The URL can be used to link to this page

Home My WebLink About213-074 . , • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed: Suspend r Perforate r Other Stimulate r Alter Casing 9 Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG f 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 213-074-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23134-61 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25667,25666 KRU 2G-17L1-01 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 16889 feet Plugs(measured) 2751 true vertical 6161 feet Junk(measured) None Effective Depth measured 16510 feet Packer(measured) 13851 true vertical 6147 feet (true vertical) 5871 Casing Length Size MD TVD Burst Collapse LINER L1-01 (OF 2218 2.625 16510 6147' SCANNED OCT 3 12016 RECEIVED Perforation depth: Measured depth: Slots 14375'-15370' JUN 2 1 2016 True Vertical Depth: Slots 6139'-6135' AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 13889 MD, 5894 TVD Packers&SSSV(type, MD,and TVD) SSSV= None SBE-BAKER GBH-22 80-40 SEAL ASSEMBLY @ 13851 MD and 5871 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 399 1099 25 627 153 Subsequent to operation 0 0 7649 275 1709 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations �w Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG J GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-077 Contact Darrell Humphrey/Bob Christensen Email: n1139(c conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date \ ,1O G -18- 1 4, vT_ g/2ib Form 10-404 Revised 5/2015 / Submit Original Only RBDMS GL- JUN 21 2016 • • 2G-17L1-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/12/16 Well brought online, converted to WAG service KUP PROD 2G-17L1-01 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/DWI Reid Name Wellbore Status Inc'(") MD(ftKB) Act Btm(ftKB) Conocarhgtt0+ 500292313461 KUPARUK RIVER UNIT PROD 99.80 14,410.40 16,889.0 ° ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2G-17u-01.1/7/2015435.55 PM SSSV:NIPPLE 10 3/16/2014 Last WO 27.60 1/27/2003 Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 14,257.0 9/15/2014 Rev Reason: REMOVE GAUGES lehalif 1/7/2015 HANGER,z3z - �� Casing Strings s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread 7; r LINER LI-01(off the 25/8 1.920 14,291.9 16,510.0 6,146.8 4.70 L-80 ST-L X4 J IT main wellbore) Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) .AAl CONDUCTOR;28.0-110.0A .A// 14,291.9 6,122.5 60.30 SLEEVE SHORTY DEPLOYMENT SLEEVE 1.920 15,370.7 6,150.0 88.19 SLEEVE SHORTY DEPLOYMENT SLEEVE 1.920 NIPPLE,502.0I _ Perforations&Slots Shot Dens GAS LIFT;4,081.2Illr' Top(TVD) Btm(TVD) (shets/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Cont 14,375.0 14,597.0 6,138.9 6,137.7 C-4,2G-17 12/2/2013 SLOTS Slotted Liner 114,611.3 15,370.3 6,137.8' 6,149.9 C-4,2G-17 '12/2/2013 SLOTS Slatted Liner I:.: 15,371.6 15,842.5 6,150.0 6,153.9 C-4,2G-17 12/2/2013 SLOTS 'Stoned Liner • 15,849.7 16,509.6 6,153.6 6,146.8 C-4,2G-17 12/2/2013 SLOTS Slotted Liner SURFACE;28.5-6752.8- 'C Notes:General&Safety End Date Annotation 11/22/2013 NOTE ADD LATERALS L1,L1-01(off the mainbore) GAS LIFT;7,961.7 I GAS LIFT;10,742.3 GAS LIFT;12,808.8 GAS LIFT;13,737.3 I it SLEEVE;13,789.2 f f NIPPLE;13,805.2 ■ 1 LOCATOR;13,849.1 all�!, 4.4 SSE;13,850.5 ant j V' PRODUCTION;26.0-14,027.4 P LINER;13,847.9-14,7680 . M SLOTS;14,375.0.14,597.0 i ii.." SLOTS;14.611.3.15,370.3 1 I SLOTS;15,371.6-15,842.5 I j SLOTS;15,849.7-16,509.6 LINER L1-01(off the main !C wellbore);14,291.9-16,510.0 Py OF • • Tye • gw\��//7. • THE STATE Alaska Oil and Gas pf A Conservation Commission i 333 West Seventh Avenue '1741-81/. '. GOVERNOR BILL WALKER .Anchorage, Alaska 99501-3572 —"'•—Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey SUMO ;r NSK Production Engineering Specialist 4j'r j ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-17L1-01 - Permit to Drill Number: 213-074 Sundry Number: 316-077 Dear Mr. Humphrey: 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, Cathy '. Foerster Chair DATED this 2. lay of March, 2016. RBDMS MAR 0 4 2016 RECEIVED STATE OF ALASKA ij h FEB 2 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION --9-• AOGGC APPLICATION FOR SUNDRY APPROVALS REVISED 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 213-074-0 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-029-23134-61 7.If perforating, 8.Well Name and Number: n� What Regulation or Conservation Order governs well spacing in this pool? AIR- 121 Will planned perforations require spacing exception? Yes r No V' 1 KRU 2G-17L1-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667,25666 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): Plugs(MD): Junk(MD): 16889 6161 16510' 6147' 2751 None None Casing Length Size MD TVD Burst Collapse LINER L1-01 2218 2.625 16510' 6147' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots 14375'-15370' Slots 6139'-6135' 3.5 L-80 13889 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None MD=0 TVD=0 Packer=Baker ZXP Liner Top Packer MD=13848 TVD=5870 12.Attachments: Proposal Summary 1v WellBore Schematic Fr, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:3/15/16 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG GSTOR r SPLUG r GINJ r Op Shutdow n r Abandoned r Commission Representative: 17.I hereby certify that the foregoing is true and the procedure approved Contact: Darrell Humphrey/Bob Christensen herein will not be deviated from without prior written approval. Printed Name Darrell Humphrey Phone:659-7535 Email: n1139Aconocophillips.com Title: NSK Production Engineering Specialist Signature .-, Date: .2 • i q I' / ✓� Commissio Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Lt. O , Rug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: A waiver. js 1r4h¢Cd to gblow pac%tt.- to be ftictcrd ',,, 'f3e a.ba v thz ta/7 Prrf'(2-0.44c25. 41 Z lb)) . Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No r/ Subsequent Form Required: Jo — 4 C 4 RBDMS 1-1.- MAR 0 4 2016 P THEROVED SY / Approved by: COMMISSIONER THEfCOMMISSION Date: 3 ..2 yr 3/ //� ?I 'l �r Ic. a ?�l6 / (e ^ Z Submit Form and Form 10-403 Revised 11/2015 p o i t i r 12 months from the date of approval. Attachments in Duplicate III • RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 3 2016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO G 0 r'. 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well r Operations shutdow n r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG Fi 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. k Exploratory r Development i✓ . 213-074-0 ` 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23134-61 7.If perforating, . 182 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will A 1 / Will planned perforations require spacing exception? Yes r No i/ J KRU 2G-17L1-01 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667,25666 • 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): Plugs(MD): Junk(MD): 16889 6161 16510' 6147' 1597' None None Casing Length Size MD TVD Burst Collapse LINER L1-01 2218 2.625 16510' 6147' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots 14375-15370' ' Slots 6139'-6135' 3.5 L-80 13889 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None MD=0 TVD=0 Packer=Baker ZXP Liner Top Packer . MD=13848 TVD=5870 12.Attachments: Proposal Summary Jr WellBore Schematic f 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Jam. 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:3/15/16 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG P • GSTOR r SPLUG r GINJ r Op Shutdow n r Abandoned r Commission Representative: 17.I hereby certify that the foregoing is true and the procedure approved Contact: Darrell Humphrey/Bob Christensen herein will not be deviated from without prior written approval. Printed Name Darrell Humphrey Phone:659-7535 Email: n1139Ca�conocophillips.com Title: NSK Production Engineering Specialist Signature _ 1 , Z - Z �p �-wr-e.�1/` �---_ � Date: i n Use Only o Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 (4-0-7-7 Plug Integrity r BOP Test r Mechanical Integrity Test 171Location Clearance r Other: Post Initial Injection MIT Req'd? Yes / No r Spacing Exception Required? Yes r No r✓ Subsequent Form Required: /0 — 40 APPROVED BY Approved by: API /,� (� /� COMMISSIONER,rTHE COMMISSION Date: f pzl ►I'( 1 1 RI 1 _ 1 J � Submit Form and Form 10-403 Revised 11/2015 Approved application i I 1 o t s to of approval. Attachments in Duplicate 2G-17L1-01 DESCRIPTION SUMMARY OF PROPOSAL Area of Review: Kuparuk well 2G-17 was drilled in 2002 to test the C Sand southeast of the 2G-pad. In 2003 the C sand was hydraulically fractured. A seven day production test showed rates to be uneconomic to justify permanent tie- in to Drillsite 2G facilities. 2G-17 was suspended at this time due to poor economic outlook. In 2013 two CTD laterals, 2G-17L1 and 2G-17L1-01, were drilled in the C sand. CTD producer 2G-17 was placed on production (POP) 2/24/2014. Encouraging production rates led to the approval and drilling of grassroots rotary horizontal injector 2F-22 in late 2014. 2F-22 was POP'd in February of 2015 for a flowback period but strong performance resulted in the decision to permanently tie-in 2F-22 as a producer and convert 2G-17 to an injection well. The top of the Kuparuk C sand was found at 14274' and /6113' tvd The top of the Kuparuk A sand was found at 14390' and /6178' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that the Kuparuk well 2G-17 is located to the southeast of drillsite 2G Kuparuk development, directly south of drillsite 2F. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2G-17 is good and classified as a "Normal Well". A proactive TIFL was performed on 5/20/2015 pre CPF2 Turnaround and passed. A pre-CTD MIT-OA passed on 9/23/2013 to 1820psi. An MIT-IA will be performed once well 2G-17 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker ZXP Liner Top Packer located at 13848' and (5870' tvd). The 9-5/8" 401b/ft L-80 surface casing of 2G-17 was cemented with 495 bbls AS Lite and 248 bbls LiteCRETE. 170 sacks of Class G cement were used for the 7" 26 lb/ft L-80 production casing. The 3-1/2" 9.3 lb/ft L-38 liner, present from 13,847'MD to 14,768'MD, was cemented with 35 bbls of Class G cement. CBL and interpretation of the cement quality: The CBL interpretation was completed on the PTD's. 1 (Oh cu ( 6r►„ef5,'04 a' rhe $'t'4 ect L'e/' is fJctcr Of a fro$ect to e II's4 c p o fr 7/11 Pcro/- f,#- ry f sr o,of Fd tat_ aAd shv Doff Phe. v/h` et* /ec©,e7. "r2 * % • Loepp, Victoria T (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, February 19, 2016 2:07 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2G-17(PTD 202-243); 2G-17L1(PTD 213-073); 2G-17L1-01(213-074) Conversion to WAG Attachments: 2G-17 Final CTD Schematic.pdf;2G-17L1 Prod to WAG 10-403 01-29-16.xlsm; 2G-17L1-01 Prod to WAG 10-403 01-29-16.xlsm; 2G-17 Prod to WAG 10-403 01-29-16.xlsm Follow Up Flag: Follow up Flag Status: Flagged Victoria-Below are the responses to your questions regarding the sundry application for 2G-17, L1& L1-01. I have attached a new schematic and also revised sundry documents to show the new value for the MPSP. This was recalculated using an initial pressure. Due to a formatting error a 'attached to the psi value.This has been eliminated to correctly reflect the psi value. Let me know if I need to resubmit a new sundry or if this will suffice.Also let me know how to proceed with filing a variance if one is still needed. Thanks, Darrell Humphrey/ Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907)659-7535 NSK-69 Pager(907) 659-7000 (924) From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, February 18, 2016 7:36 AM To: NSK Prod Engr Specialist Cc: Kanady, Randall B Subject: [EXTERNAL]KRU 2G-17(PTD 202-243); 2G-17L1(PTD 213-073); 2G-17L1-01(213-074) Conversion to WAG Darrell, This well and the laterals were originally permitted as producers. Several issues: 1. The TOC is indicated at 13890' MD. Is this the TOC for the 3-1/2" liner or for the 7" production casing?What is the TOC for the 7" production casing? How was this TOC determined? The t _ _,he 4/30/2013 Radial Cement Bc._,d Log of the 3.5" liner was found to be 13, 890' . The 7" production casing did not have a CBL completed. The TOC was calculated based on a conservative excess cement factor and determined to be at 13, 675' . This information is noted (including calculations) in the 2G-17 Area �r review word 2G-17 CBL and interpretation of the cement quality of the subject well The 9-5/8"401b/ft L-80 surface casing of 2G-17 was cemented with 495 bbls AS Lite and 248 bbls LiteCRETE. 170 sacks of Class G cement were used for the 7" 26 lb/ft L-80 production casing.The 3-1/2" 9.3 lb/ft L-38 liner, present from 13,847'MD to 14,768'MD,was cemented with 35 bbls of Class G cement. 1 • • A Radial Cement Bond Log was run on April 30,2013 to determine the cement job quality prior to drilling CTD laterals from the 2G-17 wellbore.The casing bond log request specified investigation over the 3.5" liner interval of 14,000'- 14,400'MD—per the radial cement bond log report,good cement bond was observed over the interval of 14,000'- 14,400'MD. Estimated top of cement was determined to be at 13,890'MD.The estimated top of cement accounts for 382'of good quality cement above the producing zone. The 7" production casing, set at a depth of 14,027'MD, overlaps with the 3.5" liner,set from 13,848'MD to 14,768'MD, by 179'.The radial cement bond log run on April 30, 2013 shows that at least 137' of the 179'overlap has a good cement bond.The 137' of good cement bond exceeds the 20 AAC 25.030(6) requirement of 100' overlap between outer and inner strings when the production string is a liner. The 7" production casing cement job was designed to pump 170 sacks of Class G cement based on a planned 75%excess and desired 800' cement shoe track. Following the 7" production casing cement job the decision was made to drill ahead and attempt to log the cement job at a later time due to the logging tools not working.The cement bond log of the production casing was not completed at a later date. From the drilling report on 1/14/2003: • CMT 7"" Csg- Pumped 5 bbls CW 100,Test CMT lines 3000psi, Pumped 35 bbls CW 100, Drop bttm plug, pump 50 bbls Mudpush, pump 36.5 bbls 15.8 ppg G Slurry,Drop Top Plug, Kick out plug w/20 bbls wash up-Try over to rig for displacement • Rig displace @ 6 bpm, 600 psi- Bumped plug to 1500psi (900 psi over pump rate) Slowed pump rate to 3 bpm to bump plug-CIP @ 11:30- Floats held ( Shoe @ 14027' MD-5972'TVD) From the drilling report on 1/17/2003: • TIH to 13905-Tag CMT @ 13,905' -Std bk 1 std ****NOTE****** With only the Rec,Dir,Gama & Pressure portions of the logging tools working the decision was made to drill ahead and attempt to get the logs at a later time (Mad pass or E-line logs) Calculated top of cement as follows: • Cement pumped = 36.5 bbls 15.8 ppg Class G cement slurry • Top of cement in production casing= 13,905' MD • Production casing shoe = 14,027' MD • Volume of cement in 7" (ID= 6.276") production casing: (14,027'—13,905')*(rt*6.276"2)/4=26.21 ft3- 26.21 ft3(lbbl/5.615 ft3) =4.67 bbls • Cement displaced into annulus= 36.5 bbls—4.67 bbls= 31.83 bbls • Height of 31.83 bbls of cement in the annular space between 8.5" hole and 7" 26Ib/ft casing assuming 75% excess factor (31.83bb1*0.25"'44.28ft" =352 ft 1 } lbbl j • Calculated top of cement= 14,027' MD—352' of cement= 13,675' MD Per the 3.5" liner radial cement bond log 382'of cement is present above the producing zone.The 7" production casing and 3.5" liner overlap for 179',of this 137'was shown to have good cement bond.Assuming an excess factor of 75%,the top of cement behind the 7" production casing is 13,675'MD,yielding a minimum of 352' of cement behind pipe.Total cement above the C sand producing zone (14,272'—13,675') is 597', meeting the required 500' minimum above production zones. 2. The packer depth of 13847' MD is 432' above the top perforation which does not meet regulation 20 AAC 25.412(b).A variance must be requested. Please let me know what needs to be done to request a variance as I have not done one of these before. 2 • 3. The MPSP on each of the 10-403 forms is listed as 1597'which does not make sense This has been corrected 2751 psi using an initial well pressure. 4. There is a well bore schematic in the 10-407 for the laterals drilled in 2013 which shows the motherbore as well as the laterals. I would recommend you include this schematic with the sundry applications when they are available for clarity. CTD Multi Lat schematic is attached. Please get with the production engineer to address these issues. Thanx, 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.Loepq(a�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.Loeop@alaska.gov 3 • 0 §§ CO r- %{ \\ ,t,-- co _ , f\ -4" /\ \/ ® m CO /£ a§ CV \\ \% & \ r 'I % \ - `! io # c C k '� ZS 23 7 w f j� ,r05 2 \g - G 0 E y a I j( \ ° \ 2 02t , . \ a / �� \ / b 2p � 'I : I co j \) § � f § /f G �' \I / I \ \ H\ \ k / co k» ( II �I 2 e e ; 75 & ® # § £ ( I, II - J 'iv c 03C- _» /\ E § c & I I — / Ii �� 8 Ci en o.o -YQ I �| & \ CO 0\ (RI:6 k ) J : \ u 22 0251 2 } 3 \ 11 i§ 3 o * f 0 0 ° \ % N § ( ¥$ I I S = - k \ § 'I Ii %& 0 k J § ) § 2 ) _ a of 5| ƒƒ \ f 00 ) / ! / - ® 0 » i q \ \ \ ) ¥& . ¥q n m nn n % CO \ � ) ) %2 �I }• oe 6\ H{ � �{ o ,, it / § $ I © 'di � )11 )/ % \} (6 2 ° \! \ /6 § 43i 0ca k § Li, a/ CO T ° 1T_JI -- HI CU= � . 2 # q § / °o ao o \\ 76co 1 « \o \§ } k§ }§ §\ 2\ \\ cri &2 OA ®B kf \/ IN §e �� • \,43) ,43.) )} P/ 3(\( !{}74 }7§)§ k) §\11 � ) 2- -42t 2t / \/\\$/() / / )= w\\ \ r4) - f Gm( km2 ) }{(k]{f/{{ m � \ gd }f § � e \k / \ 2 z 0 , r tgatu . 2 w � �> 2 2\ 0 e . / \7 \ go \( /\ ) O . | \ CLO2E'57 s.CL32_ff AC L32E= 7 ACLO2E'ee 42 �� ..e..®..,s.�.. Ku•'aruk Ri -r Unit • I i r ACLO25S888 ;.r 13.Jan1G 0114 Mi.2G-17 Radius ConocoPhillips 0114 Mi_2G-17L1 Radius Alaska, ire.. 0114 Mi.2G-17L1-01 Radius KRU Boundary 2G-17 10-403 Sundry Map C4.Ku paruk PA Boundary Pad Outline 0 0.15 0.3 0.45 0.6 GPAI Lease Miles KUP PROD • 2G-1711-01 ConocoPhillips ; Well Attributes Max Angle&MD TD ♦ Wellbore API/UWI Field Name Wellbore Status MD ftKB Act Btm(ftKB) Alaska. Ind 9I C�.,t°gdaips 500292313461 KUPARUK RIVER UNIT PROD J 99.80 14,410.40 16,889.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 2G-1711-01,10/2015435:55 PM SSSV:NIPPLE 10 3/16/2014 Last WO 27.60 1/27/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ___.... Last Tag SLM 14,257.0 9/15/2014 Rev Reason REMOVE GAUGES lehallf 1/7/2015 HANGER 23.2 1 asing tangs ,, , xlL * Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(No)... Wt/Len(I...Grade Top Thread i,f LINER L1-01(offthe S 2 8 1.920 14201.9 16.510.0 6,146.8 4.70 L-80 ST-L "7 " main wellbore) Liner Details ili Top(ORB) Top(TVD)(kK8) lop Incl(°) Item Des Com Nominal ID(in) CONDUCTOR;28.4110.0 1 11 14,291.9 6,122.5 60.30 SLEEVE SHORTY DEPLOYMENT SLEEVE 1.920 15.370.7 6,150.0 88.19 SLEEVE SHORTY DEPLOYMENT SLEEVE 1.920 NIPPLE.502.0 Perforations&Slots Shot GAS LIFT;4,081.2 I !-. T Dens Top(18KB) Btm(ftKB) (fK8 D) Btm(NO) (shots/f (kK8) Zone Date t) Type Com I 14,375.0 14,597.0 6,138.9 6,137.7 C-4,2G-17 12/2/2013 SLOTS Slotted Liner 1• 4,611.3 15,370.3 6,137.8 6,149.9 C-4,2G-17 12/2/2013 SLOTS Slotted Liner I. 15,371.6 15,842.5 6,150.0 6,153.9 C-4,2G-17 12/2/2013 SLOTS Slotted Liner 15.849.7 16,509.6 6,153.6 6,146.8 C-4,2G-17 12/2/2013 SLOTS Slotted Liner SURFACE;28.45.752.8- Notes:General&Safety End Date Annotation 11/22/2013 NOTE:ADD LATERALS L1,L1-01(off the mainbore) GAS LIFT;7,961.7 , 111.1 aGAS LIFT;10,742.3 in GAS LIFT;12,808.8 111 I GAS LIFT;19737.3 I I SLEEVE;13,789.2 NIPPLE;13,805.2 a LOCATOR;13,849.1 i 'l aJ� SBE;13,850.5 fas $ \9r i' N i✓. V. , PRODUCTION;26.414,027.4- `, �n 0 y, , y � LINER;13,847.9-14,768.0 SLOTS;14,375.0-14,597.0 SLOTS;14,611.315,370.3 I _ SLOTS;15,371.6-15,842.5 1 ) SLOTS;15,849.7-16,509.6 LINER L1-01(offthe main wellbore);14,291.9-16,510.0 • • Roby, David S (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Monday, February 29, 2016 4:24 PM To: Roby, David S (DOA) Cc: Autry, Sydney Subject: RE: Sundry application to convert KRU 2G-17 to a WAG injector Dave-see comments below. Let us know if you need anything else. Darrell Humphrey/Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) From: Roby, David S (DOA) [rnailto:dave.roby©alaska.go_.] Sent: Monday, February 29, 2016 3:18 PM To: NSK Prod Engr Specialist Subject: [EXTERNAL]Sundry application to convert KRU 2G-17 to a WAG injector Darrell/Bob; I'm reviewing your application to convert the subject well,and its laterals,from a producer to a WAG injector and I just want to make sure I am understanding what your plan is. If I'm reading it correctly,you originally intended for the 2F-22 well to be an injector to support the 2G-17 well, but during pre-production of 2F-22 it performed better than expected so the decision was made to swap the two wells and keep 2F-22 as a producer and make 2G-17 the injector, is this correct? Your understanding is correct. Due to the performance of 2F-22 it was decided to swap the service of the two wells. Also, are there any other wells in the fault block containing this producer/injector that will be impacted by the proposed swap in service, and if so what is the service of the other impacted wells? 2F-22 and 2G-17 are the only two wells in the C sand (isolated C sand lobe). Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robygalaska.gov. 1