (size, grade and measured depth) 3-1/2", 9. 3#, J-55, tubing w/tail (~ 8096' Packers and SSSV (type and measured depth) Camco TRDP-1AE SSSV @ 1897', BOT HB packer ~ 7817', BOT 2-B packer ~ 8060' 12.Attachments Description summary of proposal~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation A u q u s t 2 7, 1 9 8 8 o.._~ ..... ~-~ Wor].' P. epo~e~_ on 14. If proposal was verbally approved ~-'o~zQ"'u'"°"'~"z'/--~mo. Da-ted/~-//-.~//.--- ~ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 4~ ~~f- ~ Title ^ssociate Engineer d Commission Use Only (SA3/0010) Conditions of approval (JG) No. Approved by Form 10-403 Rev 12-1-85 Date Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI ~)RIGINAL SIGNED eY LONNIE C. SMITH ^pproved Copy Returned Commissioner by order of the commission Date Submit in triplicate Pre-Rio Ooerati°ns - KRU 1G-7 General Procedure 1. Obtain new BHP (both C sand only and A & C combined). 2. Set plug in D nipple to isolate A sand. 3. Cut tubing below blast rings and below second GLM between the paCkers. Ri(] Operations -- 10. 11. 12. 13. 14. 15. 16. 1. MIRU Nordic.-Kill well, pumping pills as neccessary. ND tree. NU BOPS. 2, Pull hanger to flOor, pick up a storm packer and set same 1' below the tubing head. Change out the tUbing head to 5000# equipment. 3. Pull storm packer. POH with tbg, changing the couplings to AB MOD. 4. GIH Picking up DP. Retrieve the top packer and tbg down to the cut made below the second GLM in the pre-rig operations. 5. GIH with wash pipe. Clean out any fill down to the bottom GLM. 6. GIH_with an overshot on 3-1/2" tubing;and fish the blast joints. 7. GIH with an overshot on 3-1/2" DP and fish remainder of completion from above the permanent packer. 8. GIH with packer plug. Set same in permanent pkr. Spot ±2300# of sand on plug to give ±100' of sand on top of pkr. Tag top of sand and i:K:::t-I. 9. Perf squeeze holes from 7944-7946. GIH with a pkr and sqeeze off same to isolate the C1-from the C3,4. ~' Drill out squeeze and test same. . Run CET to ensure isolatiOn GIH and clean out sand to pkr plug. Displace hole to clean brine. Pull pkr plug. ~ Make a 1-1/4~ tailpipe/scraper run to Clean out to pkr and down to the D nipple. POH LDDP. . Reperf the O1 and perf the C3,4. ' Run new completion with 2 retrievable pkrs. Release rig. Acidize the C sand after rig has been released. 7-1/16" 5000 PSI BOP STACK I I ANNULAR PREVENTER § PIPE RAHS BLIND RAMS 5 TUBIN6 HEAD ;;5 2 1, 16" CONDUCTOR SWAGED TO 10-$/4" 2. 11"-3000 PSI STARTING HEAD :~. 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5, 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSi DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI, 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP, 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. dO dULY 28, 1986 (N~ql~rbIP. RI~ 1~-~/4"~ ARCO Alaska, In,' Posl Office ..,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 2, 1987 Transmittal # 6049 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-3 1Y-14 1Y-5 1G-1 1G-7 2D-3 Pressure Report 'At Sand 8-20-87 100596H Static Gradient Survey 8-20-87 100556Y14 Static Survey 8-20-87 1005551Y5 Kuparuk Well Pressure Report(Camco) 8-24-87 Kuparuk Well Pressure Report 8-24-87 Kuparuk Well Pressure Report(Otis)'C' Sand 8-2-87 Alaska 0ii & Gas Cons. C0mmissirJn Anchorage Receipt Acknowledged: DISTRIBUTION: BPAE Chevron Mobil SAPC Unocal D&H ARCO Alaska, Inc. is a Subsidiary of AllanflcRlchfleldCompany STATE OF ALASKA ..~-" ALA----A OIL AND GAS CONSERVATION COL .~SSION 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 j~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360~ Anchoraqe, AK 99510 4. Location of well at surface 1206' FSL, 616' FWL, Sec. 29 T12N R10E At top of productive interval ' ' 1505' FSL, 1430' FEL, Sec. 29, T12N, R10E, UM A~-~'~iti'~N~-~,Pt§50'*-"~- --~-" FEL, Sec.29, T12N, RIOE At total depth 1120' FNL, 862' FEL~ Sec.29, T12N, RIOE 11. Present well condition summary Total depth: measured 8836' MD feet true vertical 7023' MD feet Effective depth: measured 8786' ND feet true vertical 6888' ND feet Casing Length Size Structural 82 ' 16" Conductor Surface 2687' 10.75" Production 8836' 7" xx~rxxxxx Perforation depth: measured 7978' -8273' MD true vertical 6410'-6610' TVD Tubing (size, grade and measured depth) 3.5", 9.2#, J-55 @ 8096' MD 5. Datum elevation (DF or KB) RKB 90 6. Unit or Property name Kuparuk River Unit 7. Well number 1G-7 8. Permit number Permit #85-201 9, APl number 50-- 029-20872 10. Pool Kuparuk Riw_r Oi 1 Pnnl Plugs (measured) None Junk (measured) None Cemented 300 X 1300 SX 730 SX Measured depth 80' ND 2687' ND 8836' ND True Vertical depth 80' TVD 2680' TVD 7023' TVD RECEIVED AUG i 9 i987 Alaska 0il & Gas Cons. 6ommissie~ Anchorage Packers and SSSV (type and measured depth) Camco TRDP-1AE @ 1897': Baker HB fa 7917; Rnf ?-R _Cd 8061' 12.Attachments Description summary of proposal,l~ Detailed operations program [] Treat w/3000 gals 12% HCl to remove scale Date approved 13. Estimated date for commencing operation August 20, 1987 14. If proposal was verbally approved Name of approver Date8/17/87 BOP sketch [] to the best of my knowledge Sr. Operations Engineer 15. I hereby certify that the fe~egoing is true andcorrect Signed ,~ Title Conditions of approval Commission Use Only [] Plug integrity Notify commission so representative may witness [] BOP Test [] Location clearance IApproval No. 7.- Approved by · - Commissioner by order of the commission Date ~""-/~0c"~ Form 10-403 Rev 12-1-85 Submit in triplicate2 Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 lA-14 1A-15 1A-16A Loo~ ATTACHMENI I I KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 Drill Site Well No. Log Date 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 lB Drill Site 1C Wel 1 No. lC-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8 - Lo9 Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Lo, 9 Date 1D-1 v 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 D-8 (ws-8) 5110/78 Attachment Page 2 Dri 11 Si te 1H Well No. Loq Date 1H-3 8/16/82 1H-4 8/13/82 IH-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. LOQ. Date lQ ~1Q-.5. ~~:.~_ 12/1/85 Drill Site 1E Well No. 1E-lA 1E-2 1E-3 1£-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 LOQ Date 8/19/81 8/}7/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 !1/5/81 10/27/8] ]0/21/8! 11/12/82 10/28/81 8/28/81 11/1/81 !1/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 !0/16/82 Drill Site Well No. Log Date 16 16-1 !G-2 16-3 16-4 16-5 16-7 ]G-8 Drill Site Well No. 9/7/S2 1F 1F-1 9/25/82 iF-2 9/28/82 !F-3 12/8/84 !F-4 10/13/82 iF-5 11/12/82 iF-6 3/12/83 !F-7 .~aska Oil A Gas ~ns. Loo Date 2/19/83 2/3/83 1/3!/83 5/29/83 !0/25/82 !0/28/82 ]1/19/82 5/7/83 Attachment II ,~-~ Page 3 Drill Site Wel 1 No. .Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~3~ 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 lZ~ 5/10/83 ~ 11121183 ~7/28/8~ - 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 12Cr~ 15~12/11/85 Drill Site 2Z' Well No. Lo9 Date t2Z~'~~_. 7/10/83 ~~,.q/22)'85 2Z-2 "6/24/83 7/19/83 2Z-3' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF: pg' 0052 Alaska Oil & Gas Cons. Comm..!::" Anchora? .--~- STATE OF ALASKA '-'--~ ~_~ " ALAS. JILAND GAS CONSERVATION ~ ~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL d(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-201 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20872 4. Location of well at surface 9. Unit or Lease Name 1206' FSL, 616' FWL, Sec.29, T12N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1505' FSL, 1430' FEL, Sec.29, R12N, R10E, UM 1G-7 At Total Depth 11. Field and Pool 1120' FNL, 862' FEL, Se¢.29, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 90' RKBI ADL 25640 ALK 2571 12. Date Spuddedl 2/26/82 13' Date T'D' Reached01/04/83 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns01/14/83 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'DVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8851'MD, 7024'TVD 8784'MD,6978'TVD YES [] NO [] 1897 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/$P/FDC/CNL/Ca], BGT, GR/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# U-40 Surf 80' 24" 300 sx AS II 10-3/4" 45.5# K-55 Surf 2487' 13-1/2" 1300 sx AS Ill & 250 sx AS I 7" 26.0# K-55 Surf 8836' 8-3/4" 730 sx Class G & 250 sx AS I 2~. 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) 8253' - 8273' 3-1/2" 8096' 8060' & 7817' 8217' - 8238' w/12 spf 7978' - 8013' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8149' - 8151' 400 sx Class G 7873' - 7875' 600 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD 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 SE[:' 1 7 1~ ~,~?,s.,~ u~ ~ G,:.Ls Cons. Commission .~nc'h0rarle Form 10-407 GRU1/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS TRUE VERT. DEPTH 31_ LIST OF ATTACHMENTS MEAS. DEPTH 7893' 8013' 8191' 8355' 6356' 6443, 6684' FORMATION TESTS Include interval tested, pressure data. all fluids recovered and gravely, GOR, and time of each phase N/A Workover Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg 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 /J ARCO Oil and Gas Company Daily Well History -Final Report Instructions: Prepare and submit the "Final Rel~ort" on the first Wednesday after allowable has been assigned or welt is Plugged, Abandoned, or Sold. "Ftnal Reflert" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion end repre~elltlUvl;.:te~t data In blocks provided. The "Final Reflert" form may be used for reporting the entire operation if space is available. District Field I County or Palish Alaska ILease or Unit Kuparuk River I Title AFE: Exp 204625 - Cap 103p85 Auth. or W.O. no. Operator ARCO Alaska, Inc. NOrth Slope Borough Accounting cost center code State Alaska ADL #25640 IWell no. 1G-7 W/O Recompletion Spudded or W.O. begun Workover Date and depth as of 8:00 a.m. 7/13184 A.R.GO.W.I. 56.24% Data 7/08/84 Complete record for each day reported Iotal number of wells (active or inactive) on this i est center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I - 0300 Hrs. 8379' DPM PBD, RR Lnd tbg in hgr, tst tbg 2000 psi, OK. Set BPV, ND BOPE, NU tree & tst tree to 250/5000 psi. Pull BPV. Circ 8.6 NaC1 f/well w/30 bbl diesel, followed by crude. Pressure csg to 500 psi, close SSSV & tst 15 min, OK. Open SSSV, tst tbs 2000 psi, OK. Shear ball @ 3500 psi. Set BPV. RR @ 2400 hfs, 7/12/84. 2B Pkr @ 8060.5' - "D" Nipple @ 8083' - Tbg Tail @ 8096' Old TD r New TD I PB Depth 885].' (1/5/83) 8379' Released rig I Date [Kind of rig 2400 Hrs. - 7/12/84 Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per dsy Pump size, SPM X length Choke size T.P.' ' C.P. Water % GOR Gravity Allowable Effective date corrected The above IS correct Drilling Superintendent ARCO Olfand Gas Company Well History- Initial Report- Dally I~U~"~I~-Pr~ mhd ~4Jbml~ Ule "lnH~t R~' on ~e fl~ Wedne~ m~r · well Is ~udded or wooer o~tlonl D~ ~ prior to s~ddl~ ~uld ~ ~~ ~ ~ ~ giving Inclusl~ d~tet only. District ' ;~ ~ -~' ~ ~ ~ A[as~ ~ ~o~h Slope ~o~ou~h Field Lea~ or Unit Kuparuk River ~L #25640 ~E: ~p 204625 - Cap 103985 ~ Recompletion IState Alaska rail no. 1G-7 W/O Operator ARCO Alaska, Inc. IA,CO W.,. 56. 24% Prior status il a W.O. Spudded or W.O. begun [Da~e IHour Workover 7/08/84 0300 Hrs. Date and depth as of 8:00 a.m. 7/08/84 thru 7/09/84 7/10184 7/11/84 7/12/84 Complete record for each day reported 7" @ 8411' (TOF) 8.6 NaC1 Accept rig @ 0300 hrs, 7/8/84. Pull BPV, kill well by spotting 9.4 ppg calc carbonate pill dn tbg, bullhead pill to perf. Shut dn & observe well. ND tree, NU &tst BOPE to 3000 psi. Pull & LD 63 jts tbg & compl jewelry. RIH w/OS. 8411' TOF 7" @ 8411', CBU 8.6 NaCl Fin RIH, tag top of slick jt @ 7790'. Set dn on pkr & push dn hole to 7893'. Spot 30 bbl calcium carbonate @ 7893', POOH w/pkr. RIH w/bit & scrpr, tag up @ 8271' DPM. Wsh dn to 8281' DPM, no torque. CBU to POOH. PBD @ 8379' DPM POOH, LD DP 8.6 NaC1 RIH w/Bkr R-3 pkr, set @ 8092', no comm bet sands, POOH. fsh'g tl assyo RIH, push TOF dnhole to 8379', POOH. PU 8379' DPM PDB, Spacing out Wt. 8.6, NaC1 POOH, LD DP & fshg tools, no rec'y. RIH w/6" gage ring & jnk bskt, tag up @ 8371' WLM. MU BOT 2-B pkr & set on WL @ 8060.5'. RU, rn 3-1/2" compl assy. Sting into pkr, drop ball, set pkr w/2500 psi. Tst tbg w/2500 psi f/15 min; OK. Press ann to 2000 psi f/15 min; OK. Shear SBR @ 120,000#. Space out tbg. The above Is correct ARCO Alaska, Post Oft=,.= Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1G-7 Dear Mr. Chatterton- Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer GRU8/L94-tw Enclosure If RECEIVED AUG 1 6 1984 Alaska 0il & Gas Cons. C0mmissJ~n Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ~.~-., STATE OF ALASKA ALAS .OILAND GAS CONSERVATION _ .)MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO Alaska, inc. 82-201 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-20872 4. Location of Well Surface: 1206' FSL, 616' FWL, Sec.29, T12N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc'.) RKB 90' 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1G-7 OTHER [] 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing {Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig (~ 0300 hfs, 07/08/84, Pulled BPV. Spotted 9.4 ppg Calcium carbonate pill down tbg to cut pipe 7791', Closed ann, Bullheaded pill to perfs w/400 psi ~ 1/2 BPM. Observed well - tbg static. Circ oil & gas out of ann, Well killed, Set BPV, ND tree. NU BOPE & tstd to 3000 psi - ok. Sheared SBR, P0H & LD tbg & completion jewelry. RIH w/overshot & tagged top of slick jt ~ 7790'DM, Set wt down on pkr & pushed downhole to 7893' (Lost 40 bbls fluid) Spotted 30 bbls calcium carbonate pill @ 7893' POH - recovered ' ' pkr. Washed down to 8281'. CBU. RIH w/R-3 pkr & set ~ 8279'. (Tagged top of fish ~ 8281'DPM.) PU to 8092', set pkr, injected 50 bbls brine into "A" sand @ 2500 psi, 1-1/2 BPM. No returns on annulus. POH & LD pkr. RIH & tagged top of fish @ 8281'DM. Jarred w/bumper sub to drive grapple over fish - fish started downhole. Jarred & pushed fish to 8379'DM. Circ hole clean. Recovered small amt of sand. POH & LD fishingl tools - no recovery. RIH w/6" gauge ring.& junk basket. .Tagged up ~ 8371'WLM. RIH & set 2-B pkr on W/L ~ 8060'. Ran 3-1/2" completion assy. Dropped ball & set pkr. Tstd tbg to 2500 psi - ok. Sheared SBR ~ 120,000t/. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Tstd packoff to 3000 psi - ok. Pulled BPV. Disp well w/30 bbls diesel followed by crude oil. Set BPV. Secured well & released rig @ 2400 hrs, 07/12/84 14. I hereby~ that the foregoing is true and correct to the best of my knowledge. / / ~.ff--f.-~¢(///~/////~~~~'_~~' Area Drilling Engineer Signed _ Title Conditi~is of APpeal, if any: RECEIVED AUG 1 6 Alaska 0il ~ Gas O0ns. o0mmissi0a By Order of Approved by COMMISSIONER the Commission Date Form 10403 GRU8/SN34 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alask c. Post Ollice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 10, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent following wells at the Kuparuk River Well Action notices on the Field: Date Performed 1F-11 Fracture 6/25/84 1F-12 Perforate 6/29/84 1F-12 Fracture 7/08/84 1G-6 Re-perforate 8/01/84 1G-7 Fracture 7/29/84 1G-8 Fracture 7/23/84 2B-7 Perforate 7/24/84 2B-8 Perforate 7/25/84 2B-9 Perforate 7/27/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL / kmc Attachment (Duplicate) RECEIVED 0il & Gas Cons. Commission A~chorag~ ARCO Alaska, Inc. is a Subsidiary o! AtlanlicRichlieldCompany STATE OF ALASKA ALASKf~ OIL AND GAS CONSERVATION uOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, I NC, 82- 201 3. Address 8. APl Number P, O, BOX 100:360, ANCHORAGE, ALASKA 99510 5o- 029-20872 4. Location of Well SURFACE LOCATION' 615'FWL, 1207' '!'12N, R109E, UM 5. Elevation in feet (indicate KB, DF, etc.) 60' (RKB)90' FSL, Sec. 29 12. I 6 . Lease Designation and Serial No. ADL25640 ALK 2571 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation J~ 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 July 29, 1984, the "A" sands of Kuparuk well 1G-7 were hydraulically fractured and propped to improve production. The treatment consisted of 180 BBLS of gelled water as pad and carrying fluid and 10,400 LBS of 12/20 sand as proppant. Prior to pumping, equipment and lines were tested to 5000 psi. sand was tagged with R.A. tracer to aid determination of job performance. The RECEIVED .AUG 1 ]984 Alaska 0ii & Gas Cons. 14. I hereby certify that the foregoin~ i~true and correct to the best of my knowledqe. Si§ned Title OPFRAT I ObIS COORD ~ N^TOR The space below for Commission use 8/10/84 Date /~ / (:~,~ 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, In, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: .. Attached are notices-of intention to 1G-1, -2, -3, -4, -5,.-6, -7 and -8. If you have any questions, please call fracture Kuparuk wells me at 263-4253. "-~ Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED J U L .[ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC, 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 615'FWL, 1207' FSL, Sec. T12N, R109E, UM 29 5. Elevation in feet (indicate KB, DF, etc.) t~0' (RK_R) 90 ' I 6 . Lease Designation and Serial No. ^DL?56~_0 ALK 757! 7. Permit No. 82-201 8. APl Number 50- 029-20872 12. 9. Unit or Lease Name KUPARUK RIVER UN IT_ 10. Well Number 1G-7 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL _POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1G-7 be hydraulically fractured and propped to improve production. treatment uses gelled water as the pad and carrying fluid sand as the proppant. The and 1 2/20 Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre-post frac logs are included in the treatment program. Fluid. Gel led Water BBLS 167 Proppant- 12/20 sand LBS 7500 ANTICIPATED START DATE: July 29, 1984 Subsequent Work' Reported tm' Form No./~ T ~d?) Dated 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~~ ~/'~/~/'/~ Title KUPARUK The space below for Commission use RECEIVED J U L 1 219 4 Alaska 0il & Gas Cons. Commission Anchorage Date 7 / 1 0 / 84 OPERATIONS COORDINATOR Conditions of Approval, if any: IIRIGIII~L' ~ttlil Approved by. COMMISSIONER Approved Copy Returned / By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AR(~O Alaska, Inc. ~' Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1G-7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1G-7 to a selective single completion. Since we expect to start this work on July 6, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ~xcT. B<. 'Kewin Area Drilling Engineer JBK/JG/tw GRU8/L34 Enclosures RECEIVED JUL 0 6 Alaska 0il & Gas Cons, C, ornmj~ion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~.,L AND GAS CONSERVATION CC..,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 615' FWL, 1207' FSL, Sec.29, T12N, R10E, UN TD: 2326' FNL, 1478' FEL, Sec. 29, T12N, RIOE, UM COMPLETED WELL I 6. Lease Designation and Serial No. ADL 25640 ALK 2571 7. Permit No. 82-201 8. APl Number 50- 029-20872 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' OTHER [] 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1G-7 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0il Pool 12. 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 ~L~ 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 Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1G-7 to a selective single completion. The procedure will be as follows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A retrievable packer will be run to verify zone isolation between A and C sand. 4. The well will then be completed as a selective single. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: July 6, 1984 RECEIVED SUbsequent Work Reported o,, JUL 0 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby,(~y that the foregoing is true and correct to the best of my knowledge. [/.~.~ ,~'~',$~/ // ~.~ /"~"~'~- Area Drilling Engineer Signed _ ~ . ~ Title - The spa Io ission use Conditi6ns of App o~.~ff', if any: Date ~.pgroved Copy Returned St/ 11~#~!£ IL $1JllIll By Order of ApprOved by COMMISSIONER the Commission Date Form 10-403 GRU8/SN12 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate following wells at the Well Action 1F-1 Fracture 1F-3 Fracture 1F-5 Fracture 1F-9 Perforate 1F-9 Fracture 1F-1 0 Perforate 1F-1 0 Fracture 1F-11 Perforate 1F-1 3 Perforate 1F-1 4 Perforate 1F-1 4 Fracture 1F-15 Perforate 1F-15 Fracture 1F-16 Perforate 1G-7 Choke 1G-10 Perforate 1G-10 Fracture 1G-12 Perforate 1G-12 Fracture are subsequent notices on the Kuparuk River Field: Date Performed 6/10/84 6/11/84 6/12/84 6/16/84 6/19/84 6/14/84 6/18/84 6/19/84 6/19/84 6/22/84 6/23/84 6/17/84 6/21/84 6/19/84 5/4/84 5/29/84 5/3O/84 5/29/84 5/31/84 ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichlieldCompany RECEIVED JUL 0 0il & {~as Cons. C0mmlssion Anchorage ~..-.-.-,., STATE OF ALASKA -- ALASKA .LAND GAS CONSERVATION C,,,. ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL r)(] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, :INC. 82-201 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20872 9. Unit or Lease Name KUPARUK RIVER UNIT -4. Location of Well SURFACE LOCATION: T12N, RIO9E, 5. Elevation in feet (indicate KB, DF, etc.) 60' (RKB)90' 12. 615'FWL, 1207' FSL, Sec. 29 UM t 6 . L8ase Designation and Serial No. ADL25640 ALK 2571 10. Well Number lC-7 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other 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 May 4, a pressure differential "storm" choke was run well 1G-7. The tubing retrievable SSSV was damaged and controlled wireline retrievable SSSV could not be run. provided unsatisfactory performance and was rerun on June The well is scheduled for workover to replace the SSSV. in Kuparuk a surface The choke 15, 1984. RECEIVED JUL 0 3 Alaska 0il & Gas Cons. C;0mmissi0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ..... OPERATIONS The space below for Commission use COOR~iNATOR 6/26/84 Date ,.~ O 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 STATE OF ALASKA ALASK )IL AND GAS CONSERVATION L....~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] · COMPLETED WE L L)~] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-201 3. Address 8. APl Number P, O, BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20872 4. Location of Well SURFACE LOCATION' 615' R~/L, 1207' T12N, R109E, UM 5. Elevation in feet (indicate KB, DF, e~c.) 60' (RKB) 90 ' 12. FSL, Sec. 29 I 6 . Lease Designation and Serial No. ADL25640 ALK 2571 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-7 1 1. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I~ 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 (Qlearly state all p'ertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Install a pressure differential storm choke. The tubing retrievable subsurface safety valve (SSSV) flow tube is damaged and we cannot run a surface controlled wireline retrievable SSSV. Expected installation date is 5-1-84. (Note- verbal approval by Jim Tremble 4-30-84) Subsequent Work ~el:~rte~ ECEIVED MAY o 1 1984 -,,~.~ .., '~;; ~. C;as Cons. Commisslorl Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/I~/I/~ The space below for Commission use Conditions of Approval, if any: Approved by Title KU PARU K OPERAT I ~"'~' ..... l NATOR Approved Cop':,, ~aturned By Order of COMMISSIONfiR the Commission Date 413~184 Date ~_. '/ .~__~_ ¢ ¢. .__ Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING · TRANSMITTAL TO- William Van Allen Transmitted herewith are the following- FROM: D.W. Bose/ShelbS J. Matthews WELL NAME' ~__~ PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE~PY . . PT ACKNOWLEDGED' · I/PLEASE RETURN RECEIPT TO' ARCO ALASKA, ATTN.· SHELBY J. P.O. BOX 360 ANCHORAGE, A'K. MATTHEWS .-:AFA}3!I ii'i]'.'.i':.~.~c 995 o ARcO~Alaska, Inc. Post Office B(~.. Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1983 'Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr-. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well Ravik State #1 #1 A1 so enclosed are well completion reports .for' 1-24 1E-21 2-8 . 1E-22 7-18 ~1F-1 7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 · 1E-20 Tract Well 24-11-14 .We also are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska. Inc. Is a subsidiary of AllanticRichfieldCompany ,.--,~--~ STATE OF ALASKA ~ ---'- ALAS_ . ,.. ,_ AND GAS CONSERVATION ,. ,..,":.'IISSION WELL COMPLETION OR RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-201 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20872 4. Location of well at surface -- 9. Unit or Lease Name 1206' FSL, 616' FWL, Sec. 29, T12N, R10E, UN l-lOCATIONS Kuparuk River Unit At Top Producing Interval I VERIFIED 10. Well Number 1505' FSL, 1430' FEL, Sec. 29, T12N, R10E, UM l~,¢rf_ ¢- 1G-7 At Total Depth :,_.~_,'.~__~__-_ _ .:.i 1 1. Field and Pool 1120' FNL, 862' FEL, Sec. 29, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool 90' RKB ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1 2/26/82 01/04/83 01/14/83I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 8851 'MD,7024'TVD 8784'MD,6978'TVD YES IX~ NO [] 1901 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/FDC/CNL/Cal , BGT, GR/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 80' 24" 300 sx AS II 10-3/4" 45.5# K-55 Surf 2487' 13-1/2" 1300 sx AS Ill & 250 sx AS I 7" 26.0# K-55 Surf 8836' 8-3/4" 730 sx Class G & 250 sx tS 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) 8253 ' -8273 ' 3-1/2" 7870 ' 7832' 8217'-8238' 12 spf 7978~ -8013' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8149'-8151' 400 sx Class G 7873'-7875' 600 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) -Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None _ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 7893' 8013' 8191' 8355' TRUE VERT. DEPTH 6356' 6443' 6570' 6684' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engr. 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". 1G-? DRILLING HISTORY NUHydril & Diverter. Spudded well @ 1045 hfs, 12/26/82. Drld 13-1/2" hole to 2514'. Ran 61 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2487'. Cmtd 10-3/4" csg w/1300 sxAS III & 250 sxAS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NUBOPE & tstd - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 406 psi - ok. Drld 8-3/4" hole to 8618'. Ran DIL/SFL/SP/FDC/CNL/Cal f/8603' 10-3/4" shoe. Ran BGT f/8603'-10-3/4" shoe. Cont drlg 8-3/4" hole to 8851' TD (01/04/83) Ran 227 jts 7" 26 0#/ft K-55 BTC csg w/shoe @ 8836' Cmtd 7" csg w/370 sx Class G & 360 sx Class G extended. Disp well to NaC1. Instld ?" packoff & tstd to 3000 psi - ok. Ran Gyro. Arctic packed ?" x 10-3/4" ann w/500 bbls H20, 230 sx AS I & 99 bbls Arctic Pack. Ran GR/CBL £/8660'-2000' Perf'd 8149'- 8151'. Set cmt retainer @ 8030'. Squeezed 400 sx Class G cmt. Per£'d 7875'-7873'. Set cmt retainer @ ???S'. Squeezed 400 sx Class G cmt. Drld cmt & retainer. Drld cmt to 8000'. Tstd csg to 1S00 psi - lost 400 psi in 30 min. Set cmt retainer @ ??30' & tstd - ok. Pumped 200 sx Class G - squeezed. Drld cmt, cmt retainer & more cmt to ?899'. Tstd perfs (?8?5'-?8?5') to 1000 psi - ok. Drld cmt f/7899' to cmt ret @ 8030'. Tstd csg to 1000 psi - ok. Drld cmt ret @ 8030' & cmt to 8170'. Tstd csg to 1000 psi - ok. Drldcmt to 8784' PBTD. Tstd csg to 1S00 psi -'ok. Ran CBL. Ran 5-1/2" completion assembly w/tail @ ?8?0', pkr @ ?832' & SSSV @ 1901'. 'Tstd hanger & packoff to 3000 psi - ok. Disp well to diesel. Set pkr. Closed SSSV. Dropped perf bars & perf'd. Flowed well & SI. Dropped ball & press. tbg to 2600 psi to release VannGuns. Instld BPV. Secured well & released rig @ 0400 hrs, 01/14/85. JG' llm o2/o3/83 ,I . ;~PLET I ON'REPORT eu.wv :ADIUS OF CURV.TURE HETHOD OF COHPUTATI-OH :OHPUTEO FOR SO I BY OCEANTECH(FH L IHOSEY TRUE DRIFT YERT[CAL RHGLE DEPTH D H RECORD OF SURVEY DRIFT DIREC DEG, TOTAL COORDINATES .JAN. 83 KUPRRUK K8 ELE¥ 9:0, FT, JOB HO 1,4~4 CLOSURES D,I. STANCE ANGLE D H ..!boG: LEG SEVERI.TY bEG/! O:OFT , ,0.0 f.O0 ~ ~0'0. :00 30:0,0 0 4:,00. :0 0 5~0:0.00 "90,00 'N ,~:OE 10,0'0 H75.72E 'ltO,O.O. H76,GGE 2'1 O, O0 835., 35W 31:0, '0~0 971 . 78E 41 O. '0:0 NS,O, 37E 600.,0~) 51 0,00 85 O. 78E 699,99 ': 6:09,99 878,47E 799,99 ,'7:09,99 NS2,47E 899,98 .809,98 H22,9'OE 999 .' 98 :~9'09,96 H22,, 32E t'1.00" 2 43 "1'~099,92 1:,i0:09,92 H4'O,OSE 1,2.~1:0 :. 4 55 11. 99.69 1 '1:09,69 N41 ;~OSE 'i3~"" ': 7 23' '1299,1"1' 1209.'1'1 H4'I,35E 14:0:0. I9 .7 1397,93 1 3:07,93 N44,85E T580 '1:3 7 1495,87 1 405.87 N48,72E I6~0. '15 39 1592,.73 15.02,73 H45,70E 47~0,0"18 2 1688,44 1598,44. N42,93E :~,?i'900,23 5 1'075,85 1705.e5 H42,~SE ~1~0 30 ~0 2054.10 ,l:9~d. 1'0 Hd~,e'OE .,~OO 3~ 38 21'3~.53 ~'04~.53 H4~. 23~e 35 49 ~22~,20 2'13~.~'0 H4d · ~.,0. S .,i02 N ..'t N .'1 S .1'1: N 1,36 N 4,'12 N 9,18 N 17,24 N 28.34 N 42,'t3 H 59, .~..0 N 79.73 H '1!:03,20 H 130,84' N 162.,2:0 N 197,39 H 235,46 H 275,93 N .07 E · 4:0 E .54 E ,00 S 90 0 0 W .07 N 75 43 '0 E .41 N 76 6 49 E ,.55 S 77 47 ,~i7E .85 $ 52 15 16 E 1,29 S 64 21 :0 E 42'.;ientific 1,ss s e6 12 st E .4~6 'i5 73,4'0 N 88 9 37 E 3.92 E 5,.59 E 9.92 E 16.98 E 27,37 E 42. !04 E 6;0.26 E 8:0.50 E · 1702,'83 E t2.7,82 E I56.52 E 189 .'02 E 224,4'0 E 2.63,45 E 4.15 N 70 53 34 E 6,95 H 53 36 41 E 13,~;1 H 47 13 15 E 24,'19 N 44 33 32 E 39,4~0 N 413 59 44 E 59,51 N 44 56 lib E" 84,34 N 45 36 24 E 11,3.3!0 H 45 16 36 E '1.46,04 H 44 45 38 E '182,91 N 44 19 54 E 2'25.,4'1 N 43 58 42 E 2?3.3:0 N 43 45 36 E 325,27 H 43 37 17 E 381',5',0 N 43 4'0 29 E , ,':083 ,217 .217 ,400 ,.400 ,150 .200 , '167 · :050 ,45:0 I. ,717 2 .'2,0:0 :~. 46:7 2, ?36 3,007 2.,543 2. 398 2,183 2,869 4, '168 2, .750 2,634 3. 256 · · . 'SECT I ON DISTANCE 2 3.93 6.94 13,46 23,98 39 .'~0'0 59. '04 83.79 · 12.48 '144., 82 : '18.1., 20 ..... ::" 223 ,'11 2,7:0.37 321 .66 37.?. 33 ,il . ) ~Rco KUPARUK I'-G-? GYROSCOPIC SURVEY .JOB .HO 1.494 0 RECORD OF SUR~EY ..!.i.,~.. TRUE lEfts. DRZFT VERT]CRL SUB DRIFT )EPTH RHGLE DEPTH SEA DIREC D H DEG. 2~9 3.949 23~1','1B 2211,18 N45,886 25~ 42 14 2376,62 2286,62 N46,836 260~ 43 33 2449.,.E8 2359.88 H46.,826 27~ 43 58 2522'.,.'1"1 2432,11 N46,786 '458,15 N TOTAL COORD~HflTEG .. 317e,g4 N 3~?,'1.2 E 364,24 H 354,62 E 4:1!0,81: H 4~4,;.25 E 454.,67 E CLOSURES DXSTANCE RHGLE D 442,7? N 43 55 5 E 5~8,36 N 44 13 59 E 526,35 N 44 3:2 2~) E 645,47 H 44 46 $2 E '28~)0 44 '1t: 2593,95 ' 25:03,95 H47,'136 5!05,63 'N 5;05.51' E :71'4,98 H 44 59 34 E 29~'.{) 44't7 2665.6:0 25~5,69 H47,226 553,~ H 556..67 E 784,69 H 45 11 13 E .:',~:0~.'..~44 16 2737,2~0 264'7,2,0 H4.7,'136 6~0'0, . 6~.7,8.7 E 854.,47 H 45 2:0 57 E ,~2~8 45 49 ~87e.42 2788.43 N46,3,0E' 743,e~~~)~.~iantif~e,,~ 32 N 45 52 22 E '.33~ 4? 2 2947.35 2857.35 NSO,;O2E . .~ ,, . ' 11,4~,g2 N 46 6 25 E "' nat,, '.,~45 H 46 31 lO E '34~ 46 19 3~'1.5.,96 2925.,96 H49,GSE ~:35G~ 46 '13 3085,~9 2995,~9 H49.,~26 -36~ 46 47 3'1:53.93 3'063,93 H5~,376 '37~ 46 35 3222,.53 3132,53 H50,926 '~38~.4'6'31 3291,30 3201o30 H51,376 79!. 83? 884 9310..67 N 908,99 E 976.2't N 1~'45,,.52 E '1358.~3 N 46 44 24 E 1'43~,.42 N 46 57 48 E 39.$~'.45 56 336~.49 3270.49 NSI..'13E 1~02'1',41H '1.1~0t.,83 E '15~2,,.44 N 47 10 9 E .4~, 45 55 3439.:05 3.340,~5 H51,856 1::0~,14 H '1'1.58.105 ~ .,.1.574,~8 H 47 21 58 E .:'42:00:4~ 4;0 3569.4,7 3479,47 H52..'156 '1.154.4~ N 12,?'1.~0'1 E 17~1',7,i05 N 47 45 2 E ;"~.~.:0~0'45 '1~" 3639,66 3549.~66 H52,326 '1198,G9 N 1327;31.-E. 1788.,~07 H 47 55 44 E 44~9 44 '1 3~19.88 3620,88 H~2.,256 1~41~4 H 1382'85 E 1'85$,,~7 H 48 5 36 E .4590 44 '1"1: 3782.,69 3692.'69 H52.,336 '1283.,6~ H 1437,9:0 E ~ '1927,49 H 4~ 14 41E 46~0 44 2 3854,49 3764,49 H52,456 '1326,~8 H 1493,~04 E 1996.91H 48 23 21E 47~0 43 15 3926.86 3e36,86 H53,~026 1367,87 H '1547,96 E 2~65~73 H 48 32 3 E 48~'43 'le 3999.?4 39.09,74 H53,2'06 1408.97 H '16~:02.72 E 21:33~."99 H 48 4:0 5'1 E 49~0'42 58 407~,80 3982,80 H53,736 :1449,62 H 1657,59 E 22~2..~4 H 48 49 45 E 50~ 42'5i0 4146,05 4~056,05 H53..,326 1,~0.~.~8..,N ....... ..,..~Z.t',2.,32,,E~...~..~. 2269.89 N 48 58 It E 51~42 '16 421'9.72 4129,72 H53,236 1530~,52 H 1766,5.3 E 2337,'33 H 49 5 39 E .f DOG.i LEG SE¥ER]:TY ~ DEG/'I ~ OFT 4 ,Gl.? 2,454 '1.317 ,417 ,275 ,.~44 ,853 .974 -' 1,525 ., .395 ,,.,637 .. 352 ., 246 ,596 ,370 ,112 ,, 507 I. 150 .1,71 .160 · .120 ,318 ,234 ,568 'SECTTOH DZSTRNCE 438;21 503.5O 5 ? 1 · 2.? 64'0,13 709,4.0 778,9'0 84 8 .' 4,'4 91 O, 49 989, 55 t 06'1 · 9 0 'l 1. 34.57 12.06 ,.74 '1279,23 1351 . 1424-, 55 14'96.75 · t 568,59 1640.36 1,7'1 '1 · 98 1783, .', 20 "' ~:''' ': 1853 . 4!0 1 g22','99 1992', 6,0 2:061 , 61 2,13 0 · 06 2190.33 2266.,,30 2333.99 ~RCO "KUP;IRUK I GYROSCOPZC SURVEY 0 *lOB HO 1-494 0 6 JAN 83 , } , RECORD OF.SURYE¥ TRUE HEAS,. DRZFT VERTICRL SUB , DRZFT TOTRL'COORD~iH~TE8 DEPTH ~NGLE DEPTH SE~ DZREC O H DEG, ~2~ 41 56 4293.92 42'03,92 N53.4.?E 1'5Z0,54 H 1820,31'E · 53~ 4'1 28 4368.58 4270,58 H53,37E 1:61.:0,.19 H 1873.73 E .54~9 4'1 6 4443,73 4353,73 N53,SBE. :t649,.46 H 1926.75 E i;:~,~59~4~ 3~ 45'19,43 4429,43 H53.43E '16~8,,32 H t979.28 E ~'.,:;~E~4~ 13 4595.63 45:05,63 N53',57E 1.,726,,83 H 2~3t.,34 E '57~.39 4~ r4672'3~ 4582'30 N53'.73E ~89~ 38 46 4749'77 4659.77 H53'"63E '~599~ 38 49 '482~'72 4737'72 H53'8~E . 60~ 38 5 49~6.~3 48'16,03 H53,8?E 6'1~' 37 55 4984.83 ~894,83 H53'~78E 62~ 3~ 52 5063,75 4973...75 N54,,88E 6.3~ 36 36 51,43,37 5053.37 H53.,~eE 64,9,9 39 1t: 5222.28 5t32,28 N53,30E C. LOSURES D ~.TI:tHCE ;INGLE D H DOG LEG 8EYER1T¥ iDEG/I:OOFT 24G4.'19 N 49 12 46 E 247~.54 H 49 1'9 33 E 2536,35 H 49 26 '1E' 26:0't,'53 H 49 32 9 E 2666~'I4*H 49 37'56 E l?64.,E~H. 2~83.~4 E 2739.t9 H 49 43:35 E .1.8~2,~1'H. 2:133.99, £. 2793,,26 N 49 48 58 E 65~9 39 56 5299,37 52i09,37 N53,,65E* 2058,53N 24e3,,57 E 3225..?~ N'50 2,0 45 E :'~6~ 39 3'1' 5376,29 5286,29 N54,!OSE 2096,2t H 2535,"t8 E 3289.57 N"5~O 24 5'1 E ~',;,,,i~:~.39 ~2 54~3.23 5363.,23 H54,~55E 2'133.4.7 H ' 2587.,~$ E 3353,29 H 5:0 29 19 E iii,"6~ ),:39 33 553:0.16 544'0,'16 HS.5,2:OE 217~0.22' H 26,39,.'31E 34'I,6.99 H 50 34 ~4 E 69~9 40 t7 5606.86 55,16,86 N~5,?3E 22,:06,'6~ N 2~92;.t, 7.E ,348~,93 H 5'0 39-38 E :70~ 49 9 5683.22 5593,22 N56,3OE 2,~,.~:~.,,,69~,.,N ......... 2~45,.21"E: 3545,22 N 5'0 45 29 E 7t:~ 4~ 18 5Z59,57 5669.57 H56,,43E 22?8.46 H 2759,48 E 72~0 41' 110 5835.35 5~45,35 N56,8'OE 23'14,36 N' 2853.97 E ,73~0 40 47 59'1,~.85 582'0,8~ N56,9?E 235.0,19 N 29~08,,,89 E 74~ 41 ? 5986.38 5896,38 H56,43E 2386;17 H 2~63,,,67 E '759~ 49 38 6~61.99 597J..99 H56,9,0E 2422,,13 H 3~18,,34 E ,76~ 41 1:0 61'3,?.58 6i'047,58 H56,~O3E 2458,3~ H 3~72,,.92 E '77~ 41 38 '6212.59 6122,59 N55,42E 2495.54 N 3'127,.,5Z E 79~9 41 49 6287.22 6197..22 H55.48E 2533,29 H 3;1~2:,*'38 E !!~;~909 43 t3 6368,93 62,?0,'93 H55.,35E 2571,65 H 32,38.!02 E 36,'09 .' 5,0 N 5,0 51 30 E 3674,43 H'5'0 57 37 E 3739,65 H 51 3 5~ E 39':04,'88 H 51 9 39 E 38,7,9,':03,H 51 1,5 14 E' 3935,23 H 51 20 26 E 4:001,".'1:? H 51 24 46 E 4:067,'57 N 51 28 44 E 4"1'34,'99 N 5'1 3;2 35 E .349 -,469 ,378 ,6:03 ,289 ',554 ,9,01'. ,,.082 .734 .170 ,417 1.4'19 2.,585 ,764 ,.452 ,399 ,412 ,766 .160 .881 ,39'0 ,'405 ..522 ,652 .54'0 ,186 [ SECT ! ON DZST;INCE - 240'1, :02 246? .53 2533,49 ,. 2598,8'1 266'3., 55 2727,73 ?eo.e3 2853,56 2915.71 297? .25 3:038.62 3 099. 'l 0 '3224,1 ? 3351,87 3415.68 3479.74 3544,16 3608,57 3673.62 3738,97 38'04.3 ] 3869.55 3934,83 4000.84 4,067; 28 4.134 ,..75 RCO KUPARUK l-G-?' ' GYROSCOPXC SURVEY RECORD OF.SURYEY JOB HO 1,4~4 ,' TRUE IE~S. DRZFT VERT.]:C~tL ~UB DRIFT TOTAL'.COORD. i:.H~IT'E.S ~EPTH RNGLE DEPTH SEiki DXREC D H DE~, D H . , . ~0:~9..,,.43 52 6433.41 6343,41 H54.92E ~t.?~.,~._32~,~'.,,~..,,.42~3'.74-N '51 36 7 E "~'~=i~'.44 "34 65~5,~08 6415.~06 N54.'~eE 2651,52 N .... ~'3'JJ~31 E /- 4273;39 N 51 38 57 E B2~9 45 22 65.75,84 64~5,64 H53,83E 2693,,'1'~ H 34-08,46 E .4344,'~'1..H 51 41 12 E 83~Q 45 44 6645,86 6555,86 H53..72E 2735,29 H 3466',~4 E 44t.5,34 H 51 43 '14 E 84~ 46 5 67'15,45 6625,45 .N55,8~E 2.776,72 N 3524,.71 E 4487,~06 N 51 46 9 E 95~ 46 3~0 6784,54 6694,54 H56,,63E 28t.6.9 N 3584,79 E 4559,1'3 ~6~ 47 9 E852.97 6762.97 N57.,98E 2856, N 3646,17~ E -4631',73 N 51 55 33 E [HE FOLLO~I'NG ~S EHTRnPOL~TED TO TD i :.."~ A~; . , Scientific ,665't 47 9 ,7:023.,67 6933,67 N57,'gOE 2953.0' ' 4871,'4.~6'H ~2 9 .25 E ~.TOH:.:HOLE CLOSURE 4814.76 FEET ~T H 52 9 ~' International , ,-, ;,,, , ..... 0 6 JAN -,63 ..~DOG:LEG C--'L 0 ~ U iR E S SEV, ER.'ITY DI'~TRHCE ~NGLE "DEG/I~OFT ~ECTZOH DZSTRNCE ,8.11 .81';0 ,371 1 ,145 ,599 .974 4203..,55 4273;23 4343,86 44'15.22 4486.96 4559.:06 4631,69 ';"~O'OO 48'1.4..76 ,,,,,' o o ~ ~O. KUPflRUK '1-G-7 GYROSCOPIC: SURVEY .,JOB' HO t4~04 · . . . ~E~SURED DEPTH RHD OTHER DRTR FOR EVERY EVEH 't~O FEET OF ~UB SER ~EPTH, HERSURED DEPTH TRUE YERTXCRL SUB HD-TVD ..DEPTH SER DZFFEREHCE VERT~CRL-, CORRECTXDH TOTRL .COORbIHRTES 19:0 29:0 390 490 690 890 99'0 I~090 I. 190 't291. 1392 1.494 't59,? '1 ,?~2 '1'808 '1915 2'142 226:1 2386 25'18 2655 2.795 29.34 30.?4 32 t.? 3362 3507' 3653 3798 3.942 4086 0. -90 190, 1'00 29~. 200 39~. 300 490. 400 59~. ~00 69~.. 60~ .790, 200 990. 800 · 99~. 9.00 1190, 1'100 iQ 1'29~., 12.00 t39~. 1.300 149~, 14'0'0 3 1590, 1'500 ? .1.69~,. 1600 '1790, l?O:O 1;? f990, 18'00 25 1990. ! 9 00 36 2090 .. 20.00 '5't 219:0. 21,00 70 2290, 2200 95 239~. 2300 128 2490, 2400 165 2590. 2500 204 2690.. 260.0 244 279:0, 2700 284 2890.., 280:0 326 2990, 290.0 372 309:0. 3'00"0 4'17 3190., 310'0 462 329.0. 3200 3390, 330'0 552 :3490. 3400 596 ;~)9 H ,47 6; .. 85: g .~2 H 8 ,,1.35,, 37,, "~1.1'. 'I,71 ~',3~0 ' t,5 212, 92' :t9 259. ,75 2~ 3'12:; fi2 .. 33 372.59 3.7 437.~2 .39 .5~03.?02 40 569,2t 4~0 635,94 ;42 . .7~04,37 46 .7,73,19 45- 841., 3I 45 9:~8., 8~ 46 9.75.* 35 44 1~4~ , 4B , '00 *.35 ,56 .62 1,14 I, 39 1 .07 2;71 3,36 5:; 32 9;39 I'6,21 26.~,39 41, ~03 59,72 1:04,62 131' ,94 '164,.91 21;03.43 247,, 52 30'0,5 I 363', 52 432.17 502.7,0 5,74.13 645,98 .720.98 801~ 50 88 l'. 03 962.,'28 *t~044,45 1125 12,06.68 E E E E E E E E E E E E E E E E E" E E E E E E E E E E E E E E E E 0 6 JRH 83 IRCO KUPARUK '1-~-? GYROSCOPIC SURYE¥ ~OB NO 1404 tEASUEED DEPTH AHD OTHER DATA FOR EVERY EYEH 1~0 FEET OF SUB.SER'DEPTH. HEASURED VERTICAL SUB ;ND-TVD YERTICAL DEPTH DEPTH SEA DIFFEEEHCE CORRECTIOH TOTAL COORDINATES 4229 4371 45t.0 4649 4?8? 4923 5;06:0 5195 5329 54;,1 5723 5652 5900 ~5"1 07 6233 6359 6878 7:009 .7'14:0 7272 7405 753? 7670 .7k304 794 0 a:079 822.0 836.3 359:0. 35'00 639 3690. 3600 68'0 3790, :3700 ?20 389 O, 3G'O.O 759 399*.0. 3900 ?'96 4:09:0. 4000 833 4190. 4'1 O0 e69 429:0, 4200 904 439:0. 4300 938 4490, 4400 971 459:0. 4500 10'02 4690. 46'0:0 1 032 479:0, 4700 '!.06'1 4990. 48:0:0 1 089 499.0, 4900 '1116 5'09:0. 5000 11 43 519:0, 5'100 1168 5,29:0. 52 00 1197 5390. 5300 '1227 549'0. 54'00 '1257 559:0,, 5500 1287 569,0, 5608 131'8 579'0 · 57.00 1349 5890, 5800 1.382 5990. 590'0 1414 609'0, 6,000 1446 619:0, 61 O0 1479 6290, 6200 1513 6390, 6300 1549 649'0, 64'0'0 1588 6590, 6500 1630 6690, 6600 '1673 6 79 O. 6 7.0.0 1717 689.0 ,. 6~0:0 1764 6990. 6900 1811 43 1'167;33 H 41 1228.62 H 4-0 J287.94 N 39 1346,8~.N 37 :1.403,49 H 37 :1459.~9'H 36 1514.29 N 35. 1568,,44:H 34 .:1621,43 N 33 '1673.29 H 29 3:0 30 3'1 . 33 32 32 33 34 36 '42 43 44 47 4,? 2053,, 94:0 N 2'1"02.86', H 2:151.14 H 2198,56 H 2245. 86* H 2292,,78 N 234'.0,34 N 238.7, ,. 91H 2435,36 H 2484.2~1 N 2534.7'1 N 2~i87,28 H 2642.. 85 H 2,701.6-.0 .N 276t. 76 N 2820,,09 fl 2'87,7,46, N 2934,6'I' N :t287,57 "E .1366 ;8.0 E 4 443, 5.2 E' :152.0,13 E ',1595.40 E '1670,48 E 1744,79 E 1817,48 E 1:888:. 87 E '1959'¥,00 E 2027,~ 5 0 E 2094..'83 E 2160,03 E 2224,.', 52 E 2287,64 E 235'0 ..79 E 2411 ,.71 E 2477.29 E 2544 .',38 E 2612,02 E 2680;40 E 2,75'0.47 E 2821.13 E 2893.75 E 2966; 29 E 3038,51 E 3111.06 E 3184.45 E 3260.57 E 3339..30 E 342'0.08 E 3503. O0 E 3589., 63 E 3680.,02 E 3771.42 E © 6 JAN.' 83 . ''O © %RCO RUPFIRUK S-G-? GYROSCOPI~ SURV£Y JOB N01404 lEiSURED DEPTH AND OTHER D~T~ FOR EVERY EVEN 1:0'0 FEET OF SUB SE~ DEPTH. O 'i'::' ' TRUE -' MERSURED VERTI, CRL SUB MD-TYD VERTICRL · - DEPTH .DEPTH SER DIFFERENCE CORRECT[OH TOTRL COORDINATES 2953.8~.. N 38'02. t9 E E)rillJnfl lnterr'~a'tio~l IRCO KUPARUK 1-G-7 GYROSCOPIC SURVEY JOB NO '1404 IHTERPOLRTED VflLUES FOR EVEN 100-0 FEET OF HEfiSURED DEPTH, TRUE HERSURED .VERTICRL ~UB DEPTH DEPTH SEa TOTRL COORDI'HflTES 1 ~90:0 ! 1)00. 91 O. 2000 4~;0,0 3430, 3340, 5000 414'6, 4:056, 7~,0 ~683, 5~93. 800'0 6433, 6343. 885 I. 7,024. &934. 3.92 E 156.52 E 6~?.87 E 1'158.~05 E 1712.32"E 2234.69.E 2745,7'1. E 3294.54 E 38~2,'1.,9 E ~¢ '-, ,~ AI~4F ~,, "Scientific' International 0 6 JiqH 83 t ~ tI, f ilk'cO KUPGiRUK. 1-G--7 GYRO$COP']LG SURVEY .,JOB NO '14~)4 ,INTERPOLRTED TRUE YE'RTZ'CAL 'DEPTHS., COORDINATES AND CLOSURES FOR'GIYEH DEPTHS ;ODE I~HE. TRUE HERSURED ~ERTICRL TOTRL COORD:JH~TES- C L 0 S U R E DEPTH DEPTH , D'[STRNCE ANGLE D H SUB 7893 .. I~355,82 8~)t 3 6442 e'l 9'1 ;'6569, e355 .6684,19 87B4 '.,6978, 1,0 8851 .?~023, 2558.92 H 2516.2'2 H 2589.33 H ~758.31. H 2927.8't H 2953..~5 H , 3234,~8 E 33G'1,9'1' E 34~3,29 E 3498,~8 E 375~,54 E 3B~2,~19 E .'413~,2"J. H 5'1 32 19 E ..6265.,82 42'l'2.,?5 H 5.l 36. 32 E 6352,78 :4337,61' H 51' 41 I E 54~9,5:t 4454,75 H 5~ 44 36 E, 5594,19 · 4765.,.9~ ,..H 52 5 49 E :5G88,10 4~t4,75 H 52 9 25 E 5933.,57 ~ 5 JRH 83 Scientific Drilling International - ~ ;-:----~--:-~Li---I -:-'- ..... 4. .... "~-"-- -' : - : : ], -' :. i ] ~ ~ ' ' ~ " · ; I - , ; ~ i } i : :l I ~ .... ~ I ~ : -:- ~ : ~ ~ . '. : T- ,,,, ,, ,,._ ,., . , , ,,, l-~ ~ : i · i :- : : ; . ; t ~ ! i i i.i i :. I.i : i ; , : ! ; i r ~-i-i i = = { ~ !, : ~ ~, ~ : : ; i , ~ i.~ ---~ .... ~'-:-~-jff "---~--;- .... 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I~ : i . , : ' - ~ - ' ' ; ' ' ' Suggested form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. Operator, W~ll Nam~ and Numbe~ Reports and Materials to be received by: Required Date Received Remarks Completion Report Yes Well .History' Yes _Samples ... .~~_ ?/ ....__ .... ~- , , .-- . Core Description Registered Survey Plat ~.~.~, InClination Survey .,~,.: Directional Survey ~, ~-~ .~ .~~ :~ ...... ~ /. ~..: .? Drill Stem Test Reports .-- (:. ..................... /,. ;., , .. ,-:.,: ..... '.:'. ../ Production Test Reports ~ ~ : . Logs Run- Yes , Digitized Data ~/.¢~ ~ ~--/:--g: ~ '"" Transmitted herewith are the follc~ing: PT.WASE NOTE:~ F- FIT~I, T- TAPE, PC - PHOTOCOPY /~CE~ ACKN~: ARCO m. ASKA, ZNC. ~" ""' F E B ! 8 ~983 ATIlt: ~- AFA/311 · P. O. BOX 360 ~/, ,¢;'/~a 0i! A Gas Cor, s. Commission ~ORAGE, AK. -99510- ^.nuhc. rage Transmitted her~qith are the follc~ing: PI.WASE N(Yl~~~ F- F~I, T- TAPE, PC - PH~PY A.TII~: ~ - AFA/31.% ,~,~ 0i~ & Gas Cons. Commissi.o~ A.,~ORAGE, AK. 99510- ' PC - PHOTOCOPY A~:{'CO A,:"aska, In ,c~--. Post Offic~ .x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT:' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-iO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 Also enclosed are well completion reports for' 2-11 1E-23 ' 7-17. 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We al.so are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska. Inc. is a s[Jbsidiary of AtlanlicRichfieldCompany Anchorage . , ~-~ STATE OF ALASKA ~-~ ALASKA ~. _ AND GAS CONSERVATION CO..~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-201 3. Address 8. APl Number P.O. Box 360 Anchorage, Alaska 99510 5o- 029-20872 4. Location of Well at surface 615 ' FWL, 1207' FSL, Sec. 29, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 90' RKB ADL 25640 ALK 2571 For the Month of January ,19 83 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1G-7 11. Field and Pool Kuparuk River Field KlJpar~Jk Rivpr (lil Pno1 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1045 hrs, 12/26/82. Drld 13-1/2" hole to 2514'; ran, cmtd & tstd 10-3/4" csg Drld 8-3/4" hole to 8618' " · ; ran 10gs. Ran, cmtd & tstd 7 Squeezed cmt. Ran 3-1/2" completion assy. Secured well & released ~i~; @ 0400 hfs, 01/14/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2487'. Cmtd w/1300 sx AS III & 250 sx AS I. 7", 26.0#/ft, K-55, BTC csg w/shoe @ 8836'. Cmtd w/730 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/FDC/CNL/Cal f/8603' - 10-3/4" shoe BGT f/860S' - 10-3/4" shoe GR/CBL f/8660 '-2000' CBL 16. DST data, perforating data, shows of H2S, miscellaneous data 7978'-8013' 8217'-8238' 12 spf 8253'-8273' 0il & Gas Cons. Gom~n~ssio~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -/-.,~/'~ '/// ..~..~ Area Drill ina Enaineer ~/~//~ SIGNED ('_ //~'/--~ ' . /~ TITLE ....... DATE NOTE--Repo~on~his fo)~ is/~ required for each calendar month, regardless of the status of operations, and must be' filed in duplicate with the Alaska Oil and Ga~Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 1G-7 DRILLING HISTORY NUHydril & Diverter. Spudded well @ 1045 hrs, 12/26/82. Drld 13-1/2" hole to 2514'. Ran 61 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2487'. Cmtd 10-3/4" csg w/1300 sxAS III & 250 sxAS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NUBOPE & tstd - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 406 psi - ok. Drld 8-3/4" hole to 8618'. Ran DIL/SFL/SP/FDC/CNL/Cal f/8603'-10~3/4" shoe. Ran BGT f/$603'-10-3/4" shoe. Cont drlg 8-3/4" hole to 8851' TD (01/~4/83). Ran 227 jts 7", 26.0#/ft, K-55, BTC csg w/shoe @ 8836'. Cmtd 7" csg w/370 sx Class G & 360 sx Class G extended. Disp well to NaC1. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx AS I & 99 bbls Arctic Pack. Ran GR/CBL f/8660" 2000' Perf'd 8149'- 8151'. Set cmt retainer @ 8050'. Squeezed 400 sx Class G cmt. Perf'd 7873'-7875'. Set cmt retainer @ 7775'. Squeezed 400 sx Class G cmt. Drld cmt & retainer. Drld cmt to 8000'. Tstd csg to 1500 psi - lost 400 psi in 30 min. Set cmt retainer @ 7730' & tstd - ok. Pumped 200 sx Class G - squeezed. Drld~cmt, cmt retainer & more cmt to 7899'. Tstd perfs (7873'-7875') to 1000~psi - ok. Drld cmt f/7899' to cmt ret @ 8050'. Tstd csg to 1000 psi - ok. Drld c mt ret @ 8050' & cmt to 8170'. Tstd csg to 1000 psi - ok. Drld cmt to 8784' PBTD. Tstd csg to 1500 psi - ok. Ran CBL. Ran 3-1/2" completion assembly w/tail @ 7870', pkr @ 7832' & SSSV @ 1901'. Tstd hanger & packoff to 3000 psi - ok. Disp well to diesel. Set pkr. Closed SSSV. Dropped perf bars & perf'd. Flowed well & SI. Dropped ball & press. tbg to 2600 psi to release Vann Guns. Instld BPV. Secured well & released rig @ 0400 hrs, 01/14/83. Alaska 0il & Gas Oon~;. {;ommissior~ Anchorage JG' llm 02/03/83 1G-7 DRILLING HISTORY NU Hydril & Diverter. Spudded well @ 1045 hrs, 12/26/82. Drld 13-1/2" hole to 2514'. Ran 61 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2487'. Cmtd 10-3/4" csg w/1300 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 406 psi - ok. Drld 8-3/4" hole to 6144' as of 12/31/82. J G' 1 tc Alaska Oil & Gas Cons, Commissiori FO8 Anchorage ARCO Ala?ka, Inc. ' Post Office B~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT:- State Reports Dear Mr. Chatterton: Enclosed are monthly reports for December on these drill sites: 1-24 13-14 1G-7 2~11 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for: 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a~ secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28:l lm Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany · ~--, STATE OF ALASKA .~ ._ ALASKA ~_.~. AND GAS CONSERVATION CC "vIlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well~'~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchoraqe, Alaska 99510 4. Location of Well at surface 615'FWL, 1207'FSL, Sec. 29, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 90' RKB ADL 25640 ALK 2571 7. Permit No. 82-20] 8. APl Number 5o-029-20872 9. Unit or Lease Name Kunar~Jk River Ilnit 10. We'H No. 1R-7 1 1 .-FTelc~ and Pool Kuparuk River Fie]d Kuparuk River 0il Pool For the Month of, December ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1045 hrs, 12/26/82. Drld 13-1/2" hole to 2514'; csg. Drld 8-3/4" hole to 6144' as of 12/31/82. ran, cmtd & tstd 10-3/4" SEE DRILLING HISTORY. 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2487'. Cmtd w/1300 sx AS III & 250 sx AS I. See Drilling History 14. Coring resume and brief description None 15. Logs run and depth where run None to date 6. DST data, perforating data, shows of H2S, miscellaneous data None ,~_L~s'¢,~ 0~'l 8,,. Gas^ _~r~neCOnS' o0mmissi0~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~' ..... ~ ' T~TLE Sr. Dr1 ] ] ing Engi nee~ DATE SIGNED ~ r ~ ~ · ............ / / NOTE--Re~t oh this ~rm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~ Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate -MEMORANDUM Sta e of TO: THPU: ALASE~. OIL Ai'TD C-~AS CONSERVATIOn7 COMMI£SIOI'~ C. tterton DATE: January i/~-¢.' FILE NO: 108A/J Lonnie C. Sroith ~ ~' ~ Com~i Ssioner TELEPHONE NO: FROM: Edgar W. Sipple, Jr.~~.~.- Petroleum Inspector Alaska . 6, 1983 SUBJECT: Witness DOPE Test on A~..CO's Kuparuk lO-7 Sec. 29, T12N, R10E, ~"~U[,~ Per~-~t No. 82-20! Parker Rig 141 Wednesday, DeceDbe.r. 2.9..,_ 1982 - I traveled this da~' from Parker 176 ( subject of another retort) to ARCO's Ku~aruk lO-7, Parker Drilling Rig 141. The drilling rig was in the process of nippling up. The B©PE test comFenced at 3:00 p.m. and was concluded at 5:15 p.m.. There ~re no failures. I filled out the A.O.G.C.C. BOPE test report which is attached. In summaz~_y, I -~itnessed the BOPE test on ARCO's I'~uparuk 1C-7, Parker Rig 141. 02-00 IA(Rev.10/79) ---,.STATE OF AIASKA OIL CAS Cr)~!SERVAT[~ '!; ,.:CM~-[ISSION B,O.P.E. Insf~Ction Ope rator ~'~ ~ Location: Sec ~ ~ Fril linq Contractor- Location, -General_ Well Sign Ceneral Housekeeping Reserve pit Rig BOPE Stack · Annular Prp~venter Pipe. Rams B lind paros oz, e -,Lin~-Valves~ H.C.R. Valve m~' r_J~e Valves ~eck: Val ?+~- /7 '. ' 7-i _- '..-~..----: i_~r-----'%: ............... Representative_ ~T6L;~ ~~,~'.~ Permit # __~2- 2. ol /0~ Casing Set @ ~eq ~'7 ft. Rig # /qt RcpLcsentative. ~o~5 . ~ ACCU~IUIA~R SYS'~M all O~arge ~es~re ~/OO psig ~essurc After Closure / ~ OO psig ~p incr. c]os. pres. 200 psig~~n,oscc. Contmts: ~ster ~ ~v~r .... R~te.__~ ._. Blinds. ~it~L.~oygr Kelly and Flor Safe%, Valves · _ ~per Kelly . ~/( Test. Pressure ~ur Kelly Ol~Test ~es~e ~o o .... ~OO ~11 ~pe . 0/% Test t~-essure I~,ide ~P 'O~ ~est ~es~re 3ooo Choke ~nifold ~ ~ ..Test ~essure ................................................ ' Test -Titanias. I S Test Pressure ~ 00o · 500° - ooo Test Results: Failures. Repair or Replacament of failed oquiprmnt to be made withinA//~_ Inspecto~[,Cc~mi~Sion 'office nOtificd. ' ~ Remarks: "~,:~/ ~'~ /I.,/~..i~'"~ (/,.,~'--~' '7 ' · arr~¢{C~ ~ 7o o p,~ Oistribut ion orig. - AO&CCC CC - Operator cc - Supervisor Ins~ctor~ Novem~r 30, 1982 Mr. Jeffrey B. Ke%~tn Senior Drilling Engineer AR~ Alaska, Inc. P. O. Bo.~ 360 Anchorage, A!a-~ka 99510 P.e: Kuparuk River Unit ARCO Alaska, Inc. Pe~i~ No. 82-201 Sur. Loc. 615'FWL, 1207'FSL, Sec. 29, T12N, R10~7, U~. B~hoie Loc. 937'FEL, I010'FML, Sec. 29, T12N, R10E, U.~. Dear Mr. ~ewin: Enclosed is ~h~ _~ approved application for permit to drill the above referenced well. if coring is conducted, a one cu~c inch chip fro.~'~ each foot of recovered~ core is required~. Samples of well cuttinqs and a ~ud ioc~ are not required. A' continuous directional survey is requir~ as per 20 AAC 25.050(b)(5). If available, a tape contamnln~ the digit~ lo~ information shall be submitted on all logs for copying except experimental logs, velocity surveys ~nu dipmeter surveys Many rivers in Alaska and %heir drainage systems have been classifie~/ as L~:~or~ant for the spawning or migration of anadrc~mous fish. O~Derations in th~se areas are subject ~o AS 16.~05.870 and th~ regulations prc. mulgated thereunder (Titl~ 5, Alaska Administrative Code). Prior to co~nmenc in .o, o~rations kcou may be contacted by the Habitat Coordinator's O~fice, Department of Fish and Can~. Pollution of any waters of the State is rorohibited by AS 46, Chapter 3, Article 7 and the regulations~promulgated 5hereunder (Title 18, Alaska Administrative Code, Cha~.ter 70) and by the ~. .... ~ . Prior to Federal ~?ater Pollution Control Act, as a..e..deo. co~encing operations you may be contacted by a representative of the Departn~.ent of Enviro~enta! Conservation. TO aid us in scheduling field work, please notify this office 24 hours prior to com~enCing installation of the blowout Mr. Jeffrey B. F~ewin Kuparuk River Unit 1C~-7 -2- November 30, 1982 prevention equi~ent so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to c~mencing equi.pment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance-notification so that we may have a witness present. Very truly yours, f C. V. Chatterton Alaska Oil ~nd Gas Conse~ation Co~ission Enclosure cc: Department of Fish & G~me, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC:be ARCO Alaska, Inc. ' Post Office Bo.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 18, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1G-7 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 1G-7, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map. o A discussion of wellbore crossings. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer jBK/JG:sm Enclosures GRU2/L41 RECEIVED NOV 2 ]982 0il & Gas Cons. Com~i$$j0ri .Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfietdCompany ,'"-'. STATE OF ALASKA '"'- ALASKA L,,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL 00( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I-3 SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 615' FWL, 1207' FSL, Sec. 29, T12N, R10E, UN At top of proposed producing interval ~ Target: 1320' FEL, 1320' FNL, Sec. 29, T12N, R10E,UM At total depth 937' FEL, 1010' FNL, Sec. 29, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Pad 60' RKB 90' ADL 25640 ALK 2571 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 10. Well number 16-7 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 32 Niles NW Deadhorse miles I 937' FEL Sec 29 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8760' MD, 6932' TVD feet +2459 19. If deviated (see 20 AAC 25.050) 120.Anticipated pressures KICK OFF POINT1000 feet. MAXIMUM HOLE ANGLE 43° o I (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 16-8 well 107' feet 18. Approximate spud date 12/11/82 2958 3369 psig@ 80°F Surface psig@ 6700 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Casing 16" 10-3/4" 7" Hole 3-1/2" Weight 65# 45.5# 26# CASING AND LINER Grade Coupling PEB K-55 BTC 8-3/4" 22. Describe proposed program: Length SETTING DEPTH MD 80' 30' I 30' 2269' 29' I 29' I TOP TVD l 28' I 28' 8732' MD BOTTOM TVD 110' 110' 2298' 12200' I 8760' 16932' I I QUANTITY OF CEMENT (includestagedata) 200 cf 1200sx AS III & 250sx AS II 1000sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8760' MD, (6932'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2958 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. See attached discussion of wellbore crossing. RE[E I VED 23. I hereby certify that the foregoing is true and correct to the best of my knowledge NOV 2 4 ]98z / X TITLE Senior Dril'ling Engineer DATE ////2~//r~z Alaska 0ii & Gas Cu~s. Corr~.~is~;iun · Anchorage Samples required Mud Icg required I~IY ES ]~i~rN O i--]YES .~NO Permit number Approval date ~.,o/~ ' / / . ~ ~ by order of the Comm,ssion 10401 GRU2/PD~7 ~ /--/ :orm / CONDITIONS OF APPROVAL IDirectional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS DATE Nov6mber 30, 1982 Submit in triplicate ~- ...... .,. --~r~ ....... ~ '~ 0 - O~ .. 100 :200.. .., ~00~, . 200 , ,Q ...................... ~ ..... ~ ............ ~ ~., .... , : : i J : I ' ' I . ANALYSIS OF 1G-8/1G-7 WELLBORE CROSSING NOTE: Refer to the attached Proximity Map 1G-7/1G-8 The proposed Well 1G-7 will cross Well 1G-8 by a distance of 107' at a measured distance of 1460'. This distance was calculated using the proposed well path data for 1G-7 and proposed well path data for 1G-8. Well 1G-7 will have an ellipse of uncertainty of 34' across its major axis at its crossing depth of 1460'. Well 1G-8 will have a ellipse of uncertainty of 10' across its major axis at its crossing depth of 1460'. The areas of uncertainty for the two wells will, therefore, not intersect. ARCO proposes the following procedures be used to drill 1G-7 safely past the aforementiOned well crossing: 1. The 13-1/2" surface hole will be surveyed to its total depth (+2300 MD). 2. If calculations show that an intersection 22' or less will occur between the two wellbores, a jetting assembly will be run above the crossing depth to impart a small cycle in the appropriate direc- tion. (The distance corresponds to an intersection of the areas of uncertainty. ) In addition to the above precautions, the on-site personnel and rig supervisor will continuously monitor all parameters as the intervals of interest are drilled. 11/18/82 GRU2/A3 NOV 24 ' ' Oil r,~', fi'as Cons. -®. O, . Surface Dive~ ._r System .. Maintenance & Operation ~-- 1. Upon initial installation close annular ! preventer and verify that ball valves I · have opened properly. I 2. Close annular preventer and blow air ~_ . through diverter lines every 12 hours° 3~ Close annular preventer in the event that gas or fluid flow to surface is 'detected. If necessary' manually over° ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. -_ 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi dri.lling spool w/10" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer'. 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. 16" Conductor 5ooo Psi , SR A BOP - 7' PIPE RRHS o .. SPOOL .. 6 PiPE RRMS lo 13-5/8" 13-5/8" 13-5/8" 16" Bradenhead 15" 2000 PSI x lO" 3-3G3 FSI c2sing head · lO" 3000 PSI tubing he~_d lO" 3000 PSI x 13-5/8" 5000 PSI . adapter spool -" 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drill in~ Sl~o,l w/choke and kill lines -_- 5000 PSI pipe _-.... :..... 5000 PSI bl ind r~LS -- '-"-" -. 5000 PSI anr=lar .... .:: .:..--'"" · . _ .. ...- . .. .-: ...... - ~-:' _v. ..:...: .. .... ACCt~.tULATOR c..~g£l'rlr T_ST __ ]'_ .. r'i ...... ..--..- -- -.___.-:.-: --..' ';.. '. -..., : - =~ _. - _ = ~_ ; --' ..- - . ~-tECK J~ FILL ACI:~..~-,TOR ~-.~.SERYQII~ TO P~OP~'~ ""' L~'EI: WITrl HYDRAULIC FLUID= .. ASS~ TP, AT ACJ:~-~T~ P~,,E I5 ~ PSI -- tCITlt 1500 PSI DO',q~I?,F.~I OF Ir':- O~SERYE TIRE l~,--~ CLIiSE ALI. L~ITS C~SLT ~qO RECORD TrlE T~ ~ PP,~ i~,~I~l,-- ' -- I;~ ',~R ALl. I~(ITS ~ CI.8SE~ WITrl P'~ OFF° P. EOI~RD ON IA. DC REPORT. ~ A~_-EFT. 2-_,...,...,...,...,~ LIJ4IT IS 45 SE~([Z~ Cl.12E;Ihl; TL"~ ~ l~_oO PSI P~-~-~qI)(Ih~ PRESSURE. - 13-5/3' ~OP STA~< TE. gT F'ILL BOP STACK A~ /4A,'~[FOLD gIT~ APJ::i']C DIE. SEL. C~EC~ TdAT ALL HOLD ~ $~ A.'~_ ,FUllY R~- TRACTED. PREDET£~",IME DEPT'- T?.AT h'llt SEAT N~ SEAT IR ~~o ~ta'i II{ LCX:X ~N SCP~IS IR CLOSE A~(~IULA~ PR~r.i~ AND C-'=~KES ~ 5'YPASS YALVES 0~( NA,qIFOLOo -~ '-. &. TEST ALL C:~POrdTg,q'S TO 250 FSI ' : '.' 10 HII~. --'' lO RI?~TES. B~ED TO ~0 ~ . ' . ' ' .= ' . 6. ~'1 '~q~R P~t~ - . 1 ..... P~E ~. -- - J .. - .:~'~ - . - 7. J~E-P~U~TO~ ~[' 4" - ' '"' "' "8 ' " ' ~ - ~'--:' - ~E ~V~ DI~ ~~'4 ' - ' ' - - ~ -- ~ .~T ~ - ~ _ . 9. ~1 TOP S~ OF PIPE Im J ' "-- ' ' ' S~ ~ PIPE ~6. ~ 'I - ~' ~; ~ h ~ ~t L ~ HII~T~. B~ED TO Z~ PSI. ~ C~O' ~ ~ m ~ m ' - ll. ~J( 80~ S~ OF PIPe ~. B~D TO ZERO PSI . - -.... - - ~,,,~I~, ~ .~j ~.~ ~ ~ -. - . ~ -" ~:'-'~ ' ~[iohof-80(~ ~ ~ IFOLD ~,D LI.~ ~ / ' . _ :_ --_ _ k . ) ----.:--- .... -. -- - _ _ 14. T~ ~f ~ ~ I~I~ I . i -'"" ...... - -__ - : -_ ~[ra~ e~. ~ .'_'' ~ . ..' ._' : - ._ ' 15. P~ TEST IIIF¢~II~ ' I i - -'-': "- _-'-.:'-' .- ~r [o~q s~. m~ s~ ~o ~~ ~ .' } _.~-:: --..-.: : _ .; ~[~. _ . . ' ~ ~ '::~- - .-' ' .~ 16. ~J C~IPL~E B~E ~ ~ ~--~_.- --_- _ . - ' -_ . _ -:" ~TI~LY OP~ ~ ~LT_ Z? SZ JS,r -! .. ARCO Alaska. Inc. F.,.,C. aru~, P'cjec! [dwg no :,A,',.,,c,,~.' P..'07. drawn by' ~/,~., CHECK LIST FOR NEW WEL'L PERMITS Company Lease & Well No. K ~ ~ ITEM APPROVE DATE (1) Fee_ (2 thru 8) YES attached //~J~' ' 1. Is the permit fee ........................................... me 3. 4. 5. 6. 7. 8. (3) Admin ~~ tl-f.~-~g-' 9. (9 thru 11) 10. 11. (4) Casg (12 thru 20) (5) BOPE //dff (2l th'ru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. REMARKS (6) Add:. 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 this pool 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 .................................. f~ Is a conservation order needed ...................................... 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 .. Will all casing give adequate safety in collapse, tenSion and burst'' Is this well to be kicked off from an existing wellbore ............. ~--~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~t~Z) psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: o ~0 Z Geology: HW K WVA ~ JAL Engi~ ~ering: LCS 7~.~ BEW,~' JKT~ ~- -RAD ~ MTM ~ HJH --~ rev: 08/19/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo_ry File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. '? 3 P'R (} C E $ $ S A g~. ,P L, E 3. () 879 39.35 S :'~, 643- 5 o 0 rj 39.3555 .39.3 ti 55 j t, 0 0 ~26.'7bdr~ 4.03~4 6,7 X~ 6 I. 3 · 3':', 3c' 35.3t,27 5. '7 6 5 7 2 6 ,, b <) 0 <) 3.3-:15 1 ! l'.i t C ik b I '1. C ~,, t.., !, i~ · 7 5 0 0 3.0391 u, 1, 7 ~ 3 7. 832C t u, 61 72 I 0,42. 9 7 b, 5 5 0 Ii{. 10, b '7 1 9 3.5703 I (3.93 75 5,62~9 ! 2.0'2, 34 l. 7 ,! 4 e .,~ -5~99. 8457 ILO -0<:9.2500 7! 5 (.) C, 1 . ~ '77:3 't [, L: - 9 % 9,250 '.'.'~ C ,", b ] -999,250~: '-,999,25L}~ - 9 9 q. 2 5 O ~.' r ;t .L...{'. -9$~ , 25 r~ i,,' -';)99 2500 l ,",: 6 7 ], ':,~ 2,1 514. 3 -99 9,25i.!0 .I i...2031 9629 - g 9 '::~, ,,,, ;, (} 8 59 1.75 ~,~ ~; :l.J..14B4 - 9 9 q. 2 ~ 0 {) 1. t.~l.A]. i ;.. 5 (,' 0 (.' 2. % ~.)'1 ,., E Pq , i.:'!3.< :72;'"5 ' . '2~: - 9 9 9.2 5 0 -999 3'49 ",t · -,g 79.2 ?;0" C' ~', 1, 'I 3.4 't ()7 3.45 b I - 999,250 11., 43'75 2.9q4 ! 1.~ .6172 - 9 9 '9. ;2 5 ~} u 2.9~ t I, I .~47 !5 3.2b'2o -999,25rio 32O3 5 54 7 2,4941 q. 29 Z, 2 5 'i a - 999.25 o 0 I '~. 4 g 2 '2 3, u2'l. b - g '? 9.25 0 -el: ""'v '? ,, 2, } (: () ;g.' ", ~,,? A .- 9 9 9.7! '.) ~ t ~,, ,'< ~.~ _ c) c, 9,2. -) {) ,"i F C..,: ~. -'9o9. ?. 5 t;u _7.9 ci 9 ,:2 !5 {.~ 0 ,,999,2500 · ,, 9:99,250 0 -999,25017 570 5 0 ~'~ 5 0 0 5 0 c, 9,,, 3,9 "/0 '7 -999,2500 -999.25(,0 -999, 2,3633 ,- iii 99,250 t~ -. 999,250 ,'i 3.41~b5 -9f19,2.509 -999, ?500 ¢"1 - 999,250 -9;39. 38.2324 b 5 'l , (; (.: 0 o t< .t"~ f} CA L, J. .... I;, H ('t CAUl t:, l... 0 C A .I.., t' J i :i t. I L: I'.} il. iq: i-i~ C :~ L 1. ~ 2' 37 5o - 99 :~, 25 0 0 1, i. ,~? 297 3. ~ 17 6 -, 9 ':~ 9. '25 0 0 :12, U 23 4 3, ". I i 3 - 999,2500 ! 9.. 1'32S ,J. 25 78 - 999 ' 250 0 I. 2, ~,609 2,bl. gb r. ' 3,591.8 -999. 2500 2, '757 ~: 3.(i3i3 - 9 t)'.:s, 2500 05 t: 3 3350 ?' ], . 5 ',~ (. (' 3. ¥ ;3 '7 9 3.g~:;~ 36.4, 553, 3.7,"!, ~ 7 43.3105 ~77 . C; ~ ~ {',:' }. t ':? ,.% '? 1 C . 2 7 3,'~ t,] 3oG~.-O0 ~ i-.'. !> :!, 7 ? ~. (,.. :-t .3 I b I.,) C ~ i. J. I C ,L [ l.. .L 1.. L,: ,', L. q t 111 3 ,, l b 2 3 I ,J. 6 '1 g 7 0 ~, ' n, .. () .,,,. a g 1 I , ~) 9 5 3 b. 539 ] 0 0 3 0 3 'I 3.8 9 5 3 O. U I 4 2, I.i .Ot:>2b o. (; 332 t .;:1~. 4 2 1 "? (,i. t)2 7 3 ! ':.1!. 9 (., 6 2 0. C) .~ 3 7 i O. ~{).55.4'1 i,, (.~ (') i5 % F' i.. J (.:... '~. 11. '/. t. ? 14, 3 1.. 1. 55 3, L, , h" !,0,t 547 3, ~!~ ! ~"¢ ':2 b. ] ~"~ 2 ~'-,' ,...1.. o , 1 ~'} 1. 4. 4, 1.502 't 2. % ') 6 i 4.0?9':; ,.+ 7. (.-. 553 t) ]:;f, t"~ 0 I L, [; C ,~ L, f 1 0 , 8047 ~.5234 0, o 1. 37 J 1.o~3. ' ), 93 U ? i2.225b 14.0:2 3 4 J. 2.1(;94 11., 4t::19 ,-, ,:. () (: 0 5 1, 5,6z5'-' ' D I0.3! 2.k. L"I'~ I'lL! 1 ii 1 ~I;-] ii! [;-] ~ ] 1- 1" .I i "' J, , t.. · ~ ~., ('t ~ ,r~ C () 4, 4- P i';~ ('!C [!.',8 8 0 ti C ,q !") u 6~ bt~ C ? C 2 62 (:2 C'2 C2 C 2 C 2 C :2 ('2 C 2 C2 (2 C: 2 m'-"]~ m"l lmimi] ilq ii_,. [qm 11 li.64,8" 12. l {,~ 9 ,a I 2 · ')oga 12, lO94 12,! 11~~ 1 2,0 0 0 0 1:!, Y.375 1 t '12.3? ~ 1'; 3~,, 36 I.,2,6'7 1 9 C2 L'~ I~ II I ill iI:-t i[~ [;~ J
