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216-170
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 8, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Cook Inlet Energy, LLC. 3A REDOUBT UNIT 3A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/08/2025 3A 50-733-20504-01-00 216-170-0 W SPT 5989 2161700 1500 4980 4980 4979 4979 280 280 284 284 4YRTST P Josh Hunt 8/14/2025 Very solid test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:REDOUBT UNIT 3A Inspection Date: Tubing OA Packer Depth 2010 2805 2802 2801IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250814203748 BBL Pumped:1.1 BBL Returned:1.1 Wednesday, October 8, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg 913170ZA P.I. Supervisor FROM: Adam Earl Petroleum Inspector Well Name REDOUBT UNIT 3A Insp Num: tnitAGE210816114504 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2021 SUBJECT: Mechanical Integrity Tests Cook Inlet Energy, LLC_ 3A REDOUBT UNIT 3A Sre: Inspector Reviewed By: P.I. Supry �T312--- Comm API Well Number 50-733-20504-01-00 Inspector Name: Adan, Earl Permit Number: 216-170-0 Inspection Date: 8/14/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A Type Inj N ' TVD 5989 Tubing 0 0 0 o PTD 2161700 Type Test SPT' Test psi! 1500 IA 1671 2823 2814 2812 - BBL Pumped: 1.7 BBL Returned: 1.7 OA 6o 85 - 55 55 Interval OTHER iP/F P Notes: Required pre-injection for start-up ✓' Wednesday, August 25, 2021 Page I of 1 MEMORANDUM TO: Jim Regg �°,lF�Z7/C9 P.I. Supervisor rq FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 27, 2019 SUBJECT: Mechanical Integrity Tests Cook Inlet Energy, LLC. 3A REDOUBT UNIT 3A Ste: Inspector Reviewed By: Jp P.I. Suprv-- NON -CONFIDENTIAL Comm Well Name REDOUBT UNIT 3A API Well Number 50-733-20504-01-00 Inspector Name: Jeff Jones Permit Number- 216-170-0 Inspection Date: 12/132019 Insp Num: mitJJ191227091008 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A Type Inj v✓' TVD 5989 ' Tubing 4340 4345 4345 4345 PTD 2t61700 Type Test SPT T¢St pSl 1500 IA 304 2805 2605 - 2805 - BBL Pumped: 3.5 - BBL Returned: 3.5 OA 30 30 30 30 Interval REQvAR P/F P Notes: 2 year MIT -]A per AID 32.001 l well room inspected, no exceptions noted. The Osprey platform appeared very clean, orderly and in good condition. Friday, December 27, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE; Wednesday,December 27,2017 TO: Jim Regg 2Z?l P.I.Supervisor / SUBJECT:Mechanical Integrity Tests COOK INLET ENERGY,LLC 3A FROM: Brian Bixby REDOUBT UNIT 3A Petroleum Inspector Src: Inspector • Reviewed Bp, P.I.Supry NON-CONFIDENTIAL Comm Well Name REDOUBT UNIT 3A API Well Number 50-733-20504-01-00 Inspector Name: Brian Bixby Permit Number: 216-170-0 Inspection Date: 12/23/2017 , Insp Num: mitBDB171226091310 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A Type Inj W` TVD 5989 Tubing 1970 ' 1970 1965 - 1965 PTD 2161700 - Type Test SPT Test psi 1500 " IA 425 2810 - 2810 - 2810 BBL Pumped: 3.5 - BBL Returned: 3.5 OA 25 35 37 37 - IntervalT OTHER ✓ [IP/F , P Notes: MIT for administrative approval paperwork.Normal injection tubing pressure on this well is about 4330 psi on the tubing.It was agreed to lower the injection pressure to 2000 psi and test to 2500 psi for the MIT thru the AOGCC office. 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CN co 7 00 00 00 00 co 00 00 00 00 00 W 00 00 00 25 ° w0 z N N N N N N N N N N N N N N N O ..r..F- coOQ ° E - E0- U•_ 0 00 I-0 IS OLL 0 d a) 2 Uo ow y 0 U U 0 0 0 0 U U 0 0 0 0 0 Z iTi a a O 0 a 0 F- c. -y 0 co c. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d 0. re o I 3 � aI w w w w LU LU w LU LU w LU w w LU • 0 - -----_- N 0 1 c N,- N o o O ii m U ' >- } } O N N LL co !, e) U 0 Z 2 co a a) O ml 0co co m -o c •� °� °> c a o Z a) a) c i1 U d m a ❑ ❑ Q Q Q M it M N N 2, III M M 0 0 O O a1 > j D a) D U U Z W Ct U ial aii ci ai m N Lai N i it it Il ❑ it N 0 0 0 U N c9 a) I J D O O O O d O E m J N E I 1"0 �/ N N N N•(0 'Li 0 �0 N 1 D IX C, Zn, W W W W W O w c r� n r- n • U II. :° m CL w e « N N 5.1! N N 1 7 Q£6 co ❑ W W co co co U) Z vi 0 Ce Z v v v o a m m ll E W Y . a) co m N O Z d (p o O O > o V V I ZN r Q co +°' coN O O O) d 3 rI o E •'C+ I III J 0 '6 U U 1 /� to c Cli c0 co cr co I G N y co O °" O N o 4) w cv U O 0 a) o 0 } � E N Qo 0 1:1m to .,lo E. E QN o 1 ra MII N t Na C Z` CaZ coaa)) E 7 to 5 0 E I- 0:1 a) t co c - a) m co .- ICC • ca `� 0 I cca 0 Oro Q Z E ..0 >,. E U D 1 Z ) ❑ ❑ ❑ ❑ ❑ C , (Q N N l 1dd N f6 N f0 N .N- O Q 17V1 C O N O bbbb i5 E coT ✓ H 1 coi co cc 0000 co c > •co K o r m co w E a O d tD lac co cc ao co ✓ N N N N N 6 w 0 H y d N a a) a' o c p2E 2 ai ',. ce •7 N , 10 CO O W aa) Y V O N c ) D NZ F c F- •7 Z c m o • o co o Q •O o Q o ❑ c c U U U U U 2 . 3 t a 0) 10` rt _a) ° E Q V n > 0 o -° a) o N I Od a• ❑ ❑ ❑ ❑ ❑ ❑ m LL 2 a) 0 a ❑ o c wWW Ww F. 0 a 0 0 0 c 100 1 0 r • GLACIER RECEIVED June 14th, 2017 JUN 2 2 2017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: RU-03A Well Completion Cook Inlet Energy, LLC Permit to Drill NO: 216-170 API No: 50-733-20504-01-00 Dear Ms. Foerster, Please find our enclosed 10-407 Well Completion Report for the RU-03A well. Included is the 10-407 form,drilling summary,wellbore schematic,final survey,and casing and cementing report. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp wholly owned company) 10-407 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax Y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20MMC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑✓ ` WAG❑ WDSPL❑ No.of Completions: 1 Service 2 • Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or5i3pH 14.Permit to Drill Number/ Sundry: COOK INLET ENERGY LLC Aband.: -4/44/2647 �. • 216-170/317-107/3/7-/•.O 3.Address: 7.Date Spudded: 15.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 3/26/2017 - 50-733-20504-01-00 • 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 1910'FSL,314'FEL,Sec. 14,T7N,R14W,SM 4/8/2017 • REDOUBT UNIT#3A • Top of Productive Interval: 9.Ref Elevations: KB: 89' 17.Field/Pool(s): 468'FNL,307'FWL,Sec.30,T7N,R13W,SM GL: n/a BF: Redoubt Shoal Undefined,Undefined Oil c Total Depth: 622'FNL,712'FWL,Sec.30,T7N,R13W,SM 10.Plug Back Depth MD/TVD: 18.Property Designation: 16396'MD/12579'TVD ADL-381203(surface),ADL-374002(TD) 1 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- 200627.483 y- 2449933.254 Zone- 4 16482'MD/12650'TVD LOCI 01-004 TPI: x- 206340.16 y- 2442128.83 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 206738.7 y- 2441968.05 Zone- 4 n/a n/a 5.Directional or Inclination Survey: Yes U (attached) No H 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 45 (ft MSL) 14176'MD/10962'TVD 22.Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary LWD:Gamma Ray,Resistivity,Density,Neutron Wireline:CBL, Multiple Propagation Resitivity,Compensated Neutron/Porosity,Compensated Bulk Density,Gamma Ray,Memory Log 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 4.5" 15.1# P-110 7483' 16479' 5990' 12647' 6.75" 690.5 cuft 15.8 ppg Class G none 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 4.5" 7505' 7483'MD/5989'TVD 3-1/8",6spf,60 deg phase,EH 0.41" ;t}MF'LE1 ION 16255'-16295'MD/12463'-12497'TVD(5/28/17) . 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. 16356'-16376'MD/12546'-12563'TVD(5/29/17) - DATE Was hydraulic fracturing used during completion? Yes❑ No ❑✓ VERIFIFD Per 20 AAC 25.283(i)(2)attach electronic and printed information �� LI- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED JUN 22 2017 27. PRODUCTION TEST Date First Production: AGC Method of Operation(Flowing,gas lift,etc.): n/a Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate ..► Form 10-407 Revised 5/2017 CONTINUED ON PA9E 2 Submit ORIGINIAL only /CI la' 7, /e /7 , (41/4//7 RBDMS L1L' JUN 2 6 2017 G 28.CORE DATA Conventional re(s): Yes ❑ No Sidewall CoresYes ❑ No ❑✓ If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form,if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME 'R4R, 1NO Xdb HO Well tested? Yes ❑ No 2 Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval , information,including reports,per 20 AAC 25.071. Hemlock Coal 12040' 15700' Top Hemlock (IP 12095' 15780' Middle Hemlock 12300' 16050' Lower Hemlock 12512' 16314' Formation at total depth: Lower Hemlock 31. List of Attachments: Daily Operations summary,Wellbore schematic,directional survey,casing and cementing report Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Authorized Contact Phone: 907-433-3808 Signature: �-- Date: 6/21/2017 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity,permeability, fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1110 GLACIER RU-03A Daily Operations Summary API: 50-733-20504-01 Permit #: 216-170 Rig: Osprey Rig 35 Date and Footage Drilled as of 24:00 hours. Activity 26 March 2017 TD: 14207' MD; MW: 10.2 ppg OBM;Vis: 68; Continue RIH with whipstock 20' � assembly to 13850'.Orient whipstock to 45 deg left of high side. Set / whipstock with top of window at 14176'. Mill window and new formation to 1 14207' MD. Perform FIT to 1500 psi, 13.0 ppg EMW. CBU and POH to 6954' �t ,0,71j` MD. 27 March 2017 TD: 14207' MD; MW: 10.2 ppg OBM;Vis: 68; Continue POH and LD milling 0' BHA. MU 6-3/4" Directional BHA and RIH to 7844'. 28 March 2017 TD: 14207' MD; MW: 10.2 ppg OBM;Vis:70; Continue RIH to 14014'. Orient 0' and RIH to 14187'.Tagged and unable to work past. POH with Drilling BHA to 4891' MD. 29 March 2017 TD: 14210' MD; MW: 10.2 ppg OBM;Vis: 84; Continue POH with Drilling BHA 3' and LD. PU Milling BHA and RIH to 14175'.Tag at 14182' MD, sat down 20K. Break circulation and ream window. Drill from 14207'to 14210'. Back ream through window. Pull up 1 stand, circulate and condition mud. POH to 13700' MD. 30 March 2017 TD: 14210' MD; MW: 10.2 ppg OBM;Vis:85; Continue POH with milling 0' assembly. PU 6-3/4" Directional BHA and RIH to 14148' MD. Orient tool face. 31 March 2017 TD: 14683' MD; MW: 10.2 ppg OBM;Vis: 76; Slide through window,tag 473' bottom at 14210'. Drill ahead, sliding as necessary, from 14210'to 14683'. 01 April 2017 TD: 15295' MD; MW: 10.2 ppg OBM;Vis: 85; Continue to drill ahead, sliding 612' as necessary,from 14683'to 15295'. 02 April 2017 TD: 15533' MD; MW: 10.2 ppg OBM;Vis: 83; Continue to drill ahead,sliding 238' as necessary,from 15295'to 15381'. Circulate bottoms up. POH to 14158' (above window).Tight spots encountered at 15035' & 14932', worked through. Circulate while working on top drive. Orient through window and TIH to 15295'.Wash from 15295'to 15381' due to tight hole. Drill from 15381'to 15533'. • • GLACIER 03 April 2017 TD: 15800' MD; MW: 10.2 ppg OBM;Vis: 79; Continue drilling from 15533'to 267' 15569'.Washout in pipe at rig floor, unable to break connection. Troubleshoot top drive. POH to 14158', repair top drive.TIH to 15569'. Continue drilling from 15569'to 15800' MD. 04 April 2017 TD: 15861' MD; MW: 10.2 ppg OBM;Vis: 91; Continue drilling from 15800'to 61' 15861' MD.Circulate while reciprocating and rotating. POH pumping for 5 stands. Continue POH on elevators to 1966'. 05 April 2017 TD: 15861' MD; MW: 10.2 ppg OBM;Vis:97; Finish POH and LD BHA. Prep 0' for BOPE test. Test BOPE to 250 psi low/4500 psi high (annular 250 psi low /2500 psi high). Witness of test was waived by AOGCC rep, Mike Quick. MU 6-3/4" directional BHA and RIH to 1700'. 06 April 2017 TD: 16032' MD; MW: 10.2 ppg OBM;Vis: 95; Continue RIH to 15508' MD, 171' wash to 15861'. Drill from 15861'to 16032' MD. 07 April 2017 TD: 16414' MD; MW: 10.2 ppg OBM;Vis: 84; Continue drilling from 16032'to 382' 16414' MD. t 08 April 2017 TD: 16482' MD; MW: 10.2 ppg OBM;Vis:81; Continue drilling from 16414'to Hi% 68' TD at 96487' Mn/.12650'TVD. Circulate while rotating, POH 1 stand per circulation. Wiper trip to 15500'. RIH to TD, circulate while rotating and reciprocating. POH on elevators to 14100', wipe back thru tight spots. Continue POH to 13292' MD. 09 April 2017 TD: 16482' MD; MW: 10.3 ppg OBM;Vis: 93; Continue POH to 9103' (7-5/8" 0' liner) and circulate. POH and LD BHA. RU to run 4-1/2" liner. MU Shoe track of 4-1/2" 15.1#P110 Geo-Conn liner. 10 April 2017 TD: 16482' MD; MW: 10.4 ppg OBM;Vis: 110; Continue RIH with 4-1/2" 0' 15.1#P110 Geo-Conn liner to 14185' MD. 11 April 2017 TD: 16482' MD; MW: 10.2 ppg OBM;Vis: 106; Break circulation. Finish RIH 0' with 4-1/2" 15.1#P110 Geo-Conn liner to 16479' MD without issue. Circulate while reciprocating. Rig up cement equipment.Cement liner with 35 bbls spacer, 123 bbls 15.3 ppg Class G cement, displaced with 248 bbls produced water. Bumped plug,set packer at 7500' MD. RD cement equipment. 12 April 2017 TD: 16482' MD; MW: 10.2 ppg OBM;Vis: 108; Clean pits. Prep 4-1/2"tie back string. • S GLACIER 13 April 2017 TD: 16482' MD; MW: 8.4 ppg Prod H2O;Vis: 27; Release running tool and sett� �w packer. Unsting from hanger. Displace annulus from OBM to produced �✓� water. POH and LD running tool. Pressure test casing to 2500 psi—good. PU Seal/latch assy and RIH on 4.5" 15.1#P110 casing tie back string to 7472' MD.Wash down and tag liner top at 7494' MD. Latch into PBR at 7518' MD. 14 April 2017 TD: 16482' MD; MW: 8.4 ppg Prod H2O;Vis: 26; Clean pits. Land hanger and Pressure test void to 5000 psi—good. Pressure test annulus, seals, and 6 L✓ hanger to 2500 psi—good. RU Eline and RIH with CBL and set down at 16140' MD, could not pass thru, log available interval, POH, RD Eline.TOC @ 12975' MD. RU slickline and RIH w/3" GR. 15 April 2017 TD: 16482' MD;Continue RIH with 3" GR and set down at 16150' MD, could not pass, POH. RIH with 2.2" GR and set down at 16154' MD, could not pass, POH.Set BPV and ND BOPE. NU dry hole tree, pull BPV and secure well. Clean pits. 16 April 2017 TD: 16482' MD; Continue cleaning pits and housekeeping. Prepare to skid. Release rig from RU-03A. Move for batch operations. 24-27 May 2017 Coiled Tubing Operations—Report of Sundry(317-171) submitted separately. 27 May 2017 RU Eline and pumping unit. RU lubricator and PU perf guns. 28 May 2017 RIH with 3-1/8" (6spf, 60 deg phase) perf gun#1, perf 16275'—16295' MD. RIH with 3-1/8" (6spf, 60 deg phase) perf gun#2, perf 16255'—16275' MD. Perform injection test. Monitor pressure drop. RIH with 3" StimGuns#1 and perf 16260'—16270' MD. Part of StimGun left downhole. 29 May 2017 RIH with 3" StimGuns#2 and misfire. POH and MU 3"StimGuns. RIH with 3" StimGuns#2 Rerun and perf 16275' - 16287' MD. POH and hung up at 15945',worked free. Perform injection test. Monitor pressure drop. RIH with 3-1/8" (6spf, 60 deg phase) perf gun#3, encounter obstruction at 16377' MD.Adjust interval and perf 16356'—16376', POH. RIH with 3-1/8" (6spf, 60 deg phase) perf gun#4. 30 May 2017 Continue RIH with Perf gun#4. Encounter obstruction at 16332' MD, unable to pass. POH with perf gun#4 without firing. RD Eline. ND frac tree and NU permanent tree.Test tree—good.Turn well over to Production for injection operations. aiRU-03A WI-Current Completion Schematic Date: 6-Jun-17 < 1111, • Version: Current GLACIER 130" 150#A-36 260'MD ID-28" Welded 260'TVD r• rI a 4-1/2"15.1#P110 Geoconn-ID 3.832" Qh. 1 rr @ 7500'MD S" 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole AA III. ID-12.25" BTC 3,024'TVD 5^ 1 C V. r} 1 4 1/2"X 9 5/8"Liner Hanger tr TOL @ 7,500'MD I.k,'r Perforations It MD TVD Feet 7,780-7,800 -6,203-6,219 20 "4 7,805-7,818 6,223-6,233 13 t+ .2 > .,„f Top of 7-5/8"x 9-5/8"Liner©9,103'MD li 9 5/8" 47#L-80 9,332'MD 121/4"Hole ` ID-8.50" BTC 7,416'TVD Vii, t . . TOC(CBL):12,975'MD :1 Window �Y 7 5/8" 29.7#L-80 14,176'MD E 8 1/2"Hole ID-6.75" Hydril 521 10,962'TVD • r 143 a'• Perf&Stim Intervals .:. 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S v) cv_-. w: 1 d :7 —n coy O � cu LL, com m m wD rm o n m m w Nr o LL >' J a a, 0 a m t3 m m N D a A O V) U N D J 0) 2f Ny N D C N Q m > - 3k 0- N N N N o O a H U —N 0) 0 o 0 m N 0 4 ct O .53 N- —1-. o co o0 W Vr Q o 0 0 0 0 0 o O O o o .n o u) o �n o 'n o N o 'n Ips O O N N n O coN j ,troy=4Pui L.I,,SN N M L ^(31)41dea ieopan anJI • 0 Glacier Oil 8 Gas(Cook Inlet Energy) CASING&CEMENTING REPORT Well No./PTD# RU-03A PTD 216-170 Date 17-Apr-17 County Alaska State Alaska Supv. CASING RECORD-Production Casing TD 16482'MD/12650'TVD Shoe Depth: 16479'MD/12647'ND PBTD: 16396'MD/12579'ND Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 41/2 GeoConn Wfd 2.16 16,479.00 16,476.84 1 4 1/2 15.1 P-110 GeoConn 39.05 16,476.84 16,437.79 F.Collar 41/2 GeoConn Wfd 1.30 16,437.79 16,436.49 1 4 1/2 15.1 P-110 GeoConn 39.11 16,436.49 16,397.38 L Collar 4 1/2 GeoConn Wfd 1.13 16,397.38 16,396.25 217 41/2 15.1 P-110 GeoConn 8,877.18 16,396.25 7,519.07 XO/Pup 41/2 BTC TIW 13.21 7,519.07 7,505.86 Liner Hgr 41/2 BTC TIW 5.17 7,505.86 7,500.69 Packer 41/2 BTC TIW 17.09 7,500.69 7,483.60 Totals 8,995.40 Csg Wt.On Hook: Type Float Collar: Float No.Hrs to Run: 32.5 Csg Wt.On Slips: Type of Shoe: Reamer Casing Crew: Wfd Fluid Description: 10.2 ppg OBM/PV=27 YP=24 Liner hanger Info(Make/Model): TIW IB-TC-DD Hyd.Hanger Liner top Packer?: X Yes_No Liner hanger test pressure: 2500 psi Centralizer Placement: centralizers on joint in shoe track to 16006'and every other joint to 14046'. CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 12.5 Volume pumped(BBLs) 35 Lead Slurry Type: Production cement-Class G Yield(Ft3/sack): 1.35 Density(ppg) 15.3 Volume(BBLs/sacks): 123 bbls/511 sacks Mixing/Pumping Rate(bpm): 4 Tall Slurry Type: Yield(Ft3/sack): ) Density(ppg) Volume(BBLs/sacks): Mixing/Pumping Rate(bpm): 1,1 Post Flush(Spacer) 1 Type: Density(ppg) Rate(bpm): Volume: T. Displacement: Type: Produced H2O Density(ppg) 8.5 ppg Rate(bpm): 5 Volume(actual/calculated): 247/254 FCP(psi): 450 psi Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press 2900 psi Casing Rotated? Yes X No Reciprocated? X Yes No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: None 61") C ) (1 Cement In Place At: 21:00 Date: 4/11/2017 Estimated TOC: 13000'MD l[C Method Used To Determine TOC: CBL-TOC at 12975' MD ✓ ee �crw idl�v`I 12,14- Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) -- Lead Slurry .7"j ej i a�' 3(�f $t0 Type: Yield(Ft3/sack): ( " Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry w Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 74` 1 p--/—17 v, Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: NDisplacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: . . AECEIVEL Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 S n17 r Anchorage, Alaska 99501 ' 1' ` ` Phone: (907) 334-6745 Fax: (907) 334-6735 GCC DATA TRANSMITTAL Date: April 18, 2017 To: Meredith Guhl From: Stephen Ratcliff AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Anchorage,AK 99501 Phone: (907)279-1433 Phone: (907)433-3808 FAX: (907)334-6735 TRANSMITTAL DESCRIPTION Well Data for RU-03A API: 50-733-20504-01-00 Qty Description 1 CD- Resistivity, Gamma Ray, Density, Nuetron, (LWD) 1 RU-03A-Multiple Propagation Resistivity, Compensated Neutron Porosity, Compensted Bulk Density, Gamma Ray, Memory Log (ND) 1 RU-03A-Multiple Propagation Resistivity, Compensated Neutron Porosity, Compensted Bulk Density, Gamma Ray, Memory Log (MD) 1 RU-03A-Gamma Ray Cement Bond Log Please sign below to acknowledge receipt. Received By: Date: Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC/AOGCC 4 14 16 Otter • STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LI Plug Perforations U Fracture Stimulate LJ Pull Tubing LJ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT Cleanout 0 2.Operator COOK INLET ENERGY LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑ Exploratory ❑ 216-170 f 3.Address: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK, Stratigraphic ❑ Service ❑✓ 6.API Number: 99501 50-73320504-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-381203(surface),ADL-374002(TD) REDOUBT UNIT#3A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a REDOUBT SHOAL UNDEFINED, UNDEFINED OIL 11.Present Well Condition Summary: Total Depth measured 16482 feet Plugs measured none RECEIVED true vertical 12650 feet Junk measured none feet JUN 14 2017 Effective Depth measured 16396 feet Packer measured 7483 feet true vertical 12579 feet true vertical 5989 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' 150' N/A N/A Conductor Surface 3507' 13 3/8" 3507' 3024' 5020 2260 Intermediate 9332' 9 5/8" 9332' 7416' 6870 4750 Production 5073' 7 5/8" 14176' 10962' 6890 4790 Liner 8996' 4-1/2" 16479' 12641' 14420 15500 Perforation depth Measured depth 16255-16380 feet True Vertical depth 12464-12566 feet Tubing(size,grade,measured and true vertical depth) 4-1/2" P110 7505'MD 5993'TVD Packers and SSSV(type,measured and true vertical depth) TIW Liner Top Packer 7483'MD 5989'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: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 317-171 Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Authorized Signature: Data 6/14/2017 Contact Phone: 907-433-3808 / if ‘ 7 Form 10-404 Revised 4/2017 rL,JUN 90`@ 1 5 2017 Submit Original Only RBDMS ' • • RECEIVED GLACIER JUN 14 2017 June 14t, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: RU-03A Well Completion Cook Inlet Energy, LLC Permit to Drill NO: 216-170 API No: 50-733-20504-01-00 Dear Ms. Foerster, Please find our enclosed 10-404 Report of Sundry(317-171)for the RU-03A well. Included is the 10-404 form, drilling summary, and wellbore schematic for the completed coiled tubing operations. If you have any questions, please contact me at(907) 433-3808. Sincerely, \\\ Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp wholly owned company) 10-404 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • GLACIER RU-03A Daily Operations Summary API: 50-733-20504-01 Permit #: 216-170 Rig: Osprey Rig 35 Date and Footage Drilled as of 24:00 hours. Activity 24 May 2017 RU on RU-03A. RU Coil. Install BPV and ND tree. NU frac tree. Pull BPV, Install TWC.Test Frac tree to 10K psi—good. RU Coil BOPE. 25 May 2017 Continue to RU Coil on RU-03A. 26 May 2017 Continue RU Coil on RU-03A.Test BOPE 250 psi low/4500 psi high.Witness of test waived by AOGCC Rep,Jim Regg. RIH with Coil Cleanout BHA and tag cement at 16097' CTD. Mill cement from 16097'to 16383' CTD. Tag PBTD at 16383' CTD. CBU and observe cement at shakers. POH while pumping to 15880'. Fill annulus with produced water. RIH with pumps off and tag at 16384' CTD. Pump sweep, POH. 27 May 2017 Continue POH, LD Coil Cleanout BHA. RD Coil. • . RU-03A WI-Completion Schematic • Date: 27-May-17 Version: GLACIER i 30" 150#A-36 260'MD f R ID-28" Welded 260'TVD fi E 4-1/2"15.1#P110 Geoconn-ID 3.832" $� @7500'MD • r + 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole ID-12.25" BTC 3,024'TVD 4 Aw 4'+ 4 1/2"X 9 5/8"Liner Hanger TOL @ 7,500'MD Perforations MD TVD Feet 7,780-7,800 6,203-6,219 20 -; a 7,605-7,818 6,223-6,233 13 �'� Top of 7-5/8"x 9-5/8"Liner©9,103'MD 1 1 9 5/8" 47#L-80 9,332'MD r' 12 1/4"Hole ' .r ID-8.50" BTC 7,416'TVD S• TOC(CBL):12,975'MD "r r Window 7 5/8" 29.7#L-80 14,176'MD 8 1/2"Hole ID-6.75" Hydril 521 10,962'TVD • No perfs at time of CT Cleanout 4 1/2" .15.1#P-110 16,482'MD 6 3/4"Hole 411 IriL ID-3.832" GeoConn 12,650'TVD PBTD:16396'MD/12579'TVD • • `'0� Ty THE STATE Alaska Oil and Gas �� 333 West Seventh Avenue 1.'11"` ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �^a : o�^- C � Main: 907.279.1433 F ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, RU 3A Permit to Drill Number: 216-170 Sundry Number: 317-237 Dear Mr. Ratcliff: 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' 4 Cathy P. erster Ktay DATED this day of June,2017. RBDMS U`' iU 1 6 2011 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 9 2017 APPLICATION FOR SUNDRY APPROVALS � �� 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ '/Perforate ❑✓ Other Stimulate El Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool El Re-enter Susp Well ❑ Alter Casing ❑ Other: 55%/K-4 u 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC • Exploratory ❑ Development ❑ 216-170' 3.Address: Stratigraphic ❑ Service 0. 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 50-733-20504-01-00• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No D✓ REDOUBT UNIT#3A' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-381203(surface),ADL-374002(TD) I REDOUBT SHOAL UNDEFINED,UNDEFINED OIL • 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): 16482' . 12650' ` 16482'' 12650' , 5,000 psi None None Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' 150' N/A N/A Conductor -- -- -- -- -- -- Surface 3507' 13 3/8" 3507' 3024' 5020 2260 Intermediate 9332' 9 5/8" 9332' 7416' 6870 4750 Production 5073' 7 5/8" 14176' 10962' 6890 4790 Liner 8982' 4-1/2" 16482' 12650' 14420 15500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 16255'-16376' • 12463'-12563' 4-1/2" P110 7,500' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): TIW Liner Top Packer 7500'MD/5989'TVD 12.Attachments: Proposal Summary [✓f Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: 6/16/2017 0 . Commencing Operations: OIL ❑ WINJ WDSPL El Suspended 16.Verbal Approval: Date: GAS El WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El 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: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: Sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: .I Date: 6/9/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3 ti—23 Plug Integrity ElBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance CI 44=7F- Co I 01c4 Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS (,t— ie.W.'aO 1 6 2017 Spacing Exception Required? Yes ❑ No V. Subsequent Form Required: /t - 410 il P APPROVED SY Approved by/• COMMISSIONER THE COMMISSION Date: _ �l�,_ / G j�z�l - , �/on D I ( I M A � �'' '3�'7 Submit Form and Form 10-403 Revised 4/201 p valid for 12 months from e date of approval. Attachments in Duplicate • • GLACIER June 9th, 2017 RECEIVED JUN 092017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission AOGCG 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: Redoubt Unit O3A API: 50-733-20504-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for RU-03A, PTD: 216-170 to add additional perforations to the 4-1/2" liner due to the success of the initial perforated zones. If you have any questions, please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave, Suite 310 Anchorage,AK 99501 1 , ' < • • GLACIER WELL NAME-RU-03A Requirements of 20 MC 25.005(f) Well Summary Current Status: RU-03A in online as an injector. Existing Perforations: MD TVD 7780' - 7800' 6203'- 6219') 00 l 1 T 7805' - 7818' 6223' - 6233' 16255' - 16273' 12463'- 12479' 16275' - 16295' 12481' - 12497' 16356' - 16376' 12546' - 12563' Scope of Work: • Rig up Eline. • Perforate selected intervals in specified order. • Establish injection pressure in perforated Zone,if possible. • Rig down Eline. • Turn well over to injection. General Well Information: Reservoir Pressure/ TVD: 5,477 psi @ 16,482' MD / 12,650'TVD MASP: 4,212 psi MPSP: 5,000 psi (max potential pressure) Wellhead Type/Pressure Rating: Eline Lubricator BOP Configuration: N/A Well Type: Water Injector Estimated Start Date: June 16, 2017 Drilling Manager: Sr.Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907)433-9738 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER 1. Program 1. Rig up Eline and Lubricator.Test lubricator to 5000 psi. 2. Rig up surface hard lines and test. 3. RIH with 3-1/8", 6spf, 60 deg phase perf guns. 4. Perforate the following intervals from bottom to top: Top, MD Bottom, MD Top,TVD Bottom,TVD 16144 16164 12376 12392 16166 16186 12394 12409 16198 16218 12419 12435 it16315* 16335* 12513* 12529* 16336* 16356* 12530* 12546* *intervals previously Approved by Sundry 317-150. a. Monitor surface pressure for 30 minutes. 5. RIH with StimGuns and perforate within new interval. 6. Establish injection pressure at 4500 psi for one tubing volume. a. Monitor surface pressure for 1 hour. b. Bleed off pressure. 7. RIH with 3-1/8", 6spf, 60 deg phase perf guns. 8. Perforate the following intervals from bottom to top: Top, MD Bottom, MD Top,TVD Bottom,TVD 16052 16072 12304 12320 t 16076 16096 12323 12338 a. Monitor surface pressure for 30 minutes. 9. RIH with StimGuns and perforate within new interval. 10. Establish injection pressure at 4500 psi for one tubing volume. a. Monitor surface pressure for 1 hour. b. Bleed off pressure. 11.RIH with 3-1/8", 6 spf, 60 deg phase perf guns. 12. Perforate the following intervals from bottom to top: Top, MD Bottom,MD Top,TVD Bottom,TVD 15920 15940 12202 12218 it 15940 15960 12218 12233 a. Monitor surface pressure for 30 minutes. 13. RIH with StimGuns and perforate within new interval. 3 • • GLACIER 14.Establish injection pressure at 4500 psi for one tubing volume. a. Monitor surface pressure for 1 hour. b. Bleed off pressure. 15.RIH with 3-1/8", 6 spf, 60 deg phase perf guns. 16.Perforate the following intervals from bottom to top: Top,MD Bottom,MD Top,TVD Bottom,TVD 15780 15800 12097 12111 /\ 15827 15847 12132 12147 15862 15882 12158 12173 a. Monitor surface pressure for 30 minutes. 17.RIH with StimGuns and perforate within new interval. 18.Establish injection pressure at 4500 psi for one tubing volume. a. Monitor surface pressure for 1 hour. b. Bleed off pressure. 19.RD hardline. 20. RD Eline. 21.Turn well over to injection. 4 •O3A WI-Current Completion Schematic • Date: 6-Jun-17 ' Version: Current GLACIER t Ys 30" 150#A-36 260'MD ID-28" Welded 260'TVD I i „i •" 4-1/2"15.1#P110 Geoconn-ID 3.832" ti 1' ., @ 7500'MD gt- z i' I tx, 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole Aiill ` ID-12.25" BTC 3,024'TVD I.' " r 'i v at, k. n 9y sy y:. 4 1/2"X 9 5/8"Liner Hanger TOL @ 7,500'MD . F. Elt Perforationsinel= 4-.5 .7 MD TVD Feet ` (,. 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 l'::°- .a%'. t-a: 41, Ar Top of 7-5/8"x 9-5/8"Liner @ 9,103'MD t• i 9 5/8" i 47#L-80 9,332'MD v ID-8.50" BTC 7,416'TVD 12 1/4"Hole I i --. r, y« TOC(CBL):12,975'MD q" a" t'4 l 7 5/8" 29.7#L-80 14,176'MD 81/2"Hole , ID-6.75" Hydril 521 10,962'TVD k I.Pert&Stim Intervals MD TVD Feet 1 ? 16255-16260 12463-12469 Peri 6 1 16260-16270 12469-12476 Pert 8-Stim 16270-16273 12476-12479 Perf 16275-16287 12481-12491 Pert&Stim C 16287-16295 12491-12497 Perf 16356-16376 12546-12563 Perf r. n Obstructions tagged @ 16332'&16377' I# I 4 1/2" 115.1#P-1101 16,482'MD 6 3/4"Hole ..I J ` ID-3.832" GeoConn 12,650'TVD PBTD:16396'MD/12579'TVD .03A WI-Proposed Completion SchematicIll 9-Jun-17 Version: Proposed GLACIER '` 30" 150#A-36 260'MD s ji { ID-28" Welded 260'TVD 3 LA 4-1/2"15.1#P110 Geoconn-ID 3.832" f b` , @ 7500'MD y t ° t. 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole . ID-12.25" BTC 3,024'TVD LPi +4! ,, . A k$1 S 196 4 1/2"X 9 5/8"Liner Hanger Il TOL @ 7,500'MD 1' 0 Perforations I, MD TVD Feet p7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 Top of 7-5/8"x 9-5/8"Liner @ 9,103'MD 9 5/8" 47#L-80 9, ' 12 1/4"Hole ID-5818.5" D-8.50" BTC 7,416332'TVD TOC(CBL):12,975'MD 8 1/2"Hole Perf&Stim Intervals MD TVD Feet Window 15780-15800 12097-12111 Planned 7 5/8" 29.7#L-80 14,176'MD 15827-15847 12132-12147 Plznnan #-',`"0 ID-6.75" Hydril 521 10,962'TVD 15862-15882 12158-12173 ri, 15920-15960 12202-12233 Planned 16052-16072 12304-12320 Planned 16076-16096 12323-12338 Planned 16144-16164 12376-12392 Planned d 16166-16186 12394-12409 Planned 0= 16198-16218 12419-12435 Planned 16255-16260 12463-12469 Perf - C 1CC 16260-16270 12469-12476 Pert&Stim 16270-16273 12476-12479 Pert 11= 16275-16287 12481-12491 Pert 8,Slim I= 16287-16295 12491-12497 Perf 16315-16356 12513-12546 Plumes Obstructions tagged @ 16332'&16377' 16356-16376 12546-12563 Perf ,.. 4 1/2" 15.18 P-110 16,482'MD 6 3/4"Hole t._" ID-3.832" GeoConn 12,650'TVD PBTD:16396'MD/12579'TVD • I 1" 1 ojy�"s9 THE STATE Alaska Oil and Gas ~t.��a� Of J /\ sKA Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, Redoubt Unit 3A Permit to Drill Number: 216-170 Sundry Number: 317-171 Dear Mr. Ratcliff: 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 this4---day of May, 2017. RBDMS L1/41AY - 3 2017 • SIVSD STATE OF ALASKA APR ` $ 207 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well E Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Cleanout ' n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development ❑ 216-170 - 3.Address: Stratigraphic ❑ Service ❑� , 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 50-733-20504-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No ❑ / REDOUBT UNIT#3A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-381203(surface),ADL-374002(TD) REDOUBT SHOAL UNDEFINED,UNDEFINED OIL : 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi):_tut, Plugs(MD): Junk(MD): 16482' , 12650' . 16482' - 12650' , psi None None Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' 150' N/A N/A Conductor -- -- -- -- -- -- Surface 3507' 13 3/8" 3507' 3024' 5020 2260 Intermediate 9332' 9 5/8" 9332' 7416' 6870 4750 Production 5073' 7 5/8" 14176' 10962' 6890 4790 Liner 8996' 4-1/2" 16479' 12641' 14420 15500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Planned: 16255'-16380' Planned: 12464'-12566' 4-1/2" P110 7,505' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): TIW Liner Top Packer Packer:7483'MD/5989'TVD 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ • 14.Estimated Date for 15.Well Status after proposed work: 5/14/2017 Commencing Operations: OIL ❑ WINJ ❑, ' WDSPL ❑ Suspended ❑ 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: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: 5_31.---0--+-\\\ Date: 4/28/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance El k., - L3 +'_ l-1 Other: X115-00 1r'S`. 17 P :: (c. ri i a` Post Initial Injection MIT Req'd? Yes Ei No Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: Jo_ 40 RBDMS (, " M Y - 3 201 P47 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:S• Z -1 0 RPIc(3SubminForm ane Form 10-403 Revised 4/2017p t i vali for 12 months from the date of approval. Attachments in Duplicate • • GLACIER RECEIVED APR 2 8 2017 April 28th,2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: Redoubt Unit 03A API: 50-733-20504-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for RU-03A, PTD: 216-170 to cleanout the 4-1/2" casing with Coiled Tubing.' If you have any questions, please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave, Suite 310 Anchorage,AK 99501 1 • • GLACIER WELL NAME—RU-03A Requirements of 20 MC 25.005(f) Well Summary Current Status: RU-03A sidetrack has been drilled. Pre-existing Perforations (Isolated behind cemented and tested liner hanger) MD TVD 7780' - 7800' 6203' - 6219' 7805' - 7818' 6223' - 6233' Scope of Work: • RU Coil tubing. Test Coil BOPE to 4500 psi. • RIH with CT and cleanout as needed. • RD Coil. • Release well to production. General Well Information: Reservoir Pressure/TVD: 5,477 psi @ 16,482' MD / 12,650'TVD MASP: 4,212 psi `' Wellhead Type/Pressure Rating: Vetco Gray- 5M -Wellhead Assembly BOP Configuration: Coil BOPE Well Type: Water Injector Estimated Start Date: May 14th, 2017 Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907)433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • GLACIER Program 1. RU CTU and N/U 1.75" Coil Tubing BOPE. a. Notify AOGCC 48 hours ahead of upcoming CTU BOPE Test. 2. Test CT BOPE to 4500 psi, per Service Company Procedure. •/ a. Be prepared for reverse circulation. 3. Pick up Coil Clean Out BHA with mill and motor. 4. RIH on coil tubing to +/- 16,000'. a. Limit running speed to 60 ft/min and perform pull test for every 1000ft. b. While RIH,pump produced water down tubing and take returns to pits. 5. Reduce running speed to 20 ft/min in anticipation of tag. a. Previous tag with slickline at 16154'. b. Report depth of fill tag on daily report, if indicated. 6. Wash down to TD. 7. Circulate 2 annulus volumes. Monitor returns. 8. POH with coil 500 ft from TD.Stop circulating and RIH with coil pumping and tag bottom. a. If tag is above desired TD depth, then repeat steps 6-8 until fill remains below required depth. 9. POH and L/D Coil clean out BHA. 10. Blowdown coil with N2. 11. Rig down Coil. 3 •, • RU-03A WI-Current Wellbore Schematic Date: 20-Apr-17 Version: Final GLACIER 30" 150#A-36 260'MD ID-28" Welded 260'TVD a . i 1'--' r 4-1/2"15.1#P110 Geoconn-ID 3.832" @ 7500'MD I 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole / ' ID-12.25" BTC 3,024'ND VI • 4 1/2"X 9 5/8"Liner Hanger TOL @ 7,500'MD i Perforations 11111"/ ^ MD ND Feet it " `J� I 7,780-7,800 6,203-6,219 20 C tS0 7,805-7,818 6,223-6,233 13 .-,� I Top of 7-5/8"x 9-5/8"Liner @ 9,103'MD -'i i 9 518" 47#L-80 9,332'MD 12 1/4"Hole ID-8.50" BTC 7,416'ND .y l: ix t L•• TOC(CBL):12,975'MD • • • Window 8 1/2"Hole 7 5/8" 29.7#L-80 14,176'MD ID-6.75" Hydril 521 10,962'ND y` . I. 5:t.f . >• tia r- is It; 1, _ T` ). x� ' .4, 4 1/2" ,15.1#P-110 16482'MD 6 3/4"Hole SII IRIL ID-3.832" GeoConn 12650'TVD PBTD:16396'MD/12579'TVD 1111 • SChlifinkeiltClient: Glacier Oil Coiled Tubing Services Dake: December 4th,2016 Pressure Category 1 BOP Configuration R€,isj Chad Barrett 9 � 9 Revision: 0 (0-3,500 psi) Well Category: CAT I • /�I "NT r' Coiled Tubing HR580 Injector Head&Gooseneck .41 111 i Weight=12,850 lbs �•r�r !i4ti .. 4 4-1/16"10K Conventional Stripper uYLPart 4 5K C062 Lubricator WH PSI 2"1502 x 2-1/16 10K Fla(Manual) (anMgeed Valve ma. 5K C062 x 4-1/16"10K Range 2-1/16 10K x2-1/16 ® 1 C C( -• 1 10K Ranged Valve (ManuaI) IIC' Il i 4-1/16"1010 mad BOP FAO 1 Mei • ;€ii r 4-1/16"10K Flow Cross - ,i © 1,1 011, 'I[Olr'I[Olr' 4 Manual 2x2 Valve 22.1/16"10Kx2-1/16'10K Range Manual 2x2 Valve 3 2.1/16"10K x2-1/16"10K Range Manual 2a2 Valve4 2"1502 x 2-1/16"10K Range 4-1/16"10K x 4-1/16"10K Riser To Deck • 4-1/16"10K x Wellhead Adapter Flange 1110,1Eli 14CI430 �'�'1 4 Wellhead:siak Be; ed • ' V OF Tit �j,�s. THE STATE Alaska Oil and Gas OfAL ASKA Conservation Commission __ _ 333 West Seventh Avenue 1754.t-N-6177- ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF 4LAgY't.' Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, Redoubt Unit 3A Permit to Drill Number: 216-170 Sundry Number: 317-150 Dear Mr. Ratcliff: 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, 247 Cathy Is. Foerster Chair DATED this 2 day of May, 2017. RBDMS (j✓'"v - 3 2017 RECEIVED APR 11 ?017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑., Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run Tubing n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC ' Exploratory ❑ Development ❑ 216-170 ' 3.Address: Stratigraphic ❑ Service Q E. 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 50-733-20504-01-00 ' 7.If perforating: /14 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C("1 719&20AAC25.055r� Will planned perforations require a spacing exception? Yes I. 1 No ILLI REDOUBT UNIT#3A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-381203(surface),ADL-374002(TD) • REDOUBT SHOAL UNDEFINED,UNDEFINED OIL 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): 16482' 12650' 16482' 12650' 7500 psi None None Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' 150' N/A N/A Conductor -- -- -- -- -- -- Surface 3507' 13 3/8" 3507' 3024' 5020 2260 Intermediate 9332' 9 5/8" 9332' 7416' 6870 4750 Production 5073' 7 5/8" 14176' 10962' 6890 4790 Liner Planned:8972' 4-1/2" Planned: 16472' Planned:12641' 14420 15500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Planned: 16255'-16380' • Planned: 12464'-12566' 4-1/2" P110 Planned:7,500' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): TIW Liner Top Packer Planned:7500'MD/5989'TVD 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑., 14.Estimated Date for 15.Well Status after proposed work: 4/14/2017 Commencing Operations: OIL ❑ WINJ ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG Cl 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: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: Sr.Drilling Engineer Contact Email: sratcliff@glacieroil.com Contact Phone: 907-433-3808 Authorized Signature: .-- "-'\\ Date: 4/11/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ' 1—l6o Plug Integrity ❑ BOP Test Mechanical Integrity Test [ Location Clearance CIi-t,c 11.--1%.4. Other: 19 Soo ,CSS i. ea' ..-t_ ri S I Post Initial Injection MIT Req'd? Yes. No ❑ 6,-,....., - ls �jAttcSpacing Exception Required? Yes ❑ Nod Subsequent Form Required: /Q /67 APPROVED BY RBDMS t/v MAY - 3 2017 Approved by:( COMMISSIONER THE COMMISSION Date: S, 2 - /7 f i"Y?1 y/1 4.d r^- A �� 4-1 z7120,1 1`SubmitForm and Form 10-403 Revised 4/2017 �Rolept��Iir/ lid for 12 months from the dat of approval. Attachments in Duplicate • • GLACIER . s April 11th, 2017 r Ms. Cathy Foerster, Chair APR I 1 L017 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 , Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: Redoubt Unit 03A API: 50-733-20504-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for RU-03A, PTD: 216-170 to supersede the previously submitted sundry for perforating the 4-1/2" liner. Based on logs, new perforation intervals have been selected. Additionally, CIE is requesting for approval to complete the well utilizing 4-1/2"tubing. If you have any questions, please contact me at(907) 433-3808. I 3 # ti� Sincerely, s"w ,\\\Stephen Ratcliff Sr.Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave,Suite 310 Anchorage,AK 99501 1 • • GLACIER WELL NAME—RU-03A Requirements of 20 AAC 25.005(f) Well Summary Current Status: RU-03A sidetrack has been drilled. Pre-existing Perforations (Isolated behind cemented and tested liner hanger) MD TVD 7780' - 7800' 6203'- 6219' 7805' - 7818' 6223'- 6233' Scope of Work: • Cement 4-1/2" liner (covered under PTD 216-170). • Run 4-1/2" 15.1# P110 tubing to 7500' MD. • Rig up Eline. • Perforate selected intervals in specified order. • Establish injection pressure in perforated Zone, if possible. • Rig down Eline. • Turn well over to injection. General Well Information: Reservoir Pressure/TVD: 5,477 psi @ 16,482' MD / 12,650'TVD MASP: 4,212 psi MPSP: 7,500 psi (max potential pressure) Wellhead Type/Pressure Rating: Vetco Gray- 5M -Wellhead Assembly BOP Configuration: 13 5/8" 10M BOPE -Annular/VBR/ Blind/ Kill Line/VBR Well Type: Water Injector Estimated Start Date: April 14, 2017 Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907)433-9738 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • GLACIER General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Completion Procedure Requirements of 20 MC 25.005(c)(13) Note: This is a continuation from the RU-03A Permit to Drill procedure. The sidetrack and completion are operationally intended to be consecutive,pending AOGCC approval. 1. Permit to Drill Submitted separately (PTD 216-170). a. Verify 4-1/2" liner has been run and cemented. la'" b. Verify the CBL has been ran and evaluated. I� 2. P/U 4-1/2" 15.1# P-110 Geoconn tubing. 3. RIH to Liner top and latch per TIW Running Procedure. 4. Space out and land 4-1/2" tubing hanger,testha_ngeger. p, 5. Test annulus to, s(TO psi. s`t p e s" �\` 6. Lay down landing joint. ;4 y /3 /7 7. Install BPV and Nipple down BOPE. 8. Install 10K psi tree. 72.-s 9. Rig up Eline. 10. Rig up cement unit and test lines. 11.RIH with 3-3/8", 6spf, 60 deg phase perf guns. 12. Perforate 16,340' - 16,360' MD / 12533'- 12550'TVD (Zone #2). qc' a. Perforate with 4,000 psi overbalance. b. Monitor surface pressure for 30 minutes. 13. Establish injection pressure at highest rate possible for one tubing volume (-235 bbls). 'j '' a. Do not exceed 8,000 psi surface pressure. b. Monitor surface pressure for 1 hour. If injection in Zone #2 is not achieved: 14. RIH with 3-3/8", 6 spf, 60 deg phase perf guns. 15. Perforate 16.360' - 16.380' MD,/ 12550' - 12566' TVD (Zone #1). a. Perforate with 4,000 psi overbalance. .,�.�N b. Monitor surface pressure for 30 minutes. 16. Establish injection pressure at highest rate possible for one tubing volume (-235 bbls). a. Do not exceed 8,000 psi surface pressure. b. Monitor surface pressure for 1 hour. 3 • • GLACIER If injection in Zone #1 is not achieved: 17. RIH with 3-3/8", 6 spf, 60 deg phase perf guns. �., 18. Perforate 16,315' - 16,337' MD / 12513'- 12531'TVD (Zone #3). 4,-°43 a. Perforate with 4,000 psi overbalance. b. Monitor surface pressure for 30 minutes. 19. Establish injection pressure at highest rate possible for one tubing volume (-235 bbls). a. Do not exceed 8,000 psi surface pressure. b. Monitor surface pressure for 1 hour. If injection in Zone #3 is not achieved: 1. RIH with 3-3/8", 6 spf, 60 deg phase perf guns. 2. Perforate 16,255' - 16,295' MD/ 12464'- 12497'TVD (Zone #4). uk a. Perforate with 4,000 psi overbalance. 41/4 b. Monitor surface pressure for 30 minutes. 3. Establish injection pressure at highest rate possible for one tubing volume (-235 bbls). a. Do not exceed 8,000 psi surface pressure. b. Monitor surface pressure for 1 hour. When injection is achieved or if injection is not successful in any of the 4 zones: 1. Rig down Eline. 2. Rig down cement unit and lines. 3. Install BPV and Nipple down 10K psi tree. 4. Install injection tree. 5. Rig Release. 6. Turn well over to injection. INA t TT 64 a--tA-r 5.� { �zr ' /A- INA 4 • RU-03A WI-Current Wellbore Schematic . De: 11-Apr-17 Version:atFinal GLACIER 30" 150#A-36 260'MD ID-28" Welded 260'TVD 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole Al ` ID-12.25" BTC 3,024'TVD }x Planned:TOL @ 7,500'MD 4 1/2"X 9 5/8"Liner Hanger Perforations '• MD TVD Feet • 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 i TOL @ 9,103'MD 7 5/8"X 9 5/8"Liner Hanger 12 1/4"Hole ' ``'' �' 9 5/8" 47#L-80 9,332'MD S+' ID-8.50" BTC 7,416'TVD r-r 4.•• .... if V9 .., t, M f7.: 14, Planned TOC:13,000'MD f,?«- t.:4 • Window I. .1+ 7 5/8" 29.7#L-80 14,176'MD 8 1/2"Hole ', ID-6.75" Hydril 521 10,962'TVD i ' y a i^ 4' t4 so- i4 ... L''.• I. k= ye d 4 1/2" 15.1#P-110 16482'MD 6 3/4"Hole 411 I ID-3.832" GeoConn 12650'TVD • 03A WI-Proposed Completion Schematic • Date: 11-Apr-17 Version: Final < _ GLACIER T' Tubing Hanger-4-1/2"15.10#GeoConn-Top&Btm R ' 30" 150#A-36 260'MD ,a.- ID-28" Welded 260'TVD i ,, •, A 4-1/2"15.108 P110 GeoConn casing A rt i ro 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole ID-12.25" BTC 3,024'TVD Planned:TOL @ 7,500'MD b+ 1111 4 1/2"X 9 5/8"Liner Hanger Perforations -i MD TVD Feet 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 7 5/8"X 9 5/8"Liner Hanger TOL @ 9,103'MD ■ 12 1/4"Hole 4' 9 5/8" 47#L-80 9,332'MD ,. ID-8.50" BTC 7,416'TVD !ikif „ 9w try r , 4-* w • Planned TOC:13,000'MD `A Window 7 5/8" 29.7#L-80 14,176'MD 8 1/2"Hole +-, ID-6.75" Hydril 521 10,962'TVD ir 1 R' Vy roil 9. .5 ` 4 41 /; yyf ;1 /11 *11i ihC. Potential Perf Intervals -Lb "y TVD Feet 9 d5 12464-12 1113C 3) ,337 12513-1:.. 4) 90-16360 12533-12550 c 0 16360-16380 12550-12566 i 41/2" 15.1#P-110 16,482'MD 6 3/4"Hole 1 (_ ID-3.832" GeoConn 12,650'TVD • • Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Thursday,April 13,2017 2:57 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA);Amanda Dial Subject: Re: RU 3A completion sundry(PTD 216-170) Guy, We are planning to perform an injection with produced water after we perf each interval. We will have higher injection pressures and want to make sure that we are compliant. We will cancel the previous completion sundry. Thanks and let me know if you have any further questions. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From:"Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date:Thursday,April 13,2017 at 2:49 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Cc:"Bettis,Patricia K(DOA)"<patricia.bettis@alaska.gov> Subject: RU 3A completion sundry(PTD 216-170) Stephen, What is the reason for the new sundry for RU 3A other than new perf intervals? Can you request by replying to this email that you need to cancel the previous sundry that was submitted March 30th(#317-133)to perforate and run tubing. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or (Guy.schwartz@alaska.gov). 1 RECEIVED it 2 1 67 0 28138 APR 1 8 2017 Cook Inlet Energy, LLC A•` .., 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 DATA LOGGED Phone: (907) 334-6745 Fax: (907) 334-6735 n%/2o1 Er A.K.BENDER DATA TRANSMITTAL Date: April 18, 2017 To: Meredith Guhl From: Stephen Ratcliff AOGCC - Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907)279-1433 Phone: (907)433- 3808 FAX: (907) 334 - 6735 TRANSMITTAL DESCRIPTION Well Data for RU-03A API: 50-733-20504-01-00 Qty Description 1 CD - Resistivity, Gamma Ray, Density, Nuetron, (LWD) 1 RU-03A- Multiple Propagation Resistivity, Compensated Neutron Porosity, Compensted Bulk Density, Gamma Ray, Memory Log (TVD) 1 RU-03A- Multiple Propagation Resistivity, Compensated Neutron Porosity, Compensted Bulk Density, Gamma Ray, Memory Log (MD) 1 RU-03A- Gamma Ray Cement Bond Log Please sign below to acknowledge receipt. Received By: Date: Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC/AOGCC 4 14 16 Otter • • RECEIVED STATE •OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 3 0 2017 APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 GCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0Other: }b e 14 yI Pull Tubing ❑ Change Approved Program❑ Plug for Redrill CI Perforate New Pool ❑ Re-enter Susp Well' CI0 Alter Casing ElOther: C4'►tiv. fS fia [Z 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 24- COOK INLET ENERGY LLC Exploratory ❑ Development ❑ 216-170 I 3.Address: Stratigraphic ❑ Service 0 , 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 50-733-20504-01- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Ga7120.0r•20 AAC 25.055 _ Will planned perforations require a spacing exception? Yesr 1 No REDOU UNIT#3A P 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-381203(surface),ADL-374002(TD) ' REDOUBT SHOAL UNDE ED ND INED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): s(MD): Junk(MD): Planned:16809' Planned: 12900' Planned:16809' Planned: 12901' 5000 psi None None Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' l'0' N/A N/A Conductor -- -- -- -- -- Surface 3507' 13 3/8" 3507' 024' 5020 2260 Intermediate 9332' 9 5/8" 9332' 7416' 6870 4750 Production 5073' 7 5/8" 14176' 109• ' 6890 4790 Liner Planned:9309' 4-1/2" Planned: 16809' -nn=.: 12900' 14420 15500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: • g Grade: Tubing MD(ft): Planned: 16110'-16120' Planned: 12305'-12312' P-110 Planned:7,500' Packers and SSSV Type: TIW Liner Top Packer ackers pnnd�SS ik M 5 (ft)and TVD(ft) Planned:7500'MD/5989'TVD 12.Attachments: Proposal Summary [✓I Wellbore schema£ 13.Well Clas after proposed work: Detailed Operations Program ❑l BOP Sketch Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: AS OIL ❑ WINJ ❑✓ - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and th rocedure approved herein will not be deviated from without prior writt approval. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer Signature A Phone Date .�v""—" 3 907-433-3808 3/29/2017 COMMISSION USE ONLY Conditions of approval: Notify mmission so that a representative may witness Sundry Number: z5'- P>- 3r-7- I33 Plug Integrity ❑ BOP Test IV Mechanical Integrity Test Location Clearance ❑ Other: t gsco r5L 6c)r) l ._Si--, Lt/' .ii APS 1 20 it RB:;,,,IDAs Post Initial Injection MIT Req'd? Yes No ❑ �/ 1jelarJSpacing Exception Required? Yes ❑ No LCJSubsequent Form Required: ( 0e I O 7 ( APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Subndi Four dud Form 10-403 Revised 11/2015 rv ap ds valid for 12 months from the date of approval. Attachments in Duplicate �ez 407- Ot11NAL obi.) y. 5-,7- • • GLACIER RECEIVED MAR 3 0 2017 March 29th, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: Redoubt Unit 03A API: 50-733-20504-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for RU-03A, PTD: 216-170 requesting to perforate the 4-1/2" liner. If you have any questions, please contact me at(907) 433-3808. Sincerely, \:\ Stephen Ratcliff Sr.Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave, Suite 310 Anchorage,AK 99501 1 • • GLACIER WELL NAME-RU-03A Requirements of 20 MC 25.005(f) Well Summary Current Status: RU-03A sidetrack is currently being drilled. Current Perforations MD TVD 7780'- 7800' 6203'- 6219' 7805' - 7818' 6223' - 6233' Scope of Work: • Run 41/2"liner and cement (covered under PTD 216-170). • Run 4-1/2" 15.5#tubing to 7500'. • Rig up Eline. • Perforate 16110'- 16120' MD. / • Rig down Eline. • Turn well over to injection. General Well Information: Reservoir Pressure/TVD: 5,634 psi @ 16,809' MD / 12,900'TVD MASP: 5,000 psi (max anticipated injection pressure) Wellhead Type/Pressure Rating: Vetco Gray- 5M -Wellhead Assembly BOP Configuration: 13 5/8" 10M BOPE-Annular/VBR/Blind/Kill Line/VBR Well Type: Water Injector Estimated Start Date: ASAP Drilling Manager: Sr.Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907)433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 , < • • GLACIER General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Completion Procedure Requirements of 20 MC 25.005(c)(13) Note: This is a continuation from the RU-03A Permit to Drill procedure. The sidetrack and completion are operationally intended to be consecutive,pending AOGCC approval. 1. Permit to Drill Submitted separately(PTD 216-170). A /�- a. Verify 4-1/2"liner has been run and cemented. G�4 �Q b. Verify the CBL has been ran and evaluated. ��- + 2. P/U 4-1/2" 15.1# P-110 Geoconn tubing. ''" co-f- 3. RIH to Liner top and latch per TIW Running Procedure. 4. Space out and land 4-1/2"tubing hanger,test hanger. 5. Test annulus to•1-5fItripsi. 2 S-00 p / 3� 6. Lay down landing joint and install BPV. 7. Nipple down BOPE. 8. Install tree. 9. Rig Release. 10. Rig up Eline. 11. RIH with 3-3/8", 6spf, 60 deg phase and perforate 16110' - 16120' MD. 12. Rig down Eline. 13.Turn well over to injection. 3 0-03A WI-Proposed Completion Schematic Date: 28-Mar-17 Version: Final G L I R r Tubing Hanger-4-1/2"15.10#GeoConn-Top&Btm 5 j 30" 150#A-36 260'MD ',i ' ID-28" Welded 260'TVD 1 4-1/2"15.10 P110 GeoConn Casing T'e as co P,, r. 4 �'= 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole Ad 11111. ID-12.25" BTC 3,024'TVD • TOL @ 7,500'MD IV " . 4 1/2"X 9 5/8"Liner Hanger tr a .. Perforations ' MD TVD Feet .. - 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 �4 4 ' TOL @ 9,103'MD 7 5/8"X 9 5/8"Liner Hanger 12 1/4"Hole }+ 9 5/8" 47#L-80 9,332'MD '' 1 ID-8.50" BTC 7,416'TVD 11 r 44. 14 A :i, L ;1* . Window 4•#,`1 191(/''- 7 5/8" 29.7#L-80 14,176'MD 8 1/2"Hole 4.. „f i / ID-6.75” Hydril 521 10,962'TVD i '-i k: i 1 r 11 ii V. t i. M 44 Perforation Interval "` 1,4 MD TVD Feet 16110-16120 12305-12312 10 ti 4 a i 1ti 4 1/2" 15.1#P-110 16,809'MD 6 3/4"Hole r 1: ID-3.832" GeoConn 12,900'TVD • • Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Thursday,April 13, 2017 3:13 PM To: Schwartz,Guy L(DOA) Cc: Bettis, Patricia K(DOA);Amanda Dial;Carlisle, Samantha J (DOA) Subject: Re: RU 3A completion sundry(PTD 216-170) Thank you! Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From:"Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date:Thursday,April 13,2017 at 3:03 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Cc:"Bettis,Patricia K(DOA)"<patricia.bettis@alaska.gov>,Amanda Dial<adial@glacieroil.com>,"Carlisle,Samantha J (DOA)"<samantha.carlisle@alaska.gov> Subject: RE: RU 3A completion sundry(PTD 216-170) Stephen, Thanks for the clarification.AOGCC will cancel previous sundry 317-133 as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITYNOTICE: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 Guy Schwartz at(907-793-1226)or (Guy.schwartz@alaska.gov). From:Stephen Ratcliff(mailto:sratcliff@glacieroil.com] Sent:Thursday,April 13,2017 2:57 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>;Amanda Dial<adial@glacieroil.com> Subject: Re: RU 3A completion sundry(PTD 216-170) Guy, We are planning to perform an injection with produced water after we perf each interval. We will have higher injection pressures and want to make sure that we are compliant. 1 • • We will cancel the previous completion sundry. Thanks and let me know if you have any further questions. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From: "Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date:Thursday,April 13,2017 at 2:49 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Cc: "Bettis, Patricia K(DOA)" <patricia.bettis@alaska.gov> Subject: RU 3A completion sundry(PTD 216-170) Stephen, What is the reason for the new sundry for RU 3A other than new perf intervals? Can you request by replying to this email that you need to cancel the previous sundry that was submitted March 30th(#317-133)to perforate and run tubing. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICEThis 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 Guy Schwartz at(907-793-1226)or (Guy.schwartz@ialaska.gov). 2 OF Fit, • • w %\��\�yy .,,, THE STATE Alaska Oil and Gas ���."�i�� of Conservation Commission , ____ _ ALASIc;A #ts,4_ -.11 -'111-61-1;* _._ = '' 7. 333 West Seventh Avenue wh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF Q. Main: 907.279.1433 ALAS Fax: 907.2 76.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, Redoubt Unit 3A Permit to Drill Number: 216-170 Sundry Number: 317-107 Dear Mr. Ratcliff: 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, i°9X44 Cathy . Foerster Chair DATED this /O day of March, 2017. REDM3 bI 1.a:,,, L J C+. i17 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 9 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 . 0 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0' Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC ' Exploratory ❑ Development ❑ 216-170 3.Address: Stratigraphic ❑ Service 2. 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 50-733-20504-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes❑ No ❑✓ ! REDOUBT UNIT#3A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-381203(surface),ADL-374002(TD) REDOUBT SHOAL UNDEFINED,UNDEFINED OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): 4'jt}- ; Plugs(MD): Junk(MD): Planned: 16809' Planned: 12900' Planned: 16809' Planned: 12901' None None Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' 150' N/A N/A Conductor -- -- -- -- -- -- Surface 3507' 13 3/8" 3507' 3024' 5020 2260 Intermediate 9332' 9 5/8" 9332' 7416' 6870 4750 Production Planned:5047' 7 5/8" Plan window:14150' Plan window:10943' 6890 4790 Liner Planned:9309' 4-1/2" Planned: 16809' Planned: 12900' 14420 15500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Planned: 15650'-16120' Planned: 11973'-12312' 4-1/2" P-110 Planned:7,500' Packers and SSSV Type: None-to be completed with Completion Sundry Packers and SSSV MD(ft)and TVD(ft) None-to be completed with Completion Sundry 12.Attachments: Proposal Summary U Wellbore schematic [,f 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development❑ Service ❑, 14.Estimated Date for 15.Well Status after proposed work: ASAP Commencing Operations: OIL ❑ WINJ ❑, , WDSPL ❑ Suspended ❑ 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. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer Signature Phone Date -.Q, \k 907-433-3808 3/9/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \`7-\ 07 Plug Integrity ❑ BOP Test 12Mechanical Integrity Test ❑ Location Clearance ❑ Other: '>k P . �biinCM.1S C1 P.M -k6-\'1O -34 NPriwv Ae1ot>,s a TO 20 FAL 2c,$i 2L6 Fete. PP Xe9. £X i4 RE:73713 Lk- r , 'i 3 L4i7 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 121 Subsequent Form Required: 10__21/401 CFmNAL APPROVED BY 14 Approved by: �J' VlZ COMMISSIONER THE COMMISSION Date: 3 -(6 — /7 h Submit Foam'Z Form 10-403 Revi ed 11/2015 a i i valid for 12 months from the date of approval. Attachments in Duplicate VI94)- 0 R� ter M:I6 7, al„ 3Y-- kiS F 3 lid►r1 • • GLACIER RECEIVED March 9th,2017 90 17 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: Redoubt Unit 03A API: 50-733-20504-01-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for RU-03A, PTD: 216-170 requesting to modify the approved program under PTD 216-170,by changing the depth of the liner hanger to cover the 9-5/8" perforations instead of setting a casing patch. If you have any questions, please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy,LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave,Suite 310 Anchorage,AK 99501 1 • • • Quick, Michael J (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Thursday, March 09, 2017 4:56 PM To: Schwartz, Guy L (DOA); Quick, Michael J (DOA) Cc: Conrad Perry;Amanda Dial; Stephen Ratcliff Subject: RU-03A (PTD: 216-170) - Variance request Guy/Mike, Per our discussion, we would like to ask for a variance with regards to the setting depth of our packer on our RU-03A well. A variance for regulation 20 AAC 25.412 (b) is requested for the changes proposed in the Application for Sundry submitted on 3/9/17 for RU-03A(PTD: 216-170)to move the 4-1/2" packer from the originally planned depth of 14030' MD to 7500' MD. The purpose of the depth change is to place the perforations in the 9-5/8" casing behind the 4-1/2" liner, however,the distance of the packer from the perforations exceeds 200 ft as stipulated in the regulation. Appreciate the help and let me know if you have any further questions. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 O- (907)433-3808 C- (907) 433-9738 1 • GLACIER WELL NAME-RU-03A Requirements of 20 MC 25.005(f) Well Summary Current Status: RU-03 is being abandoned in preparation for the RU-03A Sidetrack. Current Perforations MD TVD 7780'- 7800' 6203'- 6219' 7805' - 7818' 6223'- 6233' Scope of Work: • Set whipstock in 7 5/8"casing with top of window at+/- 14150' MD. • Mill window in casing with 6 3/4" BHA. • Drill 6 3/4" hole from KOP 14150' MD - 16809' MD. \JAR.t/h � -ts. R32- • Run 4 1/z" liner and cement. • Complete 3 stage Frac. ' NAC- .At2lti� o Frac Sundry submitted separately. ✓ pPkt, .e2 Xn - c: DEc • Run Completion. o Completion Sundry to follow.✓ • Rig down Eline. General Well Information: Reservoir Pressure/TVD: 5,634 psi @ 16,809' MD/ 12,900'TVD MASP: 4,344 psi ✓ Wellhead Type/Pressure Rating: Vetco Gray- 5M -Wellhead Assembly . BOP Configuration: 13 5/8" 10M BOPE-Annular/VBR/Blind/Kill Line/VBR Well Type: Water Injector Estimated Start Date: ASAP Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907)433-9738 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • GLACIER General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 13. Drilling Procedure Requirements of 20 AAC 25.005(c)(13) Note: This is a continuation from the RU-03 Plug for Redrill Sundry procedure. The plug for redrill and sidetrack operationally is intended to be consecutive,pending AOGCC approval. 1. P&A Sundry Submitted separately. -- l‘io -0-2- a. Verify timing for next BOP test and provide AOGCC with 48 hour notice if necessary. b. Verify 10.2 ppg mud volume and build additional if necessary prior to milling window. c. Verify 6 3/4" Mill/Whipstock/MWD BHA is set with top of window at 14,150' MD. i. Depth of Whipstock is shallower than originally planned to avoid milling a collar and into a coal. 2. Before milling window, perform FIT to 14.0 ppg EMW (10.2 ppg MW) for the 1t1 't✓�perforations in the 9-5/8" casing. jz o' 'TVD Si3f nra rZ a. FIT/LOT Procedure included in Section 5 of PTD. -3`----- 3. Prepare to mill window. !2-2 s w 4. Start milling window,per Service Company Procedure. a. Drill additional rat hole to clear the BHA, motor,and MWD tools. b. Ream window as needed to assure there is little or no drag. c. After reaming: i. Shut off pumps and rotary(if hole conditions allow). ii. Pass through window checking for drag. 5. POH and gauge mills for wear. a. Make additional run if window&mill are out of gauge. 6. Pick up 6-3/4" LWD. a. 6-3/4" SK613M-E1D PDC bit b. 4-3/4" Ultra Extreme Mud Motor- Need to Discuss Motor Bend with Engineer/Supt(Expect 1.5 degree setting) c. Stabilizer d. 4-3/4" Navi-Gamma, Density/Neutron LWD/MWD e. Stabilizer f. NM Drill Collars g. HWDP h. Jars i. HWDP j. 4" and 5" drill pipe so surface i. Detailed BHA and Hydraulics in SLB RU-03A Well Plan 7. RIH to 1000' &perform shallow MWD test. 3 • ! GLACIER 8. Continue RIH to Window. 9. If Mill did not achieve 20 ft of new hole, drill additional new hole required for a total of 20' of new formation and circulate and condition mud. Oh.v) a. Perform LOT. r�.0 PM �"'''' ‘j" b. FIT/LOT Procedure included in Section 5 of PTD. V-0- ! 1,01- 10. Directionally drill 6-3/4" hole to +/- 16,809'MD/ 12,900'TVD,per directional plan. 11.Circulate hole clean with minimum of three bottoms up, or until hole is clean. 12.Short trip to window and CBU. a. Avoid back reaming if possible. 13.RIH to TD and circulate a minimum of three bottoms up, or until hole is clean. 14. POH to window and CBU. 15. Continue POH to surface. 16. Lay down BHA. 17. Rig up to run 4-1/2" Liner. 18. P/U 4-1/2", 15.1#, P-110 GeoConn Liner. a. This is a rotatable connection. i. Max torque of 13,000 ft-lbs ii. Max MU of 11,000 ft-lbs iii. Min MU of 9,000 ft-lbs b. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through top of Hemlock. ii. 1 Solid body spiral centralizer every other joint thereafter. c. Break circulation at Mill Window. d. Note: Swab and surge pressures of tripping are excessive with 4-1/2" liner in 6- 3/4" hole at this depth. e. Planned Liner Hanger depth at 7,500' (+/- 250' above the 9-5/8" perforations). 7 19.PU TIW Liner Hanger and Running tool BHA and RIH on 4" drill pipe to window. a. Establish P/U and S/O weights. 20.Continue to RIH to bottom. 21.Circulate and condition hole. a. Reciprocate liner while circulating. 22. Rig up and test cementers. 23.Cement 4-1/2" liner per cement program. a. Continue reciprocating liner while pumping cement. b. Bump plugs with 3,000 psi - DO NOT over displace. 24.Set Liner/Hanger-Packer, per TIW Procedure. a. Release pressure and check floats and un-sting from liner. 4 • ! GLACIER 25. Reverse out excess cement. 26.POH and L/D Running Tool. 27.Pick up Polish Mill BHA. 28.RIH and Clean out casing,liner top,and latch assembly in Liner Hanger. 29.Circulate hole clean. 30.Test casing and liner lap to 3,500 psi for 30 minutes and chart if past 24 hour CIP. 31.POH and L/D Polish Mill BHA 32.P/U+/- 9300'of 2-7/8" drill pipe and MI Swaco Well Commander. a. Well commander in 4" DP section about 200'above liner top. 33.RIH to bottom and prep to displace OBM to fresh water+ 3% KCL. 34.Change over to completion fluid using appropriate spacers. a. Mix and displace with 8.5 ppg Water and KC1. b. After well has been displaced,filter brine as necessary to less than 20 NTU's. 35.POH and laydown all 2-7 8"and 4" drill pipe. �"' "" / P p � e,6t.. tJluS-c s�a�,..; cxM�� paszvW 36. Rig up wireline and run CBL in 4-1/2"liner. _ c oto . ti t 37.Evaluate Cement Bond Log. a. If squeeze is needed, confirm with CIE office on equipment and procedure. 1110(t-7 38.P/U 4-1/2" 15.1# P-110 Geoconn Frac String. 39. RIH to Liner top and latch per TIW Running Procedure. 40.Space out and land Frac tubing hanger. t-' ¢.� - r� e czytc 5 • RU-0Orrent Abandonment Schematic • 3/9/2017 Updated F f , 30" A-36 200'MD 150# Welded 200'TVD ,A 13 3/8" 68#L-80 3,507'MD ID 12.415" BTC 3,024'TVD ss Perforations-7780'-7818'MD/ _ as 6,203'-6,232'TVD TOL©9,103'MD _ - 9 5/8" 47#L-80 9,332'MD Baker Hanger Assembly �� ID 8.525" BTC 7,416'TVD Whipstock top of window @ 14,150'MD g .'?~1 TOC @14185'MD Cement Retainer @ 14271'MD _1_,... .._,..!.. _ FISH:Top of tubing cut @ 14308'WLM 1 2-7/8"XN-nipple @ 14,751'MD Top Tieback @ 14,717'MD Perforations-14,803'-14,860'MD/ _ _v_ WL Re-Entry Guide @ 14,791'MD 11,410'-11,4 zz i 7 5/8" 29.7#L-80 15,615'MD Baker Hanger Assembly I1„ % ID 6.875" Hydril 521 11,981'TVD k Cement Retainer @ 15,691'MD — ...♦� Lost fish©15,768'-16,048'MD —+✓• `% ✓lir: t k 5 1/2" 17#L-80 16,940'MD ID 4.767" Hydril 521 13,016'TVD RIF WI-Proposed Frac Wellbore Schematic Date: 9-Mar-17 Version: Final GLACIER ' Tubing Hanger-4-1/2"15.10#GeoConn-Top&Btm -.1 30" 150#A-36 260'MD ID-28" Welded 260'TVD -I. ti 4-1/2"15.10 P110 GeoConn Casing t 18 1/2"Hole , 13 3/8" 68#L-80 3,507'MD , ID -12.25" BTC 3,024'TVD TOL @ 7,500'MD .:., 1 1 .ill 4 1/2"X 9 5/8"Liner Hanger Perforations ' 1 ) MD TVD _ Feet l9 6 v !_ (� s ` �v 9 � 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 ,"I. 7 5/8"X 9 5/8"Liner Hanger TOL @ 9,103'MD 12 1/4"Hole ^' 9 5/8" 47#L-80 9,332'MD ID-8.50" BTC 7,416'TVD 1 T 4j y Tti_ '11.1 y. iy,V ice ' C.s ) 1 ((J-t ,_. = 3,5 x,15 } ,a Window 7 5/8" 29.7#L-80 14,150'MD 8 1/2"Hole ID-6.75" Hydril 521 10,943'TVD Q Lam. r'M t+4 c I Z 30 ao ro4("p ,_Iib Perf/Frac Intervals [i'i; MD TVD Feet 15650-15660 11973-11980 10CS 15860-15870 12118-12125 10 0 16110-16120 12305-12312 V,. 10 I R ti 14,301` i V 4 1/2" 15.1#P-110 16,809'MD 63/4"Hole _1 (_ ID-3.832" GeoConn 12,900'TVD Cook Inlet Energy Casing Plan WELL NAME: RU-03A Well Information ENGINEER: Amanda Dial DATE: 26-Oct-16 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Pressure) Shoe Weight(ppg) - 30 200 200 -- -- -- -- -- Conductor pipe 16" 13 3/8" 3,507 3,024 8.3 15.0 9.5 10 -- Previously Set on Original RU-03 Well 12 1/4" 9 5/8" 9,332 9,416 8.3 15.0 9.5 10 -- Previously Set on Original RU-03 Well 8 1/2" 7 5/8" 14,150 10,943 8.3 14.0 9.5 10 -- Whipstock and Window Lower Hemlock&West Forelands- 6 3/4" 4 1/2" 16,809 12,900 8.4 15.0 10 i 10.5 OBM Abnormal Pressure Gradient Casing Plan IENTER YELLOW CELLS MANUALLY Casing Size Connection API rating Wt(lb/ft) Grade Collapse Tension MD(ft) TVD(ft) (in) Type OD(in) Burst(psi) (psi) (kips) 30 150 A36 PE -- -- -- -- 200 200 13 3/8" 68 L80 BTC 10.63 5020 2260 952 3507 3024 9 5/8" 47 L80 BTC-M 10.625 6870 4760 1122 9332 9416 7 5/8" 29.7 L80 Hydril 521 8.5 6890 4790 683 14150 10943 4 1/2" 15.1 P110 U-DQX 5 14420 14350 406 16809 12900 Variables & Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.433 psi MAWP=(0.80 X CASING BURST) or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg SF)X TVD)-GasGRD X TVD)) or (Max Pore Pressure-(GasGRD X TVD)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X TVD SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) . Max Allowable Working Pressure* MAWP=(0.80 X CASING BURST) or Limiting Wellhead Pressure Hole Sizes Casing Size Safety Wellhead MD(ft) TVD(ft) Burst(psi) MAWP(psi) (in) (in) Factor (psi) 16" 13 3/8" 3,507 3,024 5020 0.8 5,000 4016 12 1/4" 9 5/8" 9,332 9,416 6870 0.8 5,000 5496 8 1/2" 7 5/8" 14,150 10,943 6890 0.8 5,000 5512 6 3/4" 4 1/2" 16,809 12,900 14420 0.8 5,000 11536 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg)X TVD)-GasGRD X TVD)) or (Max Pore Pressure-(GasGRD X TVD)) Hole Sizes Casing Size Max EMW Frac Grad at MW Safety Gas Frac Max PP at MD(ft) TVD(ft) Pressure at MASP(psi) (in) (in) (PPg) Shoe Factor Gradient Next TVDShoe 16" 13 3/8" 3,507 3,024 8.3 15.0 0.50 0.10 2135 364 364 12 1/4" 9 5/8" 9,332 9,416 8.3 15.0 0.50 0.10 6648 2,970 2,970 8 1/2" 7 5/8" 14,150 10,943 8.3 14.0 0.50 0.10 7157 3,433 3,433 6 3/4" 4 1/2" 16,809 12,900 8.4 15.0 0.50 0.10 9107 4,345 4,345 Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X TVD Hole Sizes Casing Size Safety Max EMW (in) (in) MD(ft) TVD(ft) Burst(psi) Factor MW (Pore MASCP(psi) Pressure) 16" 13 3/8" 3,507 3,024 5020 0.8 10 8.3 3749 12 1/4" 9 5/8" 9,332 9,416 6870 0.8 10 8.3 4664 8 1/2" 7 5/8" 14,150 10,943 6890 0.8 10 8.3 4545 6 3/4" 4 1/2" 16,809 12,900 14420 0.8 10.5 8.4 10127 Safety Factors Hole Sizes Casing Size Collapse Tension Liner Length SAFETY FACTORS (in) (in) MD(ft) TVD(ft) Burst(psi) (psi) (kips) Wt(Ib/ft) (ft) Burst Collapse Tension 16" 13 3/8" 3507 3024 5020 2260 952 68 - 13.8 2.3 4.0 12 1/4" 9 5/8" 9332 9416 6870 4760 1122 47 - 2.3 1.5 2.6 8 1/2" 7 5/8" 14150 10943 6890 4790 683 29.7 5047 2.0 1.3 4.6 6 3/4" 4 1/2" 16809 12900 14420 14350 406 15.1 9309 3.3 3.3 2.9 SF Burst=Burst Value/MASP ISF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) I SF Tension=Tension Value/(Length X lb/ft) or. fir. " „ A� STATE OF ALASKA A SKA OIL AND GAS CONSERVATION COMMSION ', , '` x!ni7 APPLICATION FOR SUNDRY APPROVALS r -- , 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 2 Other Stimulate ❑ Pull Tubing ❑ 'hange Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ • er: ❑ 2.Operator Name: 4.Current Well Class: 5.Perm' to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development ❑ 216-170 ' 3.Address: Stratigraphic ❑ Service 6. •I Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 \ 50-733-20504-01-00 ' 7.If perforating: 11145 8. Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Ca-71-/-14,20 AAC 25.k 5 ` r Will planned perforations require a spacing exception? YesE No ❑ % REDOUBT UNIT#3A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-381203(surface),ADL-374002(TD) REDOU- 140•L UNDEFINED,UNDEFINED OIL • • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP f• : Plugs(MD): Junk(MD): Planned: 16809' Planned: 12900' Planned:16809' Planned: 12901' 12100 p ' None None Casing Length Size MD ' TV,, Burst Collapse Structural 150' 30" 150' .0' N/A N/A Conductor -- -- -- -- -- -- Nlik Surface 3507' 13 3/8" 3507' t 1n`3024' 5020 2260 Intermediate 9332' 9 5/8" 9332' \ ' & 7416' 6870 4750 Production Planned:5259' 7 5/8" Plan window:14 . -an window: 11096' 6890 4790 Liner Planned:2779' 4-1/2" Planned: <:,9' Planned: 12900' 14420 15500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Planned: 15650'-16120' Planned: 11973'-12312' 4- ." P-110 Planned: 14,030' Packers and SSSV Type: None-to be completed with Completion Su i4 P.% s•nd SSV MD(ft)and TVD(ft) None-to be completed with Completion Sundry 12.Attachments: Proposal Summary ❑✓ Wellbore schematic (►j .- ell Class after proposed work: Detailed Operations Program 2 BOP Sketch ❑� •.ratory ❑ Stratigraphic❑ Development❑ Service ❑., 14.Estimated Date for ^� 15.Well Status after proposed work: 3/1/2017 Commencing Operations: OIL 21 WINJ 2 • WDSPL ❑ Suspended El16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑'` Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedur:approved herein will not be deviated from without prior written approval Contact Stephen Ratcliff • Email sratcliff@glacieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer SignaturePho r e Date _�C ` 907-433-3808 2 r g I ii COMMISSION USE ONLY Conditions of approval: Notify Commission so that a epresentative may witness Sundry Number: 1/- 07 0 Plug Integrity ❑ err _f BOP Test I Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 1 /�,_ LID tf RBDMS LL JUN 2 7 2017 ll.•�� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Suorrui FUlfll anu Form 10-4 33 Revi ed 11/2015 # a valid for 12 months from the date of approval. Attachments in Duplicate • • GLACIER RECEIVED February 9th, 2017 FEB 09 ?017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application for Hydraulic Fracturing Cook Inlet Energy, LLC: RU-03A Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Request to perform a hydraulic fracture for RU-03A, located on ADL 381203 and 374002 (TD), in the Redoubt Unit. Please find attached for review of the Commission the 10-403 Form,Hydraulic Frac Procedures, Post Frac Clean Up Program, Fracture Parameters, Geological Information, and Proposed Well Schematics, as required by 20 AAC 25.005, 20 AAC 25.280, and 20 AAC 25.283. Additional information includes MASP Calculations, Frac Layout, and Surface Equipment Diagrams. Rig 35, on the Osprey Platform,will be used to complete this work,commencing approximately March 1, 2017. If you have any questions, please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy (a Glacier Oil &Gas owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Stephen.Ratcliff@CookInlet.net 0: 907.433.3808 C: 907.433.9738 F: 907.334.6735 1 • GLACIER Well To Hydraulically Fracture - RU-03A Requirements of 20 AAC 25.283(a) Well Summary Current Status: RU-03 Well is currently shut-in awaiting the start of abandonment work in preparation for the sidetrack (RU-03A). Scope of Work: • Complete abandonment work approved under Sundry 316-612. • Complete 2,446' sidetrack and run 41/2" 15.10# P-110 Liner (PTD: 216-170) • Cement 4 1/2" liner in place with TOC at liner top, +/- 14,030' MD. • Run 41/2" 15.10# P110 Frac string and tie in to Liner Hanger with anchor latch/PBR. • Mobilize and rig up for 3 stage hydraulic fracturing operation. • Rig up and Test all surface equipment and frac string to 110% of Max Surface Treating '411V. 16 -4 Pressure. • Perf first stage. • Complete Data Frac to confirm breakdown. • Pump +/- 20,000 # frac in first stage. • Continue Hydraulic Fracturing Operation for remaining stages. • Demobilize pump skids and frac equipment. • Mobilize Coil Tubing Unit and clean out equipment. • Clean out well with CTU. • Run Completion Equipment, per Program - Completion Sundry to o ow. • Turn well over to injection. General Well Information: Reservoir Pressure MD/TVD: 5,634 psi @ 16,809' MD / 12,900'TVD MASTP: 12,100 psi (modelled: 8,125 psi) Wellhead Type/Pressure Rating: Vetco Grey- 5M -Wellhead Assembly Vecto Grey- 15M - 4-1/16" Frac Tree BOP Configuration: Coil BOP during CTU operations. Well Type: Injector Estimated Start Date: March 1, 2017 2 • • GLACIER Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Stephen Ratcliff (907) 433-9738 Stephen.Ratcliff@CookInlet.net Production Manager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 1. Notice of Operations Requirements of 20 AAC 25.283(a)(1) An affidavit stating that all owners, landowners, surface owners, and operators within a one- half mile radius of the current/proposed wellbore trajectory have been provided with a notice of operations. (A) Upon request, a complete copy of the application is available. (B) Operator Contact Information is on file with the AOGCC. 2. Location Summary Requirements of 20 AAC 25.283(a)(2) (A) Well Location • General Location Kenai Peninsula Borough,Alaska • Osprey Platform Center Leg 3 - Slot#15 • Sea Bottom Elevation 45' to Mudline • RKB 89' above MSL X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec/T/R 1 Surface Location 200623.926' 2449936.607' 1962'FSL 271'FEL 14/7N/14W Bottom Hole Location 207093.64' 2440304.46' 848'FNL 762'FWL 30/7N/ 13W (B) Water Wells located within a one-half mile radius of the well's surface location: X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec/T/R Not Applicable 3 • • GLACIER (C) Offset Wells with in a one-half mile radius of the wellbore fracturing interval: Surface Surface Wellbore Frac Wellbore Frac Sec/T/R X-Coordinate Y-Coordinate X-Coordinate Y-Coordinate RU-03 200623.926' 2449936.607' 203025' 2446311' 14/7N/13W RU-05A 200623.424' 2449931.683' 206153' 2444321.8' 14/7N/13W RU-05B 200623.424' 2449931.683' 206144.8' 2444325.2' 14/7N/13W See Attachment 1: Plat/As-Staked Design See Attachment 2: Planned Directional Surveys &Spider Plot Final Directional Survey will be provided to the AOGCC upon completion of the directional work. See Attachment 3: Equipment Layout 3. Identification of Freshwater Aquifers Requirements of 20 AAC 25.283(a)(3) Identification of any freshwater aquifer,within a one-half mile radius of the wellbore trajectory: Geological Name of Freshwater Aquifer: Not Applicable Measured Depth of Freshwater Aquifer: Not Applicable True Vertical Depth of Freshwater Aquifer: Not Applicable There are no freshwater aquifers within a one-half mile radius of the proposed wellbore trajectory. 4. Water Sampling Baseline Plan Requirements of 20 AAC 25.283(a)(4) Water sampling and collection of baseline water data is needed before fracturing for all water wells within a one-half mile radius of the proposed wellbore. Water Sampling Plan - Not Applicable 5. Casing and Cementing Information Requirements of 20 AAC 25.283(a)(5) See Attachment 4: Casing Design Program See Attachment 5: Cement Program 4 • • GLACIER 6. Casing and Cementing Assessment Requirements of 20 AAC 25.283(a)(6) An assessment of each casing and cementing operation has been performed with supporting information, including cement evaluation logs and the following has been determined: (A) Casing is cemented: (i) Below the base of the lowest freshwater aquifer (ii) In accordance with 20 AAC 25.030 (B) Hydrocarbon zones penetrated by the wellbore are isolated ,tA Cement Bond Log will be submitted to the state by the GLA Engineer upon running the log. Cement Bond Logs are on file with the AOGCC for RU-03, RU-05A & RU-05B and all logs have been evaluated and determined that there is no expectation of no cement or poor cement in the zones that are within the half mail radius. See CBL's on file if further analysis is needed. 7. Pressure Test Information Requirements of 20 AAC 25.283(a)(7) The wellbore and frac string will be pressure tested as follows: Surface Equipment and Pumps: 12,100 psi ✓ Frac String: 12,100 psi Frac Zone Wellbore: 12,100 psi Annular Pressure Held: 3,000 psi Inner Annulus Pop-Off: 3,500 psi 8. Pressure Ratings and Schematics Requirements of 20 AAC 25.283(a)(8) Wellbore: 14,400 psi Frac String: 14,400 psi Wellhead: 5,000 psi (Isolated) Frac Tree: 15,000 psi Surface Equipment: 15,000 psi See Attachment 7: Frac String Schematic See Attachment 8: Proposed Wellbore Completion Schematic See Attachment 9: Wellhead Schematic See Attachment 10: BOPE Schematic See Attachment 11: Frac Tree Schematic 9. Fracturing and Confining Zone Data 5 • • GLACIER Requirements of 20 AAC 25.283(a)(9) (A) Lithological Description of Zone: Conglomeratic Sandstone (B) Geological Name of Zone: Hemlock Total Number of Stages 3 (C) Depth of Zone: Zone 1 Zone 1 - Measured Depth 16,110' - 16,120' Zone 1 -True Vertical Depth ''12,304.9' - 12,312.7' Zone 2 Zone 2 - Measured Depth 15,860' - 15,870' Zone 2 -True Vertical Depth 12,118' - 12,125.2' Zone 3 Zone 3 - Measured Depth 15,650' - 15,660' Zone 3 - True Vertical Depth .. 11,973.5' - 11,980.2' (D) Thickness of Zone: Zone 1 Zone 1 - Measured Depth 10' Zone 1 - True Vertical Depth 7.8' Zone 2 Zone 2 - Measured Depth 10' Zone 2 -True Vertical Depth 7.2' Zone 3 Zone 3 - Measured Depth 10' Zone 3 -True Vertical Depth 6.7' (E) Estimated Fracture Pressure 9,700 psi 10. Offset Well Report Requirements of 20 AAC 25.283(a)(10) Within a one-half mile radius of the wellbore trajectory, a report on the mechanical condition of each off set well that will transect the confining zone has been evaluated. The offset wells within a one-half mile radius will not interfere with containment of the hydraulic fracturing fluid of the proposed wellbore trajectory. See section 2 (C) above for location and orientation of offset wells. The offset wells, RU-03, RU-05A, and RU-05B will not interfere or be interfered with containment of the hydraulic frac fluid. It has been analyzed and determined that there will not be communication between the frac interval on the RU-03A wellbore and the offset wells. 11. Geological Data Report Requirements of 20 AAC 25.283(a)(11) Within a one-half mile radius of the wellbore trajectory, a review and analysis of the location and orientation of all known and suspected geological faults and fractures,that will transect the 6 • • GLACIER confining zone, has been evaluated. The offset faults within a one-half mile radius will not interfere with containment of the hydraulic fracturing fluid of the proposed wellbore trajectory. 12. Drilling Hazards Requirements of 20 AAC 25.??? There were no losses encountered during drilling of the Hemlock in past wells and none expected for RU-03A. 13. Proposed Hydraulic Fracturing Program Requirements of 20 AAC 25.283(a)(12) C6r0 67,3L s j (A) Estimated Total Volumes Planned 29,000 Gallons per Stage (B) Base Fluid and Additives Name YF125F1exD Purpose Gelling Agent, Crosslinker, Buffer, Stabilizer,and Gel Breaker Concentration Frac Fluid: YF125F1exD 19,000 Gallons 25.0 lb/mgal Pad&Frac Fluid 20/40 CarboBond Lite 29,700 lbs per stage Flush Fluid: WF125 9,500 Gallons 25.0 lb/mgal Flush Rate 20 BPM Max (C) Max Concentration of Chemical Ingredient 8% (D) Estimated Weight/Volume of Proppant 29,700 lbs / 8767 gallons (E) Max Anticipated Treating Pressure (8072 psi (F) Proposed Fracture Total Frac Height 25 ft Length- 1 Wing 215 ft Average Frac Width 0.07 inches Method of Determination SLB - Frac Cade Pre-Frac-This is a continuation of the drilling operation of RU-03A Sidetrack y "'•-•1) Confirm the following has been completed prior to commencing operations: a) Confirm AOGCC has approved Hydraulic Frac Sundry prior to start of operations. b) Confirm that casing and liner lap has passed a 3,500 psi pressure test. c) Confirm 41/2"frac string is RIH and landed. 2) Hold pre-job safety meeting for hydraulic fracture operations. 3) Plan to N/U for Frac Operations as follows: i) 4-1/16" 15K Gate Valve#1 - Manual (Bottom of Frac Tree) ii) 4-1/16" 15K Gate Valve#2 - Hydraulic Actuated iii) 4-1/16" Frac Tee&(1)Wing Valve with 3" 1502 Unions on side iv) 4-1/16" 15K Gate Valve#2 - Manual 7 • • GLACIER v) Goat Head- 11K Manual Valve with 1502 Connections vi) 4-1/16" 15K Gate Valve#2 -Manual with 3" 1502 Union on top 4) Hold Pre Job Safety Meeting. a) Review all potential hazards with trapped pressure and risk with high pressure testing. b) Make certain that all personnel and crew members understand the hazards and where to be located. c) Confirm that all crew members are secured in a safe place while pressure testing. 5) Pull BPV. 6) Rig up necessary surface equipment and lines. 7) Rig Up Schlumberger Equipment for Hydraulic Fracture. 8) Rig up to Frac Tree and prepare for pressure test of frac string. 9) Pressure test all surface pumping equipment and lines to 12,100 psi for 10 minutes. a) Do not Pressure test frac string and liner during surface pressure test. 10)Rig Up pumping equipment for holding annular pressure while testing and performing frac. a) Note-We will hold a constant 3,000 psi on annulus. b) Set Annular Safety Pop-Off Valves to 3,500 psi. c) Take Bleed Off Line to diffuser tank or Trip Tank. 11)Ensure well is open. 12)Establish minimal rate to load hole if hole is not full. 13)Pressure Test Frac String to 12,100 psi for 10 minutes and chart. I'I.cU_ '- a) Note- Internal Yield on 4.5", 15.1#,P-110 HC is 14,400 psi. b) Note-After surface pressure test,plan to set Nitrogen Pop-Off Valves at 11,000 psi. c) Plan to hold 3,000 psi on the annulus during pressure test and frac. 14)Bleed off pressure in frac string. 15)Bleed off annulus pressure. 16)R/D Frac lines and prep for E-line. 17)Rig up wireline equipment and pressure test. a) Frac will be a Plug and Perf System. b) Will plan to perforate each zone individually before hydraulically fracturing each stage. 18)Prepare for Frac Operations a) Verify that the pump safety kick outs are set at 11,000 psi before moving into frac operations. Procedure Data-Frac-Zone 1 19)Hold&document pre job safety meeting. 20)Review entire rig up procedure,with applicable personnel, and ensure everyone fully understands work objectives and appropriate safety practices. 21)Ensure well is open. 22)Pick up 10'wireline perf guns. 23)RIH with perf guns to Zone 1 a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 1 Lower Hemlock 16110'MD 16120'MD 12304.9'TVD 12312.7'TVD 24)Correlate guns on depth. 25)Fire guns,per service company procedure. 26)POH with wireline and L/D perf guns. 27)N/D lubricator and wireline. 28)Hold&document pre job safety meeting. 8 • • GLACIER 29)Review entire rig up procedure,with applicable personnel, and ensure everyone fully understands work objectives and appropriate safety practices. 30)R/U Frac Lines and Pressure Test,per SLB Procedure. 31)Establish minimal rate to load hole if hole is not full. a) Note-Max Pump Rate of 20 BPM. 32)Consult with GLA Engineer and follow most recent Stimulation Procedure. 33)Pressure up on Annulus to 3,000 psi and hold. 34)Inject at matrix rate to ensure perfs are open,if able. 35)Wait for Pressure to stabilize. 36)Step up rate while watching for breakdown pressure until frac rate is established. 37)Hold steady rate until pressure stabilizes for at least 1/z to 1 min. 38)Hard shutdown,monitor leak-off until well is dead or pressure stops declining and stabilizes. a) Pressure data is critical for Pressure Transient Analysis. b) Confirm with GLA Engineer before bleeding off pressure. 39)Displace with 200 bbls of Linear Gel. 40)Shut Down and Monitor Pressure. 41)Send data to engineer for analysis. a) If a breakdown was present then proceed with actual frac after conferring with GLA Engineering. Procedure-Lower Hemlock Frac-Zone 1 42)Hold&document pre job safety meeting 43)Confirm that all necessary materials are on location and accounted for. 44)Ensure well is open and 3,000 psi is held on the backside. 45)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note-Prior to pumping,confirm with GLA management on latest pump schedule. b) Note-Max Pump Rate of 20 BPM. 46)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 pps. c) Once Flush volume has been pumped,close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken, proppant may be carried into the wellbore. 47)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. i) Note-This will be revised after 1st Data Frac. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then move to next stage. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 48)Bleed off annulus and tubing pressure. 49)Prepare to move to Zone 2 Frac. Procedure-Middle Hemlock Frac-Zone 2 50)Hold&document pre job safety meeting for Stage 2 Frac. 51)Plan for Data Frac prior to Pumping stage 2 Frac (See data Frac Procedure Above). 52)R/U wireline,lubricator,and pressure test. 53)Ensure well is open. 54)If no prior screen out then dummy run may not be needed. 9 • • GLACIER 55)P/U 15K Frac Plug and running tool on E-line. 56)RIH with Frac Plug to 5'above last perforation interval. 57)Set Frac Plug,per Schlumberger Procedure. 58)POH and L/D Running Tool. 59)Pick up 10'wireline perf guns. 60)RIH with perf guns to Zone 2. a) Confirm with GLA Engineer on actual interval. b) Expected Perf Interval: 2 Middle Hemlock 15860'MD 15870'MD 12118'TVD 12125.2'TVD 61)Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 62)Fire guns,per service company procedure. 63)POH with wireline and L/D perf guns. 64)R/D lubricator,wireline,and prep for pumping frac. 65)R/U Frac Lines and Pressure Test,per SLB Procedure. 66)Consult with GLA representative and follow most recent GLA Stimulation Procedure. 67)Pressure up on Annulus to 3,000 psi and hold. 68)Inject at matrix rate to ensure perfs are open,if able. 69)Wait for Pressure to stabilize. 70)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note-Prior to pumping,confirm with GLA management on latest pump schedule. b) Note-Max Pump Rate of 20 BPM. 71)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped, close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken,proppant maybe carried into the wellbore. 72)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then move to next stage. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 73)Bleed off annulus and tubing pressure. 74)Prepare to move to Zone 3 for Stage 3 Frac. Procedure-Upper Hemlock Frac-Zone 3 75)Hold&document pre job safety meeting for Stage 3 Frac. 76)Plan for Data Frac prior to Pumping stage 3 Frac (See data Frac Procedure Above). 77)R/U wireline,lubricator,and pressure test. 78)Ensure well is open. 79)If no prior screen out then dummy run may not be needed. 80)P/U 15K Frac Plug and running tool on E-line. 81)RIH with Frac Plug to 5'above last perforation interval. 82)Set Frac Plug,per Schlumberger Procedure. 83)POH and L/D Running Tool. 84)Pick up 10'wireline perf guns. a) Confirm with GLA Engineer on actual interval. 10 • 4110 GLACIER b) Expected Perf Interval: 3 Upper Hemlock 15650'MD 15660'MD 11973.5'TVD 11980.2'TVD 85)Correlate guns on depth. a) Confirm with GLA Engineer prior to setting guns. 86)Fire guns,per service company procedure. 87)POH with wireline and L/D perf guns. 88)R/D lubricator,wireline,and prepare for pumping frac. 89)R/U Frac Lines and Pressure Test,per SLB Procedure. 90)Consult with GLA representative and follow most recent GLA Stimulation Procedure. 91)Pressure up on Annulus to 3,000 psi and hold. 92)Inject at matrix rate to ensure perfs are open,if able. 93)Wait for Pressure to stabilize. 94)Follow Schlumberger Pump Schedule and Procedure for pumping frac. a) Note-Prior to pumping,confirm with GLA management on latest pump schedule. 95)Pump all chemicals. a) Bring each frac pump up to rate with cross-linked fluid. b) Flush will be called when proppant concentration drops by 2.0 ppa. c) Once Flush volume has been pumped,close in the well and allow cross-linked fluid to break. d) If pressure is released before the cross-linked gel has broken,proppant may be carried into the wellbore. 96)Complete pump schedule and shut down. a) If a pre-mature screen out occurs,pumps will shut down at 11,000 psi. b) Nitrogen Safety Pop Off Valves are set to relieve pressure at 11,000 psi. c) If no screen out then prep for milling and cleanout operations. i) If a screen out occurs,confer with GLA Engineering on clean out procedure with Coil Tubing. 97)Bleed off annulus and tubing pressure. 98)Prep for coil cleanout and milling operations. Procedure-Post Frac Clean Out 99)Hold&document Pre-Job Safety Meeting. a) Confirm that BOPE Test is still valid or Schedul BOPE Test with AOGCC. 100) Review entire rig down procedure to ensure everyone fully understands work objectives and appropriate safety practices. 101) Caution for potential hazards and trapped pressures. 102) Shut in well at frac tree by closing 4-1/16" 15K Actuated Gate Valve. 103) Rig Down Schlumberger Equipment and clear the rig floor. 104) R/D Wireline Equipment and Lubricator. a) Frac tree will remain in place 105) N/U Coil Tubing BOPE to 4-1/16" 15K Flange. a) Notify AOGCC 48 hours ahead of upcoming CTU BOPE Test. 106) Test CT BOPE,per Service Company Procedure. a) Open manual valve on frac tree after CT BOPE is installed and tested. 107) Rig up CTU and prepare to RIH to Mill Plugs and Clean Out Well. a) Make sure equipment is rigged up for reverse circulating. 108) Nitrogen lift will be utilized directly after Coil Cleanout. 109) Pick up SLB Clean out BHA, Motor,and Mill. 110) RIH on coil tubing to liner top at+/- 14,030'. a) RIH and watch running speeds in anticipation for fill. 11 < io . GLACIER 111) Continue RIH and report fill depth on daily report if encountered. 112) Clean out each stage from heel to toe of well. a) Report any issues or fill on report. b) Document on report if losses are encountered. 113) Circulate well clean with kill weight fluid and prepare to POH. 114) Confirm that well is dead. 115) POH and L/D clean out BHA. 116) Confirm Pressure on tubing and annulus is zero. 117) Install BPV. 118) Shut in 4-1/16" 15K Gate Valve below frac tee. 119) N/D Coil Tubing BOPE. 120) N/D Frac Tree. 121) Turn well over to production for injection. 14. Proposed Post Frac Clean-Up Program Requirements of 20 AAC 25.283(a)(13) Schlumberger Coil Tubing will be on location with a 16,000' - 1.75" CT string for any clean out needs. Uses/Unused hydraulic fracturing fluid will be disposed down the RU-D1 - Class 1 Disposal Well. Procedure-Screen Out(Per Schlumberger) 1) R/U 1.75" Coil Tubing, PT BOPE to 4,500 psi HI 250 Low for 5 min. 2) M/U jet nozzle for washing down operations.Stab on well, PT lubricator and flowlines to 250/4,500 psi. 3) RIH at 20 ft/min near the jewelry and tubing restriction. Increase the running speed to 60 ft/min if the tubing is clear and perform pull test for every 1000 ft. 4) While RIH,pump KCL down tubing and take returns to tank. Monitor returns for sand and tank levels in returns tank 5) Verify with Company Rep potential sand depth in the hole.Start RIH to about 500 ft or pre- determined sand depth, RIH slowly to perform dry tag top of sand.A dry tag as a first run is advised to verify where fill will be encountered. 6) Once top of fill determined,pull CT 20 ft,and line up to performed conventional fill cleanout circulation at maximum rate. a) During Operation conduct frequent WT checks and increase frequency if losses occur. 7) Wash down to desired TD depth. 8) Once reached TD,circulate 2 annulus volumes. Monitor return tank levels and return volume. Discuss returns with the Company Rep. 9) POH coil 500 ft from TD. Stop circulating.Wait 30 minutes. RIH with coil pumping and tag bottom.If tag is above desired TD depth (review results with Company rep),then repeat steps 6-8 until fill remains below this depth. 10) POH with coil.Unstab coil from well. 11) Blowdown the string with N2. RD Coil. 12) Turn well over to Operations. 12 • • GLACIER 15. Hydraulic Fracturing Requirements of 20 AAC 25.283(b) Hydraulic fracturing done through the production or intermediate casing will have a pre casing test to 110 percent of maximum anticipated pressure differential. If the casing fails the pressure test, casing will be repaired prior to starting the frac or a frac string will be utilized. Requirements of 20 AAC 25.283(c) Hydraulic fracturing done through a fracturing string must be: (1) Stung in to a liner or run on a packer set at a measured depth of not less than 100 feet below the cement top of the production casing or intermediate casing (2) Tested to 110 percent of maximum anticipated pressure differential CIE will perform the hydraulic fracture through a frac string. Requirements of 20 AAC 25.283(d) A pressure relief valve will be installed on the treating line between the pump and the wellhead to limit line pressure to the test pressure determined under(a)(12)(E) of this section. The well will be equipped with a remotely controlled shut-in device. Inner annulus pressure relief valve will be set to pop-off at 3,500 psi. Surface lines are protected with pop-off valves set at 13,500 psi. Shut down surface pressure from the pumps is set at 13,100 psi. Requirements of 20 MC 25.283(e) The placement of all hydraulic fracturing fluids will be contained to the approved formations during the hydraulic fracturing operations. Requirements of 20 AAC 25.283(f) Surface casing pressures shall be monitored with a gauge and pressure relief device while frac operations are in progress. (and) The annular space between the fracturing string and the intermediate or production casing will be continually monitored. The pressure in the annulus will not exceed the pressure rating of the lowest rated component that would be exposed to pressure if the frac string failed. Requirements of 20 AAC 25.283(g) 13 GLACIER During fracturing operations, all annulus pressures will be continuously monitored and recorded. IF at any time during hydraulic fracturing operations,annular pressure increases by more than 500 psig above anticipated increases, CIE shall perform the following: (1) Notify the commission as soon as possible,but not later than 24 hours after the incident (2) Implement corrective action and/or increased surveillance (3) Submit a Report of Sundry Well Operations (Form 10-404) not later than 15 days after the incident Requirements of 20 AAC 25.283(h) A Report of Sundry Well Operations (Form 10-404) will be completed and submitted to the commission no later than 30 days after completion of the hydraulic fracturing operations. Attachments Attachment 1: Plat/As-Staked Design Attachment 2: Directional Spider Plot Attachment 3: Equipment Layout Attachment 4: Casing Design Program Attachment 5: Cement Program Attachment 6: Cement Bond Log-Will be submitted when available. Attachment 7: Frac String Schematic Attachment 8: Proposed Wellbore Completion Schematic Attachment 9: Wellhead Schematic Attachment 10: BOPE Schematic Attachment 11: Frac Tree Schematic Attachment 12: FracCade Stim Proposal Attachment 13: Trajectory and Plots Attachment 14: Affidavit Providing Notice of Operations Attachment 15: Geologic Frac Summary TITLE NAME SIGNATURE DATE ' APPROVED Engineer Originator Engineer Review Superintendent Drilling Manager 14 MILLER RIG - 35 - Schema • • .,. A ILI! inviaits . i . 1111 4 00034 Pa \( .. '4 i - SIC gt,.SUM ,d1A 111W ,..' / r'4. IA V NM VW iy4 elpr.:( t -141 it X *n ristsaii,, __ •i,„): ..., H ,• 4 V•4 tc 74 't . . 'OrAilie,' ,' I ,1, i I WI i f ilirlak ,,' pr .c. yi irtil 445 i I. • ..‘. 1 .• 1 " - ifolt..0* - i 1-r, .- • , , . ., . , • • . 1 ! = ,..,,,C.** ,..., t. . i. f , _ 7 - . • .. 1 r ''. •:!: r li. lor Ntipr 'it k ...4,risti4.t,, vit. 7 - • -- - ...- - ---• . .„,,,: iV . '....... L-- ------ , :--** --- - --- , ,-• . • ..1 ., , fk) rrttia-T ,,,...., . • P)RPLUNG RIG AR.RI1C.31 MI NI FAST SIDE . . • r. ittyl; mar9MING! 01-14Y fiZ . t,...-----.-•, _.. ........ ... s • SECTION 14 T7N R1 SM A 0 300 450 600 O RE P LAT F•R M GRID SCALE 1 inch =300 ft. See Deta' +• ' 322' EEL - y 269' FEL 7 WELL SLOT #8 WELL SLOT • #22 #12 + • WELL SLOT PT.NO.21 WELL RU-7 s * #9 ,C CENTERLEG3 WELL SLOT /- ` LAT:60°41'43.698"N #10 VLON: 151°40'14.573"W #11 WELL SLOT V N:2449936.607' WELL SLOTes\ E:200623.926' OSPREY PLATFORM \ ASP ZONE 4 NAD 27 ELEV SEA BOTTOM:-45'MLLW DETAIL 1"=20' #17 WELL RU D-1 PT.NO.6 #18 CENTER LEG 2 O WELL RU-2 LAT:60°41'44.155"N #19 LON: 151°40'13.520"W0 WELL RU-1 N:2449981.637' G 41110 Y E:200677.509' s #14 ASP ZONE 4 NAD 27N enWELL RU-4 ELEV SEA BOTTOM:-45'MLLWLL° #15 �- WELL RU-3 - °' #16 WELL RU-5 See Tabular Sheet for Well Slot Coordinates CD 1.BASIS OF HORIZONTAL AND VERTICAL � 1 1' CONTROL WAS DETERMINED BY AN OPUS ! OF qCi _I SOLUTION FROM CORS BASE STATIONS �`• �s ,t,, C "AC23 PID DM748"&"AC51 PID DD1812"& • "KEN5 PID DJ3029"ALASKA STATE PLANE * (Jill A" % *�e U NAD 83 ZONE 4 EPOCH 2010 HORIZONTAL .10 4 / CD DATUM AND NAVD88 VERTICAL DATUM A nn UTILIZING GEOID12A. / 0 � `. 2)SECTION LNE OFFSETS DETERMINED /, M.SCOTT McLANE FROM PROTRACTED SECTION CORNER VALUES. ,I, "•.$ep28 201¢••.`" 3)MLLW ELEVATIONS WERE DERIVED i ,T , Ir FROM NOAA NAUTICAL CHARTS. �•1 ` 11\\"``` NOTES Section Line I k OSPREY PLATFORM COOK INLET, ALASKA ENGINEERING-TESTING WELL LOCATIONS NAD27 SURVEYING-MAPPING MCL P.O.BOX 468 CLIENT: COOK INLET ENERGY, LLC VOICE:OL (907NA, 28. -421899669 601 W. 5TH AVENUE SUITE 310 (907)283-4218 FAX:(907)283-3265 _ Cook Inlet Energy_ ANCHORAGE,AK 99501 WWW.MCLANECG.COM Consulting Inc PROJECT NO. DRAWN BY: DATE: LOCATION: 133075 PROTRACTED SECTION 14 msm Sept 15,2015 TOWNSHIP 7 NORTH, RANGE 14 WEST SEWARD MERIDIAN,ALASKA 0 • cw c c in 2 H F- c 0OY 0 ,� on 40 oYvpi uaym v E CR. it • °' sgI000'8L Ln Ln N Ln >-- cc (,9'8 x ,Zi)OHS 1-4 y a to 0 v T �La o 1,r) xx = °O _c CIO 0 O cl u 0 p O (gy(p� .-� oci - -� ' `-a M _-0 �c cu x O rV a Qi 'O c OZ x „Z,8 xt o o a °C M o '�` X o o ., A08b-08£ � � o `� "' a110600 o � Sg1000'Zi F.. Q. Qj O ,--i N 6 1`d0'paA 0 I L. •G O 7 cs, OO r- d f O. x G O. 03 i c� Cr‘3v y C a c c, '-- V W k s a-@ v ,n $ dog � � g 4 30) O pi ;,� x8 QQ u v▪ viao d - co O� a2 = •1 Q� O N` Q► m 5 6G° t „ m 8 u \ ` O co 8 '6 ca i cc 8x,91 oo qel Dead /q el Pn W > Sq!000'ot 8# )13Id ,osx,Oti a Ci xo9 1001!!off OT#Phi ! 0 b E IIeM 8'U cu cc I- " v m v 8' W i 0 N D O > ion !V N x L v J i N Q i 0 0 OI- A > O a Q N U u 0 Q x - U i. U 0 LL pOp N C� Ll i-- M,—.1d = rn J= ao O E tr _ c' v cc N N C _ y a 2 ti '° +' .Q C N _0 .>, m C O 0 VI IlnJ uaLl mt Tr C `° Sg1000'8L Ln Ln N N (,9'8 X,ZT)OI!S ,--i ,—i f • 1 I I I I 1 i Sg1000'O ' I ,ZT x ,OZ) Japual8 GOd 1 1 1 1 i 1 1 N IEI 1 1 1 co .n I I 1 in ' �i I 1 1=1 v ^ OO 1m1 I �1 £ S 111 �I Q X O i� I �1 u ZO �1 Im1 Imp 04 Iii I f---4--1 2 IN1 I I —1 1 I I sql 000'99 1 ° i, 1 (,8 x ,0£) dwmd o n I I 1 a I i 1 I 1 11 I R I 1 1 SgI000'99 (,8 X ,0E) dwihd 1 I I I L 4-+ 3 0 c 591OOZ'£LE (,Z6.8 x ,SZ'LZ) dwnd v , or) cu '= a, cn v, n IIeM 2!H Cook Inlet Energy Casing Plan WELL NAME: RU-03A Well Information ENGINEER: Amanda Dial DATE: 20-Dec-16 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Pressure) Shoe Weight(ppg) 30 200 200 -- -- -- -- -- Conductor pipe 18.5" 13 3/8" 3,507 3,024 8.3 15.0 9.5 10 -- Previously Set on Original RU-03 Well 12 1/4" 9 5/8" 9,332 9,416 8.3 15.0 9.5 10 -- Previously Set on Original RU-03 Well 8 1/2" 7 5/8" 14,362 11,096 8.3 14.0 9.5 10 -- Whipstock and Window - 6 3/4" 4 1/2" 16,809 12,900 8.4 15.0 10 10.5 OBM Lower Hemlock&West Forelands Abnormal Pressure Gradient Casing Plan 'ENTER YELLOW CELLS MANUALLY Casing Size Connection API rating Wt(lb/ft) Grade Collapse Tension MD(ft) TVD(ft) (in) Type OD(in) Burst(psi) (psi) (kips) 30 150 A36 PE -- -- -- -- 200 200 13 3/8" 68 L80 BTC 10.63 5020 2260 952 3507 3024 9 5/8" 47 L80 BTC-M 10.625 6870 4760 1122 9332 9416 7 5/8" 29.7 L80 Hydril 521 8.5 6890 4790 683 14362 11096 4 1/2" 15.1 P110 GeoConn 5 14420 14350 406 16809 12900 Variables & Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.433 psi MAWP=(0.80 X CASING BURST) or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg SF)X TVD)-GasGRD X TVD)) or (Max Pore Pressure-(GasGRD X TVD)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X TVD SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) Max Allowable Working Pressur •AWP=(0.80 X CASING BURST) or Limiting Wellheadsure Hole Sizes Casing Size Safety Wellhead MD(ft) TVD(ft) Burst(psi) MAWP(psi) (in) (in) Factor (psi) 18.5" 13 3/8" 3,507 3,024 5020 0.8 5,000 4016 12 1/4" 9 5/8" 9,332 9,416 6870 0.8 5,000 5496 8 1/2" 7 5/8" 14,362 11,096 6890 0.8 5,000 5512 6 3/4" 4 1/2" 16,809 12,900 14420 0.8 5,000 11536 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg)X TVD)-GasGRD X TVD)) or (Max Pore Pressure-(GasGRD X TVD)) Frac Hole Sizes Casing Size Max EMW Frac Grad at MW Safety Gas Max PP at MD(ft) TVD(ft) Pressure at MASP(psi) (in) (in) (ppg) Shoe Factor Gradient Next TVD Shoe 18.5" 13 3/8" 3,507 3,024 8.3 15.0 0.50 0.10 2135 364 364 12 1/4" 9 5/8" 9,332 9,416 8.3 15.0 0.50 0.10 6648 2,954 2,954 8 1/2" 7 5/8" 14,362 11,096 8.3 14.0 0.50 0.10 7257 3,499 3,499 6 3/4" 4 1/2" 16,809 12,900 8.4 15.0 0.50 0.10 9107 4,345 4,345 Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X TVD Hole Sizes Casing Size Safety Max EMW MD(ft) TVD(ft) Burst(psi) MW (Pore MASCP(psi) (in) (in) Factor Pressure) 18.5" 13 3/8" 3,507 3,024 5020 0.8 10 8.3 3749 12 1/4" 9 5/8" 9,332 9,416 6870 0.8 10 8.3 4664 8 1/2" 7 5/8" 14,362 11,096 6890 0.8 10 8.3 4531 6 3/4" 4 1/2" 16,809 12,900 14420 0.8 10.5 8.4 10127 Safety Factors Hole Sizes Casing Size Collapse Tension Liner Length SAFETY FACTORS MD(ft) TVD(ft) Burst(psi) Wt(lb/ft) (in) (in) (psi) (kips) (ft) Burst Collapse Tension 18.5" 13 3/8" 3507 3024 5020 2260 952 68 - 13.8 2.3 4.0 12 1/4" 9 5/8" 9332 9416 6870 4760 1122 47 - 2.3 1.5 2.6 8 1/2" 7 5/8" 14362 11096 6890 4790 683 29.7 5259 2.0 1.3 4.4 6 3/4" 4 1/2" 16809 12900 14420 14350 406 15.1 2779 3.3 3.3 9.7 SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) • • may' • *- • • �T 11-�. " ,�..... String: 4.5-in Production Liner C,E-i"'•ti'� Well Name: RU-03A WI Company: Glacier Oil &Gas Field: REDOUBT SHOAL Contact: Amanda Dial Well Location: Cook Inlet,Alaska (Offshore) Well Number(API): Osprey Platform County: State: Proposal Number: 4 Date: 12/15/2016 Made By: Stephen Lauper Service from District: Kenai,AKA District Phone: Objective: Fully Cement Liner iwth Returns circulated off of liner top Acceptance Criteria: Pump per design (Volume, Density, Rate) Disclaimer Notice Schlumberger submas this document with the benefit of its Judgment,experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts a information provided by others,limitations,computer Schlumberger models,measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be interred and no intellectual property rights are granted hereby. r • 0 Well Data Summary The cementing program incorporates the following data All depths take the rig floor as reference Yp Mud LineDepth Ri9 T e Offshore 345.0 ft Fluids Return to Water Depth 185.0 ft Mud Return Depth 79.0 ft BHST 198degF Section MD 16809.0 ft Section TVD 12900.0 ft Tubulars and Casing Hardware MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft lb/ft in psi psi Prey Casing 9103.0 9 5/8 40.0 47.0 8.681 L-80 4750 6870 API 14379.0 7 5/8 40.0 29.7 6 7/8 L-80 4790 6890 API Drill Pipe 9103.0 5 40.0 19.5 4.276 E75 10000 9500 API 14030.0 4 40.0 14.0 317/50 S-135 20140 19490 API Liner 16809.0 41/2 40.0 15.1 3.826 P-110 14340 14420 API Liner Hanger 14046.4 4 1/2 40.0 15.1 3.826 14340 14420 Landing Collar 16729.0 Serial number : MD °R Inclination(deg) Horizontal Departure(ft) a!er 0 10 20 30 40 50 ,, ,� 61C X 1 1 o 0 —Indurat on(deg} —Hor¢ontai Departure fit) J 5'61n Casing 8 J G Gid is 1 9U3ft lir L {. i v 4,4N OIII . _a 4n DalPge� a1- iii a, a SBmCasiog Z _. f- 17B46ft il Pacfier l O II i 412ing < 13830 143791 `r .trier p. .r Holei Col __j CO 16377R 1091E 1=1 c 16974 ft a: v 2 of 18 Schlumberger :A* � Open Hole Total Volume 119.5 bbl Minimum Diameter 6.750 in Maximum Diameter 6.750 in Mean Diameter 6.750 in Mean Annular Excess 20.0 Mean Equivalent Diameter 7.115 in MD NG Oft __ Oft _ lb:gal 345 ft _3451 _—_... ........... 8 10 11 12 13 c Co cc,t E. ;a E tin 5103': G) C CO C lJ'r-.+ J � u• C> 12846*9966 ft - r 13834E 10715* _ 14379ft 11108ft y k' O 1 JI R 12521ft 16729*12827ft L., 169742 16974* Formation Frac Pore Top Bottom Bottom Frac Bottom Pore Bottom Res. MD MD TVD Top ED ED Top ED ED Lithology Fluid Name ft ft ft lb/gal lb/gal lb/gal lb/gal 345.0 16974.0 13065.0 4.59 13.00 4.59 9.00 3 of 18 Schlumberger • • . Temperature Relative Name Top MD Bottom MD Bottom TVD Temperature Gradient Gradient Sea Current ft ft ft degF degF/100ft degF/100ft ft/min Surface 0.0 0.0 0.0 80 0.00 0.00 SeaLevel 0.0 160.0 160.0 80 -0.02 -0.02 10.13 SeaBed 160.0 345.0 345.0 73 -2.15 -4.00 10.13 Rock 345.0 16000.0 12220.8 191 0.91 1.00 0.00 Rock 16000.0 16809.0 12900.0 198 0.92 1.00 0.00 Geothermal Profile degF 60 80 100 120 140 160 180 200 0 0 — :geothermal temp.{degF} ...— ! i -4t- 1 92 O + r 1 , $ co tO j _ r�... O os 8 4 of 18 Schlumberger • • • Fl Summary udsSum v Fluids Type Name DensityConditions K n Ty lb/gal Ibf.s^n/ft2 Ibf/100ft2 Drilling Fluid Mud 10.10 Custom 175 degF[T2] 8.00E-3 0.60 5.92 Spacer CemPRIME SCRUB 11.50 Manual 7.43E-2 0.28 9.43 OBM Slurry Production Cement 15.30 Manual 1.37E-3 0.92 9.77 Drilling Fluid Produced Water 8.50 Surface 68 degF 7.89E-4 0.58 0.79 "Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC(65degF) — t f 1;;:ft2 — -e T,=^It.1E :E cf.lvft2 G. Rne,:ngfCeTen: ,'ICG1 ft — Rhecl7,3i F.cJ,JCe.i A31 cf:l;vh= c E t_ / 0 200 400 600 800 1000 1200 Shear Rate(1/5) 5of18 Schlumberger 0 • Mud Circulation Fluid Mud Ambient Temperature 110 degF Number of Circulation 1.55 Correction Slope 0.00 Total Volume at Ambient T 1440.0 bbl Pumping Stages Fluid Pump Rate Duration Volume bbl/min hr:mn bbl Mud 8.0 03:00 1440.0 Well Security Status Description Min Differential At Depth At Time Pressure ft hr:mn psi Success Fracturing 1316 14379.0 03:00 Success Production/Influx 605 14379.0 03:00 Success Burst 8102 79.0 03:00 Success Collapse 9457 9103.0 03:00 Psi I. --- E.n.v :ea; Je; 0 2000 4000 6000 8000 1000 z 2 0 -0 1 Pore Pressure(psi) o FracPreure(psi) m 8 \ g o —Max Annular Pressure(030`t Min Annular Pressure(psi) E o i— ,:v \\\ 's - g\ S r G \ koU s. g \\\ ? o cc.,,c :M CC4c CIM C .. .::f 6I1C 024 031C Time(hrmn) 6 of 18 Schlumberger • • Fluid Placement Surface Densities are computed at P=1 atm and T=Surface Temperature(80 degF) Fluid Placement in Annulus Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Mud 79.0 12846.4 12767.4 555.2 10.10 CemPRIME SCRUB 12846.4 13834.2 987.7 30.0 11.50 OBM Production Cement 13834.2 16809.0 2974.8 86.8 15.30 Fluid Placement in Pipe Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Produced Water 0.0 16377.4 16377.4 248.5 8.50 CemPRIME SCRUB 16377.4 16729.0 351.6 5.0 11.50 OBM Production Cement 16729.0 16809.0 80.0 1.1 15.30 MD Oft !I „ ... Producedt4ae Mud I ir.4'. y 91038 ' ' Ce T RFME SCRUB' 128468 __ 13834 8 ' Production Cement i 143798-_ CernPPoMESCRUB1 1- . 08M Fri,d or Cement_ 1637 9 did -: 16869 8 169748 7 of 18 Schlumberger • • r .s Pumping Schedule Pumping Schedule Pump Injection Cumulated Fluid Name Duration Volume Rate Temperature Comment Time hr:mn bbl bbl/min degF hr:mn CemPRIME SCRUB 00:05 30.0 6.0 68 00:05 OBM Pause 00:05 00:10 Production Cement 00:15 87.9 6.0 68 00:25 Plug 00:10 00:35 CemPRIME SCRUB 00:01 5.0 6.0 68 00:35 OBM Produced Water : 00:35 248.5 > Produced Water 00:30 238.5 8.0 68 01:05 > Produced Water 00:05 10.0 2.0 68 01:10 Maximum Required Hydraulic Horsepower(HHP) 483.1 hhp(at 01:05 hr:mn) 8 of 18 Schlumberger 1111 . ,741...-..45/510351r#40magier Pump rate(bblimin) Return Rate(bbl/Int) 0000 C1 'me mr: / 8 ----- 00:00 0020 00:40 01:00 Time(hrmn) CSI —Boaartt hole ixenire ED Oat13 PreSare E:r Frac Pressure At Bottom Hole :^e-Mrf tCrt:T E: tqat, ED(b/gal) (NI E.: ai 00:00 00:20 00:40 01:00 Time(hrmn) 9 of 18 Schlumberger • • ' ' .,...... J�'���'_"ii^F - 'yrs' ----�`-��--„"?- Well Security Sec y Well Security Status Description Min Differential At Depth At Time Pressure ft hr:mn psi Success Fracturing 890 16809.0 01:05 Success Production/Influx 605 14379.0 01:01 Success Burst 7124 79.0 01:05 Success Collapse 8243 7759.2 00:46 N/A Dead-End Collapse 0 0.0 00:00 N/A Dynamic u-tubing in Dead-End 0 0.0 00:00 N/A Balanced u-tubing in Dead-End 0 0.0 00:00 psi 0 2000 4000 6000 8000 10C,C 0 oPure Pressure(psii —Max Annular Pressure(psi) -- Min Annular Pressure 0 o Frac Pressure(psi) oo o o0 —t! gi rim 0 CO _ __:1 ._. _.. .._; _c, iimv O ��' � - -N .Ariorimo " rrrr� 1/4ai.,,._ 2 '''' '''' 'Mil 1,===ifivoir=oresmoiik.mavomm =EIE:EEEMIM-7E1M1111 --- 14 -4 rrrrr .`1rr raft.. �r. 10 of 18 Schlumberger • Temperature Outputs Temperature SummaryTable p Static Temperature.at TOC 176 degF Static Temperature at BH 198 degF Simulated HCT at TOC 154 degF Simulated HCT at BH 167 degF Max First SK Temperature 167 degF Max Last SK Temperature 167 degF At time 11 00:57 hr:mn At time 01:10 hr:mn T at Bottom Hole(degF) _Mad i CemPRIME SCRUB 0814 (JDInterface Temp(degF) CemPRIME SCRUB OBM f Productcm Cement Interface Tem;(degF Produci n Cement i CemPRfME —SCRUB DBM Interface Temp ( F) o CemPRIME SCRUB OBM i Produced �' cT Water Interface Temp(degF) 8 00 00 00:20 00:40 01:00 Time(hymn) degF 60 80 100 120 140 160 180 LC' o— - 0 — Gectnermal temp.i,degFi —T m annulus at time(degF 0 T in pipe at time(degF) o o T ' { o 1 - 4 o 1-44 E 11 of 18 Schlumberger • • .f Centralization Centralizers Commercial Alias Manufacturer Name Type Config Csg OD Min OD Max OD Count in in in SPIRAGLIDER HD-4 Hannover Not Set rigid Not Set 4 1/2 6.252 6.252 0 1/2-4-SPI RAL650 SpiraGlider HD-5 0-4- Hannover SpiraGlider HD rigid Spiral 5 6.252 6.252 0 Spiral650 - 1502041-41/2-4- Houma 1502041 rigid Positive 41/2 6.500 6.500 60 Positive Pattern Placement Bottom MD Joints Centralizer Alias Pattern Min STO Depth ft ft 14418.0 9.29 - 0 0.0 14052.9 16809.0 59.77 1502041-4 1/2-4-Positive 1/1 0.0 14423.1 D, MD Oft 100 345 ft ----- Proci;ce 1^;a'er 0 20 40 60 80 - 8 NIi,d ,I Standoff bt*central¢ets (%) 3 • . Standoff at centralizers t%1 k 1 I i 7 0 8 co \ItilFj1 to • to $' 0 C 8 \ ,, , 1 .846* _ _ Ce RBAE SCRUB] 138341 "-5, r "'.Production Cement 1 >43791 i 1 CemPRIME SCRUB P „OMM1- _x Prodi on Cement 1 16377 ft.. .> �16729*�� 16974 ft Computation time:Cement Turns 00:56 12 of 18 Schlumberger • • • WELLCLEAN* III Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe Average Concentration(%) Average Concentration(%) D 20 40 60 80 100 o 0 20 40 60 80 100 120 —mod mann.(%) —Mudmpipe(%) CemPRIME SCRUB OBM _CemPRIME SCRUB OBt�! m ann. in pipe Production Cement in ann. Production Cement in pipe ( (%) —Produced Water in ann. ( —Produced Water in pipe 8 t � Q m S kr,w v U C af)i w g L � 71 Mil + � 8 �!�4 of 13 of 18 Schlumberger • • Atize, Final Fluid Concentrations MD 0 ft 345 t_ 1 5.500 91038 — 12840* CP R ME SCRUB' ORM Frcd,cnor Cement, 13834* i 1403011 14379* Fluids Concentrations Md COBM CemPRIME SCRUI31 emPRIME SCRUB Production Cement Prediction Cemerti III 1 Produced Water 163774k. rTT 4,11 mud 16729* " RoP2: -- itti74 t 14 of 18 Schlumberger • • an. Post-Processing Results (Annulus) 14500_ 14600 } 15500 15000_ 1 5000_ YS" 18000_ 15500_ 16500 Contact Time(second) Mud On Wall Risk - 0 0 ® None 675 3 III Low I. 1350.7 Medium 2026.0 ® High IN2701 4 15 of 18 Schlumberger • • Operator Summary Volume Summary Prepared Fluid Mix Fluid Dead Silo dead Fluid Name Pumped Volume Dead Volume Prepared Fluid Volume volume bbl bbl bbl bbl ton Production Cement 87.9 5.0 92.9 0.0 0 CemPRIME SCRUB 35.0 15.0 50.0 0.0 0 OBM Material Summary Additive Pumped Required Loadout Loadout Pack. Pack. Comment Quantity Quantity Quantity Items Name Size D031 6142.61b 8775.21b 8775.21b 79.77 sack 110.Olb Fresh Water 3328.1 gal 3940.9 gal 3940.9 gal 0.00 0.0 gal D182 149.2 lb 213.2 lb 213.2 lb 4.26 sack 50.0 lb D047 7.0 gal 10.0 gal 10.0 gal 2.00 pail 5.0 gal F103 70.0 gal 100.0 gal 100.0 gal 1.82 drum 55.0 gal U066 70.0 gal 100.0 gal 100.0 gal 0.00 0.0 gal Production Cement 34493.1 lb 36454.2 lb 36454.2 lb 0.00 bulk 0.0 lb Blend D046 69.0 lb 72.9 lb 72.9 lb 1.46 sack 50.0 lb D202 172.51b 182.31b 182.31b 7.29 sack 25.Olb D400 275.91b 291.61b 291.61b 11.67 sack 25.Olb D154 2759.4 lb 2916.3 lb 2916.3 lb 29.16 sack 100.0 lb D174 517.4 lb 546.8 lb 546.8 lb 10.94 sack 50.0 lb D198 17.2 lb 18.2 lb 18.2 lb 0.36 sack 50.0 lb 16 of 18 Schlumberger • • Fluid Preparation Production Cement Pumped Volume:87.9 bbl Density: 15.30 lb/gal SVF:40.4% Yield : 1.35 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 38304.6 lb 40482.3 lb Production Cement Blend: 94.0 lb per sack 34493.1 lb 36454.2 lb 36454.2 lb -G 94 lb/sk WBWOB 34493.1 lb 36454.2 lb 36454.2 lb D046 0.2%BWOB 69.0 lb 72.9 lb 72.9 lb D202 0.5%BWOB 172.5 lb 182.3 lb 182.3 lb D400 0.8%BWOB 275.9 lb 291.6 lb 291.6 lb D154 8.0%BWOB 2759.4 lb 2916.3 lb 2916.3 lb D174 1.5%BWOB 517.4 lb 546.8 lb 546.8 lb D198 0.1 %BWOB 17.2 lb 18.2 lb 18.2 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Mix Fluid 5.965 gal/sk VBWOB 2188.6 gal 2313.1 gal Fresh Water 5.965 gal/sk VBWOB 2188.6 gal 2313.1 gal 2313.1 gal CemPRIME SCRUB OBM Pumped Volume:35.0 bbl Density: 11.50 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity CemPRIME SCRUB OBM 4.18 lb/gal WBVOSpacer 6142.6 lb 8775.2 lb 8775.2 lb Weighting Material: -D031 4.18 lb/gal WBVOSpacer 6142.6 lb 8775.2 lb 8775.2 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1300.0 gal 1857.2 gal Fresh Water 0.8 bbl/bbl BVOSpacer 1139.5 gal 1627.8 gal 1627.8 gal D182 5.50 lb/bbl WBVOBF 149.2 lb 213.2 lb 213.2 lb D047 0.2 gal/bbl BVOSpacer 7.0 gal 10.0 gal 10.0 gal F103 2.0 gal/bbl BVOSpacer 70.0 gal 100.0 gal 100.0 gal U066 2.0 gal/bbl BVOSpacer 70.0 gal 100.0 gal 100.0 gal 17 of 18 Schlumberger • • ro Document Control Document Name and Version Once approved by Schlumberger and the Operator,any deviation from this program requires document agreement(SLB QHSE Standard S010 Management of Change and Exemption Standard) Approvals Name Signature Date Author Stephen Lauper Schlumberger review Rianne Campbell Schlumberger Approval Customer Approval Amanda Dial "By signing this document (or confirmation email), I confirm I have reviewed and approved it as the basis for the well cementing program." Distribution List : Cementing Program Generated From Cementics File ru-03a_designv2.jdcx Cementics Version 2016.2.70 Revision History Date Version Description Author 12/15 V4 Updated Liner Depths and Directional slauper References Version Planned Date received Originator Filename or actual Well Trajectory P6 18of 18 Schlumberger • R3 Current Completion 12/6/2012 SSSV©303'MD i ''''' ' N ____ 2-7/8"Halliburton SSSV at 287' liL 30" A-36 200 MD 150# Welded 200'TVD (I * 4 — 2-7/8"chemical injection mandrel @ 2,500'MD 4113 3/8" L-80 3,507'MD �_. 68# BTC 3,024'TVD 0 4 2-7/8"WXO Sliding Sleeve @ 7,578'MD fit.A, x � ( 9-5/8"x 2-7/8"Weatherford Hydrow I ,44'b' hydraulic-set packer @ 7,614'MD 4 2-7/8"Sliding Sleeve @ 7,754'MD 2 7/8"6.5#L-80 EUE M Tubing Perforations-7780'-7818'MD/ 6,203'-6,232'TVD i r II Redressed 9-5/8"x 2-7/8"Weatherford Hydrow 1 hydraulic set packer @ 7,854'MD TOL @ 9,103'MD dr3- " Baker Hanger Assemblyi 9 5/8" L-80 9,332'MD �� �, -I 47# BTC 7,416'TVD 2-7/8"XN-nipple @ 14,751'MD i J 0 I cl� Top Tieback 14,717'MD i WL Re-Entry Guide @ 14,791'MD Perforations-14,803'-14,860'MD/ 11,410'-11,450'TVD 3 I Baker Hanger Assembly 1' 7 5/8" L-80 15,615'MD Z I 29.7# Hydril 521 11,981'TVD Cement Retainer @ 15,691'MD `Dili _ Lost fish @ 15,768'-16,048'MD -.w „lc, T, - 5 1/2" L-80 16,940'MD 11 17# Hydril 521 13016'TVD RU-03 Proposed Abandonment Schematic • 12/20/2016 Version-3.0 i ,1. i, 30" A-36 200'MD 150# Welded 200'TVD -A 13 3/8" 68#L-80 3,507'MD ID 12.415" BTC 3,024'TVD .:1 ' .I -`Casing Patch-ID 7.75"after setting @ 7,770'-7,830'MD ) Perforations-7780'-7818'MD/ (c L 6,203'-6,232'TVD 71 .115 i , ti. TOL @ 9,103'MD 9 5/8" 47#L-80 9,332'MD Baker Hanger Assembly 2ID 8.525 BTC 7,416'TVD s: Whipstock top of window @ 14,362'MD Cement Retainer @ 14,388'MD Top Tieback @ 14,717'MD .• r : .� Cern-.t squeeze perfs,20 bbls 15.3 ppg Perforations-14,803'-14,860'MD/ – •n" 11,410'-11,450'TVD • •••� ? IN .1 ' t`I 17 5/8" 29.7#L-80 15,615'MD Baker Hanger Assembly ID 6.875" Hydril 521 11,981'TVD ev, Cement Retainer @ 15,691'MD . ✓- Lost fish @ 15,768'-16,048'MD — ✓eY '` i I A ,3 '' 5 1/2" 17#L-80 16,940'MD ti ID 4.767" Hydril 521 13,016'TVD • RU-03A WI-Proposed Frac Wellbore Schema: Date: 3-Jan-17 Version: 1.0 GLACIER Tubing Hanger-3-1/2"12.95#PH6-Top&Btm 30" 150#A-36 260'MD _I 7., ,a.._ Tubing -28" Welded 260'TVD y tl 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole A , ID-12.25" BTC 3,024'TVD Perforations 9-5/ Casing Patch-7,750'-7,850'MD MD TVD Feet ^1I / 7,780-7,800 6,203-6,219 20 7 7,805-7,818 6,223-6,233 13 / 7 5/8"X 9 5/8"Liner Hanger TOL©9,103'MD 9 5/8" 47#L-80 9,332'MD 12 1/4"Hole ID-8.50" BTC 7,416'TVD F.; 4 1/2"15.1#P-110 Frac String TOL @ 14,030'MD - _fik: Window 7 5/8" 29.7#L-80 14,362'MD 8 1/2"Hole ID-6.75" Hydril 521 11,096'TVD a i =N cep° ..., . 't liaeR ... [sw ,.„,,,._ .._ .c... - Perf/Frac Intervals MD TVDFeet , i Plug and Pert Hydraulic Frac Completion f C 15650-15660 11973-11980 10 15860-15870 12118--12125 10 16110-16120 12,65-12312 10 / 4 1/2" 15.1#P-110 16,809'MD 6 3/4"Hole ' , I_ ID-3.832" GeoConn 12,900'TVD 37Nl-Proposed Completion Wellbore Schematic, Date: 7-Feb-17 Version: Final GLACIER Tubing Hanger-3-1/2"12.95#PH6-Top&Btm 30" 150#A-36 260'MD ID-28" Welded 260'ND 3-1/2"12.95#P-110 PH6 Tubing-ID-2.75" 13 3/8" _ 68#L-80 3,507'MD 18 1/2"Hole , , ID-12.25" BTC 3,024'ND Perforations _ 9-5/8"Casing Patch-7,750'-7,850'MD MD TVD Feet 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 7 5/8"X 9 5/8"Liner Hanger , TOL @ 9,103'MD ; 7' 9 5/8" 47#L-80 9,332'MD 12 114"Hole '-•k ID-8.50" BTC 7,416'ND $l'. . A • t: 3-1/2"PH6 X 2-3/8"EUE X/0 at 14,150'MD TOL @ 14,030'MD Window 'L 7 5/8" 29.7#L-80 14,362'MD 8 1/2"Hole ID-6.75" Hydril 521 11,096'ND ,.. 2 3/8"4.6#L-80 EUE Tubing-ID-1.901" ■ 2-3/8"X 4-1/2"Permanent Packer r 2-3/8"Sliding Sleeve @+/-16,500'MD c llPerf/Frac Intervals II• 2-3/8"X4-1/2"Permanent Packer MD TVD Feet • (( 15650-15660 11973-11980 10 { c 2-3/8"Sliding Sleeve 15860-15870 12118-12125 10 16110-16120 12305-12312 10 2-3/8"X 4-1/2"Permanent Packer a c ( ''': 2-3/8"XN Nipple i 4 1/2" 15.1#P-110 16,809'MD 6 3/4"Hole J IF. ID-3.832" GeoConn 12,900'ND 1 • • Page 25-R Metal One GeoGunn Date 22-Jul-14 Connection Data Sheet Metal One Corp Rev. 4 1 fL. 1 « 1-----.--,,,,, ;,:z, -glii, ,i, -,70,14.:k.A.,„ ,,,,:!.-kv,,,,74,-,,,74i„^41,,,,i_,,,';_1.1 I I c '17 I I Imperial Si. Pipe Body Grade P110 P110 Pipe OD(D) 4.500 in 114.3 mm Weight 15.1 lb/ft 22.50 kg/m wall thickness(t) 0.337 in 8.56 mm Pipe ID(d) 3.826 in 97.18 mm Drift Dia. 3.701 in 94.01 mm Connection Pipe Critical Area 4.41 in2 2,842 mm2 Box critical Area 4.51 in2 2,911 mm2 Coupling OD(W) 5.250 in 133.35 mm Coupling Length(NL) 8.068 in 204.93 mm Make up Loss 3.984 in 101.19 mm Thread Taper 1 /16(3/4"per ft) Number of threads 5 TPI Performance Properties S.M.Y.S. 484.6 kips 2,155 kN Connection Joint Strength 508.6 kips 2,262 kN M.I.Y.P.pipe body 14,400 psi 99.31 MPa M.I.Y.P.Connection 18,000 psi 124.14 MPa Collapse strength 14,340 psi 98.90 MPa Pipe body Yield Torque 45,184 ft-lb 61,200 N-m Note S.M.Y.S. = Specified Minimum YIELD Strength of Pipe body M.I.Y.P. = Minimum Internal Yield Pressure Torque Recommended Min. 9,000 ft-lb I 12,200 I N-m I Opti. 10,000 ii-ib 13,500 AI-r+. 1 Max. 11,000 ft-lb 14,900 N-m I Operational Max. 13,000 I ft-lb 17,600 N-m Connection Yield Torque 1 15,300 1 ft-lb 1 20,700 1 N-m Note :Operational Max.torque can be applied for high torque application Legal Notice The use of the information is at the reader's risk and no warranty is implied or expressed by MetalOne Corporation with respect to the use of Information contained herein. 0 0 Cook Inlet Energy, L.L.C. GE & ,,,,.. 44.- C:IGos RU-03 Proposed Frac e I t "e ....' A 1 # _sp. .... ,.. .1•41 0, lial — 0 • . 4 t 0 411111.11M I 11 •4 or t a ' I INIMINNIN MO -ME mom= tif ID ....„.. .....,..itl 0.-4.... u...._ ii• 1' ,-1 i 0 WA f. . .. • 10Ai = I 1 ..] orii 1 1;1 Int 0 .a"4 L I I 1 T i 0 • oli GE Oil & Gas 4 45.6" • TT FR1 360' O 'b:� 3-1/8'5M O O ''t-.,1 IMO 1Pt• 31/8'SM I 011, ilk 01464 411(0144 (4 °' 'C) 0 a 4 .it:311111 ^O ici,',1111 V V' mt11I n1�1111 . Si 4" /40111.4 ,,4-54, ::,z....-- .t,i;:ai 111 O O 1 1. u u lull 1m1 114.5' 13-5'8"SM / lel_ •i � ' 29 9.10 5 )8.0" ■..... I. ) �ayIllllllllll�l.l'I J O , ,, ■ 2-1/16.5M • • ' n•I. :rte' — Lu iSSI 27.2"to 3 •.... I A 2-1116"561 lig ' at ! 1■P w 'ii a Il l I— _ll 30'Casing [l I1Gas,318"Cas 9-58'Casing 3-112'TUWn9L_ PFT Cable ALL DIMENSIONS ARE APPROXIMATE INLET CMC This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing, 1-]COOK INLET ENERGY A �A� neither it nor its contents may be used,copied.transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. OSPREY PLATFORM FORM RU-03A V V I 13-3/8" x 9-5/8" x 3-1/2" 5M Multibowl Wellhead DRAWN _ CR 050CT16 APPRV KN 050CT16 Assembly With MB-205 Tubing Head and Tubing FOR REFERENCE ONLY Hanger and Adapter Flange DRAWING NO. HP160203-1 , . • CIE Rig 35 Redoubt Unit 13 5/8" 10,000 PSI BOP STACK L. i 5000 psi Annular } 1 t A 10,000 psi 4" pipe rams Double Gate ...�. �.:. _ .....,..�..,..�... .1.- 4" outlets 10,000 psi l DSA T/3" Both sides Blind Rams Double Gate 3" Kill line Mud 3" Choke line 2 2 i Cross x~ 2 1 1= HCR Valve 10,000 psi I 2=Gate Valve 4" Pipe Rams Single Gate I t r t 13 5/8" f, . 1 1 5M t. t t Wellhead k e_ s 13 3/8" Surface Casing 9 5/8" Intermediate Casing i Schiumberger FracCADE* STIMULATION PROPOSAL Operator : Glacier Oil &Gas Well : RU-03A Field : Redoubt Formation : Lower Hemlock Well Location : Cook Inlet County : Kenai Peninsula State : Alaska Country : United States Prepared for : Anna Belanger Service Point : Prudhoe Bay Proposal No. Business Phone : 907 2731700 Date Prepared : 31 Jan 2017 FAX No. : 907 561 8317 Prepared by : Gunther Rutzinger Phone : 907 2731788 E-Mail Address : grutzinger@slb.com *Mark of Schlumberger Pisclaimer Notice: This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • . Client : Glacier Oil &Gas tirr Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Contents Section 1: Wellbore Configuration 3 Section 2: Zone Data 4 Section 3: Propped Fracture Schedule 7 Section 4: Propped Fracture Simulation 9 Section 5: Propped Fracture Simulation Results 12 Section 6: Fluid Descriptions 13 Section 7: Proppant Data 14 Section 8: Hole Survey 15 2 • • Client : Glacier Oil &Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 1: Wellbore Configuration Bottom Hole Temperature 190 degF Deviated Hole YES Treat Down TUBING Well Type Vertical Well Location OffShore Tubing Data OD Weight ID Depth (in) (lb/ft) (in) (ft) 4.500 15.5 3.826 12928.0 Casing Data OD Weight ID Depth (in) (Ib/ft) (in) (ft) 9.625 47.0 8.681 12928.0 4.500 15.1 3.826 16809.0 Perforation Data Top Top Bottom Bottom Shot Number Diameter MD TVD MD TVD Density (ft) (ft) (ft) (ft) (shot/ft) (in) 16110.0 12304.9 16120.0 12312.7 6.00 60 0.32 Offshore Ocean Depth 50.0 Ocean Bed Temperature 39 Ocean Surface Current Velocity 50.63 3 • i Client : Glacier Oil & Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 2: Zone Data Formation Mechanical Properties Zone Name Top TVD Zone Frac Insitu Young's Poisson's Toughness Ift) Height Grad. Stress Modulus Ratio (psi.in0.5) (ft) (psi/ft) (psi) (psi) DIRTY-SANDSTONE 11889.0 18.0 0.807 9606 4.560E+6 0.26 1200 SILTSTONE 11907.0 22.0 0.831 9904 3.840E+6 0.26 1000 DIRTY-SANDSTONE 11929.0 22.6 0.789 9421 4.790E+6 0.19 700 DIRTY-SANDSTONE 11951.6 2.1 0.822 9825 4.160E+6 0.24 700 CLEAN-SANDSTONE 11953.7 27.5 0.773 9251 4.360E+6 0.23 1200 DIRTY-SANDSTONE 11981.2 8.4 0.821 9840 4.230E+6 0.25 700 CLEAN-SANDSTONE 11989.6 31.4 0.771 9256 4.800E+6 0.20 1200 Siltzone 12021.0 6.0 0.803 9660 1.610E+6 0.39 700 SILTSTONE 12027.0 12.0 0.855 10288 3.900E+6 0.30 1000 DIRTY-SANDSTONE 12039.0 30.0 0.820 9884 3.970E+6 0.28 700 Middle Hemlock 12069.0 128.1 0.777 9430 4.620E+6 0.23 1200 DIRTY-SANDSTONE 12197.1 8.2 0.803 9798 3.830E+6 0.19 700 CLEAN-SANDSTONE 12205.3 8.3 0.773 9438 5.010E+6 0.21 1200 SHALE 12213.6 12.9 0.945 11548 3.970E+6 0.28 1000 CLEAN-SANDSTONE 12226.5 34.7 0.775 9489 4.730E+6 0.19 1200 SILTSTONE 12261.2 2.8 0.905 11098 2.180E+6 0.31 1000 DIRTY-SANDSTONE 12264.0 1.8 0.816 10008 1.180E+6 0.43 700 SHALE 12265.8 3.5 0.938 11507 3.700E+6 0.28 1000 SILTSTONE 12269.3 10.2 0.887 10887 3.480E+6 0.26 1000 Lower Hemlock 12279.5 16.5 0.806 9900 5.170E+6 0.19 700 DIRTY-SANDSTONE 12296.0 4.5 0.821 10097 6.180E+6 0.18 700 CLEAN-SANDSTONE 12300.5 24.7 0.776 9555 5.940E+6 0.17 1200 DIRTY-SANDSTONE 12325.2 12.6 0.820 10112 4.350E+6 0.19 700 CLEAN-SANDSTONE 12337.8 7.3 0.773 9540 4.460E+6 0.23 1200 SILTSTONE 12345.1 2.6 0.844 10420 6.800E+6 0.18 1000 DIRTY-SANDSTONE 12347.7 5.6 0.787 9720 6.480E+6 0.16 700 SHALE 12353.3 3.6 0.886 10947 7.690E+6 0.19 1000 DIRTY-SANDSTONE 12356.9 45.6 0.804 9953 5.350E+6 0.19 700 DIRTY-SANDSTONE 12402.5 11.2 0.832 10324 6.100E+6 0.17 700 CLEAN-SANDSTONE 12413.7 18.1 0.790 9814 5.190E+6 0.20 1200 WF Coal 12431.8 11.2 0.977 12151 4.520E+6 0.29 1000 SILTSTONE 12443.0 4.3 0.917 11412 5.120E+6 0.24 1000 DIRTY-SANDSTONE 12447.3 4.3 0.839 10445 4.940E+6 0.23 700 SHALE 12451.6 8.6 0.952 11858 4.300E+6 0.29 1000 SILTSTONE 12460.2 17.2 0.906 11297 4.890E+6 0.27 1000 DIRTY-SANDSTONE 12477.4 14.6 0.829 10350 3.930E+6 0.23 700 SHALE 12492.0 12.9 0.958 11974 3.250E+6 0.28 1000 SILTSTONE 12504.9 7.8 0.916 11458 3.520E+6 0.29 1000 SILTSTONE 12512.7 8.6 0.885 11078 4.230E+6 0.27 1000 4 • • Client : Glacier Oil &Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock DIRTY-SANDSTONE 12521.3 6.0 0.827 10358 3.570E+6 0.24 700 SHALE 12527.3 13.8 0.978 12258 3.590E+6 0.31 1000 West Foreland 12541.1 42.2 0.803 10087 2.800E+6 0.31 1200 SHALE 12583.3 4.3 0.956 12032 1.270E+6 0.29 1000 DIRTY-SANDSTONE 12587.6 3.4 0.815 10260 5.780E+5 0.40 0 DIRTY-SANDSTONE 12591.0 29.2 0.838 10563 3.330E+6 0.29 700 SILTSTONE 12620.2 14.6 0.898 11339 2.190E+6 0.32 1000 SILTSTONE 12634.8 6.0 0.851 10755 3.450E+6 0.29 1000 CLEAN-SANDSTONE 12640.8 10.5 0.798 10092 2.620E+6 0.33 1200 DIRTY-SANDSTONE 12651.3 7.4 0.837 10592 1.460E+6 0.32 700 DIRTY-SANDSTONE 12658.7 12.8 0.737 9334 2.450E+6 0.33 700 Formation Transmissibility Properties Zone Name Top TVD Net Perm Porosity Res. Gas Oil Sat. Water (ft) Height Imd) (%) Pressure Sat. (%) Sat. (ft) (psi) (%) (%) DIRTY-SANDSTONE 11889.0 14.4 10.000 15.0 3957 10.0 65.0 25.0 SILTSTONE 11907.0 8.8 0.100 10.0 3959 10.0 65.0 25.0 DIRTY-SANDSTONE 11929.0 18.1 2.000 15.0 3963 10.0 65.0 25.0 DIRTY-SANDSTONE 11951.6 1.7 2.000 15.0 3969 10.0 65.0 25.0 CLEAN-SANDSTONE 11953.7 27.5 10.000 18.0 3979 10.0 65.0 25.0 DIRTY-SANDSTONE 11981.2 6.7 2.000 15.0 3988 10.0 65.0 25.0 CLEAN-SANDSTONE 11989.6 31.4 10.000 18.0 3997 10.0 65.0 25.0 v Siltzone 12021.0 2.4 2.000 10.0 4005 10.0 65.0 25.0 . SILTSTONE 12027.0 4.8 0.100 10.0 4008 10.0 65.0 25.0 DIRTY-SANDSTONE 12039.0 24.0 2.000 15.0 4014 10.0 65.0 25.0 Middle Hemlock 12069.0 128.1 10.000 18.0 4045 10.0 65.0 25.0 DIRTY-SANDSTONE 12197.1 6.6 2.000 15.0 4074 10.0 65.0 25.0 CLEAN-SANDSTONE 12205.3 8.3 10.000 18.0 4077 10.0 65.0 25.0 SHALE 12213.6 0.6 0.001 5.0 4082 10.0 65.0 25.0 CLEAN-SANDSTONE 12226.5 34.7 10.000 18.0 4091 10.0 65.0 25.0 SILTSTONE 12261.2 1.1 0.100 10.0 4099 10.0 65.0 25.0 DIRTY-SANDSTONE 12264.0 1.4 2.000 15.0 4100 10.0 65.0 25.0 SHALE 12265.8 0.2 0.001 5.0 4101 10.0 65.0 25.0 SILTSTONE 12269.3 4.1 0.100 10.0 4104 10.0 65.0 25.0 Lower Hemlock 12279.5 16.5 2.000 18.0 4109 10.0 65.0 25.0 DIRTY-SANDSTONE 12296.0 3.6 2.000 15.0 4113 10.0 65.0 25.0 CLEAN-SANDSTONE 12300.5 24.6 10.000 18.0 4119 10.0 65.0 25.0 DIRTY-SANDSTONE 12325.2 10.1 2.000 15.0 4127 10.0 65.0 25.0 CLEAN-SANDSTONE 12337.8 7.3 10.000 18.0 4131 10.0 65.0 25.0 SILTSTONE 12345.1 1.0 0.100 10.0 4550 10.0 65.0 25.0 DIRTY-SANDSTONE 12347.7 4.5 2.000 15.0 4552 10.0 65.0 25.0 SHALE 12353.3 0.2 0.001 5.0 4553 10.0 65.0 25.0 DIRTY-SANDSTONE 12356.9 36.5 2.000 15.0 4557 10.0 65.0 25.0 DIRTY-SANDSTONE 12402.5 9.0 2.000 15.0 5597 10.0 65.0 25.0 5 • 0 Client : Glacier Oil & Gas SeMo fel Well : RU-03A 1►II ler ri G1 Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock CLEAN-SANDSTONE 12413.7 18.1 10.000 18.0 5603 10.0 65.0 25.0 WF Coal 12431.8 0.6 0.001 5.0 5609 10.0 65.0 25.0 SILTSTONE 12443.0 1.7 0.100 10.0 5613 10.0 65.0 25.0 DIRTY-SANDSTONE 12447.3 3.4 2.000 15.0 5614 10.0 65.0 25.0 SHALE 12451.6 0.4 0.001 5.0 5617 10.0 65.0 25.0 SILTSTONE 12460.2 6.9 0.100 10.0 5623 10.0 65.0 25.0 DIRTY-SANDSTONE 12477.4 11.7 2.000 15.0 5630 10.0 65.0 25.0 SHALE 12492.0 0.6 0.001 5.0 5636 10.0 65.0 25.0 SILTSTONE 12504.9 3.1 0.100 10.0 5640 10.0 65.0 25.0 SILTSTONE 12512.7 3.4 0.100 10.0 5644 10.0 65.0 25.0 DIRTY-SANDSTONE 12521.3 4.8 2.000 15.0 5647 10.0 65.0 25.0 SHALE 12527.3 0.7 0.001 5.0 5651 10.0 65.0 25.0 West Foreland 12541.1 42.2 10.000 18.0 5663 10.0 65.0 25.0 SHALE 12583.3 0.2 0.001 5.0 5673 10.0 65.0 25.0 DIRTY-SANDSTONE 12587.6 2.7 2.000 15.0 5675 10.0 65.0 25.0 DIRTY-SANDSTONE 12591.0 23.4 2.000 15.0 5682 10.0 65.0 25.0 SILTSTONE 12620.2 5.8 0.100 10.0 5691 10.0 65.0 25.0 SILTSTONE 12634.8 2.4 0.100 10.0 5695 10.0 65.0 25.0 CLEAN-SANDSTONE 12640.8 10.5 10.000 18.0 5699 10.0 65.0 25.0 DIRTY-SANDSTONE 12651.3 5.9 2.000 15.0 5703 10.0 65.0 25.0 DIRTY-SANDSTONE 12658.7 10.2 2.000 15.0 5707 10.0 65.0 25.0 6 • • Client : Glacier Oil &Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 3: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length(X1)of 214.8 ft with an average conductivity(K,w)of 251 md.ft. Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (gal) (lb/mgall (PPA) PAD 20.0 YF127FIexD 10500 27.1 0.00 1.0 PPA 20.0 YF127FIexD 1609 27.1 20/40 CarboLite(USA) 1.00 2.0 PPA 20.0 YF127FIexD 1544 27.1 20/40 CarboLite(USA) 2.00 3.0 PPA 20.0 YF127FIexD 1483 27.1 20/40 CarboLite(USA) 3.00 4.0 PPA 20.0 YF127FIexD 1428 27.1 20/40 CarboLite(USA) 4.00 5.0 PPA 20.0 YF127FIexD 1376 27.1 20/40 CarboLite(USA) 5.00 6.0 PPA 20.0 YF127FIexD 1328 27.1 20/40 CarboLite(USA) 6.00 Flush 20.0 WF127 9622 27.1 0.00 n' C* C 3 Fluid Totals CD 19267 gal of YF127FIexD m 9622 gal of WF127 - m Proppant Totals o 29700 lb of 20/40 CarboLite(USA) Pad Percentages %PAD Clean 54.5 %PAD Dirty 51.0 Job Execution Step Step Cum.Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (Ib) (Ib) Pressure (min) (min) (gal) (bbl) (bbl) (psi) PAD 10500 10500 250.0 250.0 0 0 8061 12.5 12.5 1.0 PPA 1609 12109 40.0 290.0 1609 1609 8033 2.0 14.5 2.0 PPA 1544 13652 40.0 330.0 3087 4696 7955 2.0 16.5 3.0 PPA 1483 15136 40.0 370.0 4450 9146 7808 2.0 18.5 4.0 PPA 1428 16563 40.0 410.0 5710 14856 7607 2.0 20.5 5.0 PPA 1376 17939 40.0 450.0 6879 21735 7359 2.0 22.5 6.0 PPA 1328 19267 40.0 490.0 7966 29701 7060 2.0 24.5 Flush 9622 28888 229.1 719.1 0 29701 7238 11.5 36.0 7 • . Client : Glacier Oil & Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Pumping Schedule Totals Summary for This Stage: Average Pump Rate 20.0 bbl/min Volume Weighted Average Rate 20.0 bbl/min Total Fluid Volume 28888 gal Total Proppant Mass 29700 lb Total Slurry Volume 719.1 bbl Total Pump Time 36.0 min Fluid Based Totals for This Stage Average Volume Total Total Total Total Fluid Pump Weighted Fluid Proppant Slurry Pump Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) fib) (bbl) (min) WF127 20.0 20.0 9622 0 229.1 11.5 YF127FIexD 20.0 20.0 19267 29701 490.0 24.5 Proppant Based Totals for This Stage Average Volume Total Total Total Total Proppant Pump Weighted Fluid Proppant Slurry Pump Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (lb) (bbl) (min) 20/40 CarboLite(USA) 20.0 20.0 8767 29701 240.0 12.0 Summary for Each Treatment Average Volume Total Total Total Total Treatment Pump Weighted Fluid Proppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (Ib) (bbl) (min) Propped Fracture 20.0 20.0 28888 29701 719.1 36.0 Summary for Each Fluid in Each Treatment Average Volume Total Total Total Total Treatment Fluid Pump Weighted Fluid Proppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time (bbl/min) (bbl/min) (gal) (Ib) (bbl) (min) Propped Fracture WF127 20.0 20.0 9622 0 229.1 11.5 Propped Fracture YF127FIexD 20.0 20.0 19267 29701 490.0 24.5 8 • • Client : Glacier Oil & Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 4: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model.Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD 12300.5 ft Initial Fracture Bottom TVD 12325.2 ft Propped Fracture Half-Length 214.8 ft EOJ Hyd Height at Well 159.2 ft Average Propped Width 0.060 in Average Gel Concentration 720.1 lb/mgal Average Gel Fluid Retained Factor 0.50 Net Pressure 793 psi n Efficiency 0.260 ? Effective Conductivity 468 md.ft = 3 Effective Fcd 0.2 Max Surface Pressure 8072 psi m CD -v Il..' Simulation Results by Fracture Segment m From To Prop.Conc. Propped Propped Frac. Frac. Fracture {ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (lb/mgal) (md.ft) (PPA) (lb/ft2) _ 0.0 53.7 6.1 0.073 100.3 0.64 627.8 313 53.7 107.4 6.0 0.070 147.3 0.63 _ 622.1 294 107.4 161.1 5.4 0.063 127.2 0.57 638.7 269 161.1 214.8 1.1 0.037 70.3 0.34 991.9 157 9 • • Client : Glacier Oil & Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Fracture Geometry Data Per Zone for Production Prediction Zone Name Top MD Top Gross Net Fracture Fracture Fracture Ift) TVD Height Height Width Length Conductivity (ft) (ft) (in) (ft) (md.ft) DIRTY-SANDSTONE 15523.8 11889.0 18.0 14.4 0.000 .0 0 SILTSTONE 15550.7 11907.0 22.0 8.8 0.000 .0 0 DIRTY-SANDSTONE 15583.5 11929.0 22.6 18.1 0.000 .0 0 DIRTY-SANDSTONE 15617.3 11951.6 2.1 1.7 0.000 .0 0 CLEAN-SANDSTONE 15620.5 11953.7 27.5 27.5 0.000 .0 0 DIRTY-SANDSTONE 15661.6 11981.2 8.4 6.7 0.000 .0 0 CLEAN-SANDSTONE 15674.1 11989.6 31.4 31.4 0.000 .0 0 Si)tzone 15720.8 12021.0 6.0 2.4 0.000 .0 0 SILTSTONE 15729.7 12027.0 12.0 4.8 0.000 .0 0 DIRTY-SANDSTONE 15747.2 12039.0 30.0 24.0 0.000 .0 0 Middle Hemlock 15790.6 12069.0 128.1 128.1 0.000 .0 0 DIRTY-SANDSTONE 15968.4 12197.1 8.2 6.6 0.000 .0 0 CLEAN-SANDSTONE 15979.4 12205.3 8.3 8.3 0.000 .0 0 SHALE 15990.5 12213.6 12.9 .6 0.000 .0 0 - CLEAN-SANDSTONE 16007.6 12226.5 34.7 34.7 0.000 .0 0 SILTSTONE 16053.3 12261.2 2.8 1.1 0.000 .0 0 DIRTY-SANDSTONE 16057.0 12264.0 1.8 1.4 0.000 .0 0 SHALE 16059.3 12265.8 3.5 .2 0.000 .0 0 SILTSTONE 16063.9 12269.3 10.2 4.1 0.011 181.9 48 Lower Hemlock 16077.1 12279.5 16.5 16.5 0.048 205.7 200 DIRTY-SANDSTONE 16098.5 12296.0 4.5 3.6 0.085 214.8 358 CLEAN-SANDSTONE 16104.3 12300.5 24.7 24.6 0.111 214.8 468 DIRTY-SANDSTONE 16135.9 12325.2 12.6 10.1 0.086 212.1 364 CLEAN-SANDSTONE 16151.9 12337.8 7.3 7.3 0.078 197.3 330 SILTSTONE 16161.2 12345.1 2.6 1.0 0.070 188.6 295 DIRTY-SANDSTONE 16164.5 12347.7 5.6 4.5 0.055 185.5 232 SHALE 16171.5 12353.3 3.6 .2 0.044 182.3 186 DIRTY-SANDSTONE 16176.1 12356.9 45.6 36.5 0.034 167.1 143 DIRTY-SANDSTONE 16233.0 12402.5 11.2 9.0 0.011 127.1 46 CLEAN-SANDSTONE 16246.9 12413.7 18.1 18.1 0.010 101.6 41 WF Coal 16269.2 12431.8 11.2 .6 0.004 77.0 15 SILTSTONE 16282.9 12443.0 4.3 1.7 0.000 .0 0 DIRTY-SANDSTONE 16288.2 12447.3 4.3 3.4 0.000 .0 0 SHALE 16293.4 12451.6 8.6 .4 0.000 .0 0 SILTSTONE 16303.9 12460.2 17.2 6.9 0.000 .0 0 DIRTY-SANDSTONE 16324.7 12477.4 14.6 11.7 0.000 .0 0 SHALE 16342.4 12492.0 12.9 .6 0.000 .0 0 SILTSTONE 16357.9 12504.9 7.8 3.1 0.000 .0 0 SILTSTONE 16367.2 12512.7 8.6 3.4 0.000 .0 0 DIRTY-SANDSTONE 16377.5 12521.3 6.0 4.8 0.000 .0 0 10 0 • Client : Glacier Oil & Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock SHALE 16384.6 12527.3 13.8 .7 0.000 .0 0 West Foreland 16401.1 12541.1 42.2 42.2 0.000 .0 0 SHALE 16450.9 12583.3 4.3 .2 0.000 .0 0 DIRTY-SANDSTONE 16455.9 12587.6 3.4 2.7 0.000 .0 0 DIRTY-SANDSTONE 16459.9 12591.0 29.2 23.4 0.000 .0 0 SILTSTONE 16494.0 12620.2 14.6 5.8 0.000 .0 0 SILTSTONE 16510.9 12634.8 6.0 2.4 0.000 .0 0 CLEAN-SANDSTONE 16517.8 12640.8 10.5 10.5 0.000 .0 0 DIRTY-SANDSTONE 16530.0 12651.3 7.4 5.9 0.000 .0 0 DIRTY-SANDSTONE 16538.5 12658.7 12.8 10.2 0.000 .0 0 Exposure Time Prediction by Step Step Name Fluid Name Pump Fluid Perforation Exposure at Exposure Rate Volume Injection BHST of aboveWatch (bbl/min) (gal) Temp. 190 degF Temp.of (degF) (min) 185 degF (min) PAD YF127FIexD 20.0 10500 177 9.5 9.5 1.0 PPA YF127FIexD 20.0 1609 170 6.0 6.0 2.0 PPA YF127FIexD 20.0 1544 152 4.0 4.0 3.0 PPA YF127FIexD 20.0 1483 142 0.5 0.5 4.0 PPA YF127FIexD 20.0 1428 134 0.0 0.0 5.0 PPA YF127FIexD 20.0 1376 127 0.0 0.0 6.0 PPA YF127FIexD 20.0 1328 120 0.0 0.0 Flush WF127 20.0 9622 11 • • Client : Glacier Oil &Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay country : United States Loadcase : Lower Hemlock Section 5: Propped Fracture Simulation Results (1) ACL Fracture Profile and Proppant Concentration Plot FracCADE' Glacier RU-03AOil a Gas Lover Hemlock 31 Jan 2017 a„«u�Profile and Proppant Concentnation 12250 12300- _. ....,' c 0.0163• 0.0-0.1 .12 0.1-0.2 • 2 -- 0.2-0.3 •12 12350- 0.3-0.4 •'2 0.4-0.5 •12 0.5-0.6 •12 0.6.0.8 •t2 8 In 0.8.0.9 •12 I >0.9 Wet 5 12400- 12450- - 01 Fractures l Initiation MD=16120.1 r 8 3` 12500 9000 11000 -0.10 -0.05 r 0.05 0.10 0 100 200 300 Stress-ps ACL Wdth et Wellbore-In Fracture Hal length.0 (2) Treating Plot - Bottomhole Pressure — Surface Pressure — Total Int.Rate EOJ elv 11000 t _1. _. '20 10000 18 -18 9000 —14 8000 12 1 10 7000 3 3 -B 8000• 6 •4 5000 -2 • 4000 I ♦• 0 0 10 20 30 40 Treatment Tme-min 12 • • Client : Glacier Oil&Gas Schlumhorgcr Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 6: Fluid Descriptions Brine{8.47ppg 3%KCI} • M117,Potassium Chloride 249.00 lb/mgal WF127 • M117,Potassium Chloride 250.00 Ib/mgal • J891,Guar Polymer Slurry 6.30 gal/mgal • F103,EZEFLO Surfactant 1.00 gal/mgal • W054,Non-Emulsifing Agent 1.00 gal/mgal • M275,Microbiocide 0.50 lb/mgal • W054,Non-Emulsifing Agent 1.00 gal/mgal YF127FIexD • J891,Guar Polymer Slurry 6.30 gal/mgal • M117,Potassium Chloride 250.00 lb/mgal • F103,EZEFLO Surfactant 1.00 gal/mgal • U028,Activator 1.00 gal/mgal • J604,Crosslinker 2.00 gal/mgal • J475,EB-CLEAN Breaker 5.00 lb/mgal • W054,Non-Emulsifing Agent 1.00 gal/mgal • M275,Microbiocide 0.50 lb/mgal 13 • S Client : Glacier Oil & Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 7: Proppant Data Proppant Permeability is calculated based on the following parameters: BH Static Temperature: 190 degF Stress on Proppant: 9541 psi Propped Fracture Conc.: 1.00 Ib/ft2 Average Young's Modulus: 5.940E+06 psi Proppant Data Proppant Name Specific Mean Pack Permeability Gravity Diameter Porosity (md) lin) (%) 20/40 CarboLite(USA) 2.71 _ 0.029 39.1 100889 20/40 CarboBond Lite 2.61 0.016 43.3 174369 Proppant Permeability Plot Proppant Permeability 280000. Stress on Proppant 260000t 240000 220000 200000 180000 160000 z \\\ m 140000 ` 20/40 CarCarboBon(USA E _ s-, Prop tress and Ute Prop Stress o_ 120000 100000 80000 60000 40000 20000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Closure Stress(psi) 14 • • Client : Glacier Oil &Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Section 8: Hole Survey Hole Survey MD ND Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 93.0 93.0 0.0 0.0 0.0 0.0 0.0 177.0 177.0 0.3 0.3 275.0 -101.2 0.3 200.0 200.0 0.3 0.2 237.9 -161.4 0.8 267.0 267.0 0.8 0.7 202.0 -53.6 0.8 351.0 351.0 2.6 2.2 186.0 -19.0 2.3 446.0 445.8 4.5 2.0 180.0 -6.3 2.0 535.0 534.4 6.0 1.7 173.0 -7.9 1.8 624.0 622.8 7.0 1.1 164.0 -10.1 1.6 715.0 713.0 8.0 1.1 158.0 -6.6 1.4 827.4 824.0 10.0 1.8 148.4 -8.5 2.2 917.7 912.7 11.9 2.1 147.7 -0.8 2.1 1007.0 999.8 13.2 1.4 148.8 1.2 1.5 1097.3 1087.4 15.0 2.0 148.5 -0.3 2.0 1191.0 1177.6 16.4 1.4 148.0 -0.5 1.4 1288.4 1270.4 19.1 2.8 147.4 -0.6 2.8 1381.8 1358.0 21.5 2.6 147.1 -0.4 2.6 1475.2 1444.4 23.0 1.7 145.7 -1.5 1.8 1567.1 1528.3 25.3 2.4 145.4 -0.4 2.4 1657.4 1609.4 26.7 1.6 146.0 0.6 1.6 1752.1 1693.9 27.1 0.5 148.2 2.3 1.1 1848.0 1778.0 30.1 3.1 149.3 1.2 3.2 1944.3 1860.6 31.8 1.8 148.9 -0.4 1.8 2040.1 1939.9 36.3 4.6 148.5 -0.4 4.6 2136.0 2015.1 40.4 4.3 147.5 -1.0 4.4 2231.0 2087.6 40.1 -0.3 146.4 -1.2 0.8 2326.0 2160.0 40.6 0.5 146.1 -0.3 0.5 2421.1 2231.5 42.0 1.5 147.5 1.4 1.7 2514.3 2300.0 43.3 1.4 146.7 -0.9 1.6 2609.3 2368.8 43.9 0.5 145.9 -0.8 0.8 2703.6 2436.9 43.6 -0.3 145.6 -0.3 0.4 2798.3 2505.1 44.3 0.7 144.9 -0.8 0.9 2890.0 2570.9 44.1 -0.2 144.4 -0.5 0.4 2986.0 2641.0 42.1 -2.1 144.6 0.2 2.1 3079.4 2711.0 40.7 -1.5 144.9 0.3 1.5 3176.2 2782.9 43.4 2.7 145.2 0.3 2.8 3272.3 2852.9 43.1 -0.2 144.8 -0.3 0.3 3368.1 2922.9 43.1 -0.1 144.6 -0.3 0.2 3452.8 2984.4 43.7 0.8 144.6 0.1 0.8 15 0 0 Client : Glacier Oil &Gas Well : RU-03A Schlumberger Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Hole Survey MD ND Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 3507.0 3023.5 44.0 0.5 144.7 0.1 0.5 3560.0 3061.5 44.3 0.5 _ 144.8 0.1 0.5 3655.7 3130.1 44.1 -0.2 144.5 -0.3 0.3 3751.7 3199.3 43.7 -0.4 _ 144.8 0.4 0.5 3847.6 3268.8 43.3 -0.4 _ 144.6 -0.2 0.4 3944.0 3338.9 43.3 -0.1 143.8 -0.9 0.6 4040.0 3408.6 43.6 0.3 145.8 2.2 1.5 4136.1 3478.0 44.1 0.6 147.3 1.6 1.2 4231.0 3546.1 44.2 0.1 147.3 -0.1 0.0 4324.7 3613.2 44.4 0.2 146.7 -0.7 0.5 4419.0 3680.7 44.1 -0.2 146.5 -0.1 0.3 4514.1 3748.9 44.2 0.1 145.9 -0.7 _ 0.5 4606.3 3814.7 44.8 0.6 145.8 -0.1 0.6 4702.4 3883.3 44.1 -0.7 146.4 0.6 0.8 4797.7 3951.8 44.0 -0.1 _ 146.9 0.5 _ 0.4 4892.4 4020.7 42.6 -1.4 146.9 0.0 1.4 4988.1 4091.5 42.0 -0.7 147.4 0.5 0.8 5083.4 4162.4 41.9 -0.1 _ 146.4 -1.0 _ 0.7 5178.8 4233.4 41.9 0.1 146.6 0.2 0.2 0 y 5274.2 4304.5 41.7 -0.2 146.7 0.1 0.2 tv 5370.1 4376.2 41.4 -0.3 146.2 -0.5 0.4A 5466.1 4448.0 41.9 0.4 145.3 -1.0 0.8 5561.8 4519.4 41.6 -0.3 145.6 0.3 0.4 5656.1 4589.9 41.7 0.1 _ 145.8 0.2 0.1 5751.9 4661.5 41.6 -0.1 145.4 -0.4 0.3 5845.9 4732.1 41.1 -0.5 146.3 0.9 0.7 5939.5 4802.6 41.0 -0.1 147.1 1.0 0.6 6037.0 4876.3 40.8 -0.2 146.6 -0.6 0.5 6130.2 4947.0 40.6 -0.2 146.8 0.3 0.3 6225.2 5019.2 40.4 -0.3 146.5 -0.4 0.4 6320.7 5092.0 40.3 -0.1 146.2 -0.3 0.2 6415.1 5164.5 39.4 -0.9 146.8 0.6 1.0 6509.7 5237.8 39.1 -0.3 146.2 -0.7 0.5 6604.5 5311.4 39.0 -0.1 146.3 0.2 0.0 6700.2 5385.7 39.0 0.0 146.3 -0.1 0.0 6796.5 5460.1 39.8 0.8 147.8 1.6 1.3 6889.5 5530.8 41.3 1.5 148.0 0.2 1.5 6983.7 5601.2 42.0 0.8 147.7 -0.4 0.9 7077.7 5671.1 41.8 -0.2 148.0 0.3 0.3 7171.2 5741.0 41.4 -0.4 147.4 -0.6 0.6 7267.1 5813.0 41.3 -0.1 146.4 -1.0 0.7 16 i i Client : Glacier Oil &Gas Schlumberger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 7361.6 5884.2 41.0 -0.3 146.4 -0.0 0.3 7455.2 5955.0 40.7 -0.3 146.8 0.4 0.4 7549.2 6026.4 40.5 -0.3 145.9 -1.0 0.7 7643.6 6098.4 40.0 -0.4 146.0 0.1 0.5 7736.8 6169.8 39.9 -0.1 145.8 -0.2 0.2 7828.1 6239.8 40.0 0.1 145.3 -0.5 0.4 7922.5 6312.2 39.8 -0.3 145.9 0.6 0.5 8017.2 6385.1 39.6 -0.1 146.7 0.8 0.5 8114.2 6459.3 40.5 0.9 147.5 0.8 1.0 8215.4 6536.7 39.7 -0.7 147.5 0.0 0.7 8307.0 6607.3 39.6 -0.2 146.7 -0.9 0.6 8402.9 6680.9 40.1 0.6 146.2 -0.5 0.7 8497.3 6753.3 39.6 -0.5 145.8 -0.5 0.6 8592.0 6826.3 39.5 -0.1 146.2 0.5 0.3 8683.2 6896.8 39.1 -0.5 146.0 -0.3 0.5 8776.6 6969.6 38.6 -0.5 145.5 -0.5 0.6 8871.0 7043.8 37.7 -0.9 146.3 0.8 1.0 'D 8965.7 7119.0 37.2 -0.5 145.6 -0.7 0.7cD 9060.0 7194.5 36.4 -0.9 145.4 -0.2 0.9 -a 7 9156.7 7272.6 35.9 -0.5 145.7 0.3 0.5 <' .0 9233.3 7335.1 34.9 -1.3 144.9 -1.1 1.4 9275.9 7370.1 34.4 -1.0 145.0 0.1 1.0 9332.0 7416.5 34.0 -0.8 144.7 -0.5 0.9 9382.5 7458.4 33.6 -0.8 144.4 -0.6 0.8 9475.7 7534.6 36.8 3.4 144.6 0.2 3.4 9571.8 7609.8 40.2 3.5 145.6 1.1 3.6 9665.4 7680.1 42.5 2.5 145.8 0.2 2.5 9757.8 7747.1 44.5 2.2 146.0 0.2 2.2 9853.7 7814.6 46.0 1.5 146.6 0.7 1.6 9951.1 7882.4 45.8 -0.2 146.0 -0.7 0.6 9993.8 7912.3 45.4 -0.8 146.9 2.2 1.8 10044.3 7947.7 45.5 0.2 147.4 1.0 0.7 10139.8 8014.5 45.6 0.1 147.4 0.0 0.0 10236.0 8081.9 45.6 -0.0 147.8 0.4 0.3 10331.7 8149.1 45.3 -0.3 147.1 -0.7 0.6 10427.3 8216.1 45.6 0.4 146.7 -0.4 0.5 10521.4 8282.1 45.4 -0.2 146.8 0.1 0.2 10620.8 8351.9 45.4 0.0 147.2 0.4 0.3 10716.1 8418.7 45.5 0.1 147.3 0.1 0.0 10810.8 8484.8 45.9 0.3 146.9 -0.4 0.5 10907.1 8552.1 45.4 -0.5 146.9 0.1 0.5 17 0 • Client : Glacier Oil & Gas SChlem6erger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Hole Survey MD TVD Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 11001.9 8618.8 45.2 -0.2 146.2 -0.8 0.6 11091.3 8682.1 44.7 -0.6 145.9 -0.3 0.6 11188.7 8751.2 44.8 0.1 145.9 0.0 0.0 11283.2 8818.3 44.7 -0.1 145.8 -0.1 0.0 11374.8 8883.5 44.4 -0.3 145.4 -0.4 0.4 11469.5 8951.4 44.0 -0.4 145.2 -0.2 0.4 11563.4 9019.0 43.8 -0.3 145.2 -0.0 0.3 11657.8 9087.4 43.5 -0.3 144.3 -0.9 0.7 11751.9 9155.9 43.1 -0.4 144.4 0.1 0.4 11848.7 9226.2 43.6 0.5 146.3 2.0 1.5 11941.6 9293.6 43.4 -0.2 145.5 -0.9 0.7 12041.5 9366.3 43.2 -0.3 145.4 -0.0 0.3 12137.6 9436.6 42.8 -0.3 144.0 -1.5 1.1 12233.3 9506.6 43.0 0.2 143.7 -0.3 0.3 n 12325.2 9574.5 41.7 -1.5 143.1 -0.7 1.6 = 12420.2 9645.9 40.9 -0.8 141.6 -1.6 1.3 B 12517.4 9719.1 41.4 0.5 142.4 0.9 0.8 12609.3 9787.8 41.9 0.6 145.9 3.8 2.6 12704.1 9858.7 41.3 -0.7 145.1 -0.8 0.9 v 12798.5 9929.8 41.0 -0.3 144.3 -0.9 0.7 12894.1 10002.0 40.8 -0.3 143.4 -1.0 0.7 m 12989.7 10074.3 40.9 0.1 143.3 -0.1 0.0 13038.2 10110.7 42.0 2.1 145.5 4.6 3.7 13084.8 10145.5 41.6 -0.7 144.3 -2.7 1.9 13175.9 10213.6 41.5 -0.1 142.9 -1.5 1.0 13270.8 10285.2 40.4 -1.2 141.9 -1.0 1.3 13369.1 10359.5 41.4 0.9 144.2 2.3 1.8 13460.1 10428.7 39.8 -1.7 142.6 -1.8 2.1 13505.1 10463.4 39.1 -1.4 141.5 -2.4 2.1 13566.4 10511.1 38.7 -0.8 141.9 0.6 0.9 13659.2 10583.2 39.3 0.8 143.8 2.1 1.5 13755.7 10656.6 41.8 2.5 145.5 1.7 2.7 13848.0 10725.0 42.5 0.8 146.4 1.0 1.0 13942.2 10793.9 43.6 1.2 146.9 0.5 1.2 14040.6 10864.7 44.4 0.8 148.1 1.3 1.2 14135.4 10932.7 44.0 -0.4 147.4 -0.8 0.7 14229.2 11000.9 42.9 -1.2 147.0 -0.4 1.2 14323.9 11069.3 44.6 1.8 148.9 2.1 2.3 14362.0 11096.4 44.7 0.4 149.4 1.2 0.9 14378.0 11107.6 46.5 10.9 148.0 -8.6 12.5 14398.0 11121.4 46.5 0.0 148.0 0.0 0.0 18 . • Client : Glacier Oil & Gas Schlumbcrger Well : RU-03A Formation : Lower Hemlock District : Prudhoe Bay Country : United States Loadcase : Lower Hemlock Hole Survey MD ND Deviation Deviation Azimuth Azimuth Dogleg (ft) (ft) Angle Build Rate Angle Build Rate Severity _ (deg) (deg/100ft) (deg) (deg/100ft) (deg/100ft) 14400.0 11122.7 46.5 0.0 147.9 -2.5 1.8 14500.0 11191.7 _ 46.4 -0.1 145.2 -2.8 2.0 14600.0 11260.7 46.3 -0.0 142.4 -2.8 2.0 14700.0 11329.7 46.4 0.0 139.6 -2.8 2.0 14800.0 11398.7 46.5 0.1 136.9 -2.7 2.0 14900.0 11467.5 46.6 0.2 134.1 -2.7 2.0 15000.0 11536.0 46.9 0.2 131.4 -2.7 2.0 15100.0 11604.2 47.2 0.3 128.7 -2.7 2.0 15200.0 11672.0 47.5 0.3 126.0 -2.7 2.0 15300.0 11739.3 47.9 0.4 123.4 -2.6 2.0 15314.8 11749.2 48.0 0.5 123.0 -2.6 2.0 15400.0 11806.2 48.0 0.0 123.0 0.0 0.0 15500.0 11873.1 48.0 0.0 123.0 0.0 0.0 15600.0 11940.0 48.0 0.0 123.0 0.0 0.0 15689.7 12000.0 48.0 0.0 123.0 0.0 0.0 15700.0 12006.9 47.8 -2.2 122.9 -0.6 2.3 3 15800.0 12075.5 45.6 -2.2 122.3 -0.6 2.2 co 15900.0 12146.8 43.4 -2.2 121.6 -0.7 2.2 CD a 16000.0 12220.8 41.3 -2.2 120.9 -0.7 2.2 -o 16100.0 12297.2 39.1 -2.2 120.1 -0.8 2.2 w 16200.0 12376.0 36.9 -2.2 119.2 -0.9 2.2 m 16300.0 12457.0 34.8 -2.2 118.3 -1.0 2.2 16400.0 12540.2 32.6 -2.1 117.2 -1.1 2.2 16500.0 12625.4 30.5 -2.1 116.0 -1.2 2.2 16600.0 12712.5 28.4 -2.1 114.6 -1.4 2.2 16700.0 12801.3 : 26.3 -2.1 113.0 -1.6 2.2 16800.0 12891.824.2 -2.1 111.2 -1.8 2.2 16809.0 12900.0 1 24.0 -2.1 111.0 -2.0 2.3 19 • 0 eoaeoeseRee 12 :4:4 44 W m# W m Qq p8 O n m a C O O g O C e e OO O O g K o O O f i o N S Y m W N n f U mG �� U 0 N[p b � o J a> .e21 a > w • " n ii n n g www t It it .. U K 0 O F N <W<K m N f r,n~h ON)N' 0_ ;2 2 kill U- j U - C t U �sa '� E z d c m a Mil ! E :< N 6 . ^ O b*h"0 0 o m pc , .."—.,%41 O0d O o J -fi.1NN • � K n n = a a 1 ry n a U N 4 hSZ.-4°`"4'4 a < a u tin n nm HJObAhppA : . .-0 . £ £N mw> < - - - re EI w W o . m F j << `� U < '1.1 ''' ---(71.....0,11 Nclaa. RP Y b O W W O e o a L a rc a _ n m o o n n n n . . �� , . , . 02 . a t5a0on < j0oa$3o,$om •�wNp7wrc v-ih wmmui ws w — .¢a Q o O a z i z w i ` .. _ LL O O a o �F >j j O V . . m o . 0 LL 2 .3 w w a t . m a "(7(7 p ao z W ▪ `y E § .- a Q w J �w >� z qr lmogm' O z3 3^E�$$w m 3 gg g °c a tom :�l Z�aid me�wwwa a. 4.m K N 2.:n: 2.g. g _ri�n a a3 z m L �� ! I 3 <m o` g O <O p p p p p p N g < c o o Cc '� A rm N r o,3g3SSS 92 - r a >? rc r 0 o w .6.. ? V a m a 0 a ,,0 0 0 ffi 4.o o r o a m o w ;1 nr <mo .'.N ,oo ... N E a � �a _ e U M. RR �� RRRRRRRR p a v_, BB 1 13, 2 00 ' :▪m n L a 1g r ~ I r o a = o eo W 0 r...�-r y — - a l E 5 '4 E 1 <53555 = Ec f Y A3q 7 a E 8- U Z 1 i a 1 U o M - -- - :la i m <r fZa > = NMOWW F22Wv Y ry C rt o. < < 05113V-`- it nm «sqa e a 22 N N a 02 2 y - 9 m 2 Y, n ` i E a s 0.. ,. - E m- O 2 W. a N.+ 9 . o�norroman c i. - j, .d n z o o ; ' E F E q . " � a' oa'in • r ,-- 45 ECD C cm O O OQ C L CO CI. 0 U > itz, x FL...i > -. lion JaPuale • CD mL.J 0 0 6 1--o-o-- -U{} .--00-. • S Schiumberr Schlumberger Oilfield Services Y- 6411 A Street Anchorage AK 99518 USA Tel: 1-907-273-1780 Fax:1-907-561-8317 Organization and Support Structure: Schlumberger Well Services is structured to mare than adequately to support the work required by Cook Inlet Energy. We are by far the largest provider of Fracturing services in Alaska and have the proven ability to mobilize experienced people and equipment to any location in Alaska via land transport,offshore platform,or ice road. We will provide personnel to fill the following positions: (1)Field Supervisor-Manages crew/calls the job (1)Field Engineer-Tests fluids and proppant,QC's equipment,provides reports (1)Pump Operator-Controls high pressure pump rates (1)Line Boss-Manages fluid movement through lines,actuates SLB valves (1)POD operator-Operates sand and water blender (1)LAS operator-Operates liquid additive pumps (1)C-Pump Transfer Operator-Operates C-Pump to supply linear gel to POD Blender header tank (1)Silo Operator-Operates sand Silo and is a POD assistant (1)Electronic Technician-Supports SLB equipment (1)Mechanic-Supports SLB equipment Organization Chart AKA Pressure Pumping Services.Fracjurin, rvices: QSerdltilE , �1� K1eerMY 016E Twm r., MiUmrreee... 1 K.Perkins 55 ..,., LOlfnp ....... L..,rr� G.eutrinPr 111.14 maw, ,..... ]1 iordar 1110 rnatum. sAismYd sD'"'" CENOssimil 1 1 [ riII t Slope Pela !�H/i gnaw. iP11 MO.* d OA wwe wpparl i 10 s S Schlumberger Oilfield Services Schlumberger 6411 A Street Anchorage AK 99516 USA Tel. 1-907-273-1780 Fax 1-907-581-8317 Fit for Purpose Equipment Specifications: Equipment listed below is described in their own specifications sheets included in this proposal. • 3 x SPS 343—3 plunger(Triplex)stimulation pump is a skid mounted pump designed for high horsepower applications. Available with: a. 2000 HHP each a. 4.5"inch fluid end—capable of 6 bpm at 12,500 psi(MAWP 15000 psi) • 1 x SBS-614—Programmable Optimum Density(POD*)Blender is a skid mounted blender capable of blending and pumping up to 35 bpm of proppant laden fracturing fluid a. 1 proppant blending system—automated operation with manual backup b. Maximum proppant delivery is up tc 9,000 lbs./min c. Suction flow meter d. 1 dry additive system • lx FracCAT monitoring unit—fully enclosed skid used to monitor,control and display stimulation treatments in a controlled environment a. FracCAT Software b. Automatic control of POD blender c. Automatic control of pumps d. Acquisition center for treatment sensors(density and pressure) e. Field Lab with breaker testing and water analysis capabilities • 1 x Liquid Additive System(LAS)-Supplies liquid chemicals to suction or discharge side of POD blender. This unit is supplied with 14)pumps with(2)operational and 12)for backup.The FracCAT unit records rate, calculates concentration,and totalizes the total chemical volumes added. Existing Facilities Schlumberger is the only company that has provided continuous Pumping Services in Alaska for over 30 years.At Schlumberger,we have the people and the experience to provide the high level of safe,quality service that the Caelus Energy organization expects. The facility has: • The only fully functional Laboratory on the North Slope,with X-ray analysis of scale samples,cement slurry and fracturing fluid QC • Main shop with four maintenance bays for our pumping services equipment • Environmentally friendly recycling and filtration wash bay • Bulk Acid storage and blending facility on the North Slope • Bulk and blending facility,with drive on State certified truck/trailer weigh scale on the North Slope.The facility is permitted for operation through the Department of Environmental Conservation(ADEC) Schlumberger Oilfield Services Schlumberger 6411 A Street Anchorage AK 99518 USA Tel: 1-907-273-1780 Fax:1-907-561-B317 Laboratory The Well Services laboratory in Prudhoe Bay is a state of the art field laboratory.It has the capacity to handle large volumes of testing and special requests simultaneously.This laboratory runs preliminary and QA/AC testing for Cement,Fracturing and Acid crews. The Laboratory contains: •Two Chandler Precision Controlled Mixers/blenders •Three scales with precision down to 0.0001g. •Seven Fann 35 rotational viscometers—to measure viscosity •One Brookfield viscometer—to measure fracturing fluid viscosity •Four computer automated Chandler 5550 viscometers for fluid viscosity Some of the tests that are routinely run are listed below. Stimulation •Perform fracture fluid breaker testing per API spec •Test hydraulic fracture proppantto API spec solubility,sphericity,roundness. •API water analysis •Acid crude compatibility,breakout,sludge test •Acid iron concentration •TAG open and closed flash testing •Reid vapor pressure testing of volatile fluids •X—Ray Diffraction to identify unknown scale • 0 Schlumberger schh.,h.,.,Wield Swims 6411 A SOW Anchormen 99518 USA Tel 1-907-Z73-1780 Fax:1-907-5614317 Quality Assurance/Quality Control lOA/QC1 . Key !Service F-racturitig 'Quality Requirements , vkiilriAlti t „ .„ . ...„.., 1.114214146.11Woollo;. .:•::-....-:-.-• 1koo4044 ,.;''.•' , J.! kilradooper v..:27 e:s. fr.,4t1 Os prep*1141.4 fachabirs(111 Nis sod meld". 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A gaol.**proud,*SitoltstiOn.**4 5•44cs bassitycombhoosendem studs%asiarwat 284xio eau Ow. .- 34 Addeo INOI)Woo ropolood 42 2.7 verity Acqjiltion iii4 C.rwm!kativtlCiaingloloParatkooew Ji ‘..'rt*iii011101. .....-.......ist Om adv.;siorawdrice Fout.0 laws!Anto441;.-; .•- ,o.posztois k...1.....-4 WE.listedvitookrm .....* --.... « 24 Polo"um*Watson*deft*OW IX' ,.-: -:.-'• , JS Mr Oo 4114 kW*111%**le 1,1100141 OW',V,'i',..;,-,i^L- .,.-.................-..-----......-...—...............,.......-..-• 28 Mini*pals,6404 mpotried job sten My. 5$ IV Perkin opvatims mitIrgrislAb ialliti! 42 «... - - ...... ... . . -...— -- - . -.....----...... 1 fokslio looksook 114404A1644 72 raw Evikstian bed Ewa 1***22g 1.44 S..4 le.k St mit,it Iltitt,.*Ntep*ir Ida yo t t[wt.:...,. *topic*0 iktmt*et elittri qv:***Met p*Vttforeite.Ct&Id likst a ei,os.ot...,,,s oq 1,,,,,%vet eel Woo ic ex.,*V Mt athrtuect limn a:Lill ..-.. ......... ........ _ _.... ... ...... . .___.. _ _ . . . . . - . 34 6ith ups*toiireek frotA0P. jr4 Mir orifoce.471robk.4041,74sA it*IOW Oa!k_Le sik.-44:k 02 1 1dA 1.42 li..........., . ., I- 1.K;s ,. ,..s. . • i , h. • • Schlumberger Oilfield Services Scrdumberger 5411 A Street Anchorage AK 99518 USA Tel 1.907-273-1780 Fax:1-907-561-8317 KSQR Fracturing Services,Fracturing KSQR systems are outlined above.For Fracturing Services,Schlumberger has a comprehensive DA/QC system in place.The system is a combination of the Key Service Quality Requirements,the appointment of a Service Quality/Safety coach and the use of a Laboratory system designed to provide quality control/quality assurance of fracturing products. KEY SERVICE QUALITY TESTING REQUIREMENTS-FRACTURING Prior to any hydraulic fracturing treatment,the Minimum Service Testing Guidelines provided in the"Key Service Quality Testing Requirements-Fracturing"must be followed.This will ensure the product quality.Tests should be performed at the district laboratory,in advance of the treatment,and repeated on location,as required. Standards and Practices It is each employee individual responsibility to adhere to Schlumberger's Standards and Practices.These Standards apply to everything we do in providing services to our client from convoying equipment and products to location to wrapping up the service and returning the well to production or injection. QUEST QUEST is Schlumberger's QNSE data capturing and reporting system.The QUEST system captures all of Schlumberger's service quality and safety data. Once inputted into the system,QUEST tracks action items and sends reminder emails to ensure that unresolved issues are recognized and acted upon in a timely manner.Adherence to this system is ingrained in the Schlumberger culture and thus carries over in to our everyday work activities. Maintenance QA/QC Program Our Alaska maintenance group has one the highest levels of experience of any Schlumberger location.Every Technician is enrolled in Schlumberger's Structured Career Development Process that includes continued education through internal&external technical training sessions and training skill sets assigned by a mentor. We have a Computer Based Maintenance Management System(MAXIMO),which is a server-based application with a central database with all the company's equipment including all the fluid pumps,trucks,CT units,nitrogen units, etc.This central database configuration enables anyone to use this system to generate reports and look at trends to minimize down time for all the company's equipment The system enables: • Predictive and preventive maintenance scheduling • Tracking all inspections,repairs and a Inventory management. Structured Preventive Maintenance All equipment is scheduled for inspection every 400 hours or 180 days regardless of activity,including: • Annual third party inspection of cranes • Biannual third party inspection of all lifting equipment. • • SPS-343 Stimulation Pump Skid High-Pressure Pumping System, Radiator Cooled iii 1 till �i t ip '111;011 rfr - Ir' t Nil: illilierilir_ Aldr-.1". Alt Wier MIN I so rat 1!■41 11 ,, -, imossiviewmillivaff cry+ ,j The SPS-343 Stimulation Pumper Applications Equipment is a skid-mounted fracturing service pumping unit designed for high-horsepower applications. • Pumps up to 20,000 psi or up to • Caterpillar 3512B twelve The triplex pump delivers 25 BPM, depending on fluid-end cylinder deck engine rated at fracturing fluids to the well at high size. 2250 BHP 1900 rpm. pressure and rate. • Electronic controlled engine • Allison S9810M transmission gives maintenance and trouble- with eight'gear locked out. The unit can be delivered with shooting information. any of the Dowell - "OPI" style • 8' stroke HD-2000 Power-end fluid-ends. depending on the rate • Provides a remote control panel, with available fluid-end sizes and pressure requirements in the which may be located up to 120 3.75", 4.5", 5", 5.5", 6.5", or user's market. It is equipped with feet away from fracturing skid. 6.75"diameter. a remote panel allowing control of Skid can be split in three pieces • 3-piece DNV 2.7-1 designed the fracturing job from up to 120 for easy transportation on and skid and crash frames. feet away. The panel allows gear offshore. selection, throttle control, and • Radiator cooling for maximum emergency shutdown to be versatility. performed. *A Mark of Schlumberger ■P. ■■ 5rr,200G Sehlu erger • • SPS-343 Stimulation Pump Skid General Specifications Part Number 100305352 Deck Engine Caterpillar 3512B-2250 BHP @ 1900 RPM Deck Transmission Allison S9810M,7 gears Ambient Rating -5 DegC to 48 DegC Dimensions: Length Overall 27 ft.-3 in. [8.30 m] Height 18 ft.-6 in. [5.63 m] Width 8 ft.-11 in. [2.70 m] Total Weight 73,194 Ibm[33,200 kg] Engine skid(W x L x H) 8-ft.-11 in. [2.70m]x 15-ft.-9 in. [4.80m]x 11-ft.-6 in. [3.50m] Engine skid weight 35,715 Ibm[16200 kg] Pump skid(W x L x H) 8 ft.-11 in. [2.70 m]x 10-ft.-2-in. [3.09m]x 11-ft.-6 in. [3.50m Pump skid weight 25,353 Ibm[11,500 kg] Radiator skid(W x L x H) 8 ft-11 in. [2.70 mJ x 15 ft.-9 in. [4.80 m]x 7 ft. [2.14 m] Radiator skid weight 12,125 Ibm[5500 kg] Deck Load 12,5 PSI(from the two longitudinal I-beams only) Fuel tanks Two,each 160 Gal Utilities Consumption: Air for starting 100 psi Fuel 107 Gal/min(maximum) Triplex Pump Model HD-2000 Type 8 inch stroke Reciprocating Triplex(Gear Ratio-6.353:1) Hydraulic Horsepower 2000 HHP Fluid End EOPI(4.5") Maximum Pressure 15,000 PSI Maximum Rate 11.4 BPM Fluid-Ends Available FOPI(3.75"), EOPI (4.5"), HOPI (5"), IOPI (5.5"), UOPI (6.5"), ]JOP1(6.75") - g *A Mark of Schlumberger ..J2 Schfnnberper . III SPS-343 Stimulation Pump Skid Horsepower Performance-HD-2250 ENGINE:3512B(2250BHP)-TRANSMISSION:S8810M-FLUID END:4-112" 17500 i ENGINE . f Caterpillar 35129 4 2260 BNP 1 ®,900 pn let 3rd 'Er Max Pressure 16,000 Kilter Field End 15000--<..-:;c•:;<..< >-- — — — — -- ! TRANSMISSION 2nd . ALLISON 586101.1 • ) Converter.T01060a RATIOS:tat Ger3.5 Zednr.3.5O1 E 4th Id Grar.1.9, p 12500 r'•�� . — 41h Geer:1.43 54 _ — 41h_ Slh Gear.1.00 .� 2000 MHP 61h Gear.0.74 Pum >K 1400-1900p rates OD-1900 Engine 711 Gear:0.60 16 . '�`'�r'�`-Ir,�\1 PE 1pp(,bEWE-GO HOP1r50-4-1t2" PLUNGER SIZE 'e 6th ---4......„, ' PLUNGER-r STROKE-6.353 INTERNAL O I a ,II • GEAR RATIO l I _ -330 RPM MAX AT MAIN SHAFT 75C0 { { i 1 - _. ._ 'MX P.6.1.15,000 NNS IMMI 12.6 . . .VOLUMETRIC EFF.97% 5000 I ! I 200 3.00 4.00 5.00 5.00 7.00 8.00 0.00 10.00 11.00 1203 Rate(BPM) A Mark of Schlumberger °°` Schlumberger • • Schiumberger SBS014 Stimulation POB Blender Skid Note:The photograph may not be exactly representative of current production;be sure to review the specifications. APPLICATIONS • Blends and pumps up to 35-bbl/min fracturing slurry F , %INA • Controls solid to liquid ratio precisely with I !`"141011111,' it designated values I �•4 ' ' • Runs in full automated mode with : y 1 .�setpoints provided by operator or host ii _ ce �' system P;ipp[ -{r a 11 • Communicates with FracCAT for remote $' ; control al I FEATURES • 400 bhp diesel engine 1 • POD*(Programmable Optimum Density) {71 ' I -, i 1' t computer control systemI , • Mechanically-driven vortex mixer (` (� le • • Distributed control hardware for + : automated operation with manual backup411,4 • DNV 2.7-3 certified crash frame r Integrated Dry Add feeder with 1 interchangeable feed screws • PropNET'fiber feeder • Suction flowmeter on process fluid flow stream SBS-e14 Stimulation POD Blender Skid • Radioactive densitometer for proppant The SBS-614 Stimuiaticn POD Blender Skid is a skd-mounter;fracturing service densities(available separately)' blender which is capable of blending and pumping up to 35 bbl/min of fracturing 10ueto radioactive source and handling restrictions,the slurry,The POD(Programmable Optimum Density)computer precisely controls the radioactive densitometer Is not provided efton ordering solid to liquid ratio at designated values throughout the entire job in both ramp and unit-Order the rat;ioactivedenstometsrIP/h159 00) stair step modes. from PPCU. The blender consists of a 5.56-m'/min [35-bbl/min] vortex mixer and does not need an averaging tub.Additionally,an auger is not required to add the proppant because gravity works for the mixer,not against it.The maximum discharge pressure is 100 psi[6.8 bar]. A cnmputer-cnntrnlled integral tjate metmrs the amount of sand added to the slurry from the sand hopper.The skid mixer hydraulics are powered by a 400-bhp diesel engine. www.slb.com `Mark of Schlumberger Other company,product,and service names are the properties of their respective owners. Copyright©2515 Schlumberger.All rights reserved. �t i SBS-614 Stimulafloo POD Blender Skid General Specifications Engine Detroit Dieser Series 60 6063MK74-400 bhp at 2,100 rpm Fuel Consumption 20.6 galUS/h 78 L/h Hydraulics Parker®PAVC variable displacement load-sensing system Skid EN 10025 carbon steel frame construction Skid(combined) Length 225.5 in 5,728 mm Width 72 in 1,829 mm Height(shipping) 102 in2,590 mm Height(operational,handrails 132 in 3,353 mm installed) Weight(dryl 24,200 Ibm 11,000 kg Auxiliary Hydraulics 18 galUS/min at 137.9 bar 68.14 L/min at 2,000 psi Fuel Capacity 60 galUS 227 L Vortex Mixer Sand Gate Type integral Maximum Discharge Pressure 100 psi 6.8 bar Maximum Sand Rate 9,000 Ibm/min 4,090 kg/min Maximum Slurry Rate 35 bbl/min 5,564 1/min Inlet Connection 8-in WECO®FIG206 Winged-Male Sub(1) Outlet Connections 4-in WECO F1G206 Female Sub(3) Additive System Dry Add(1) 0.019 to 0.766 ft/min 540 to 21,700 cm'/mm PropNET Fiber Feeder(1) 10 to 200 Ibm/min 4.5 to 90,7 kg/min Other Gauges Available Dual-scale or user-configurable between metric and imperial units,e.g.,Yokogawat flowmeter Control System Distributed microprocessor-controlled system Cooling System Standard radiator(1) Skid Certified offshore skid designed to DNV 2.7-3 Ambient Rating 23 to 118 degF -5 to 48 degC Certifications Crash Frame Certification DNV 2.7-3 Engine Emission Certifications US EPA Non-Road Tier 2 EURO Non-Road Stage II IMO MARPOL 73/78 Annex VI 'Mark of Schlumberger www.slb.com Other company,product and service names are the ht02015 chlumf their respective owners, Schlumberger Copyrightflci 2075 Schlumberger.All rights reserved. V1.D 12 Mar 2075 • • GLACIER RU-3A(P6)Proposal Geodetic Report SWMin. (Det Plan) Report Date: December 13,2016.02:09 PM Survey I DLS Computatioe. Minimum Curvature/Lubinaki Client: Glacier 0118 Gas Ve3icel Section Azimuth: 127.103°(Grid North) Field: Redoubt Unit Vertical Section Origin: 0.000 6,0.000 ft StrWellcture/Slot. RU-3 Osprey PleNorm/13-616(6 vm: KB ation: 90.000 ft above MSL Borehole: RU-3A Feffl�gibility$tll� TOD Reference Elevation: Elevation: 45.000 ft below MSL APP: 507332060401 Magnetic Declination: 16.102° Survey Name: RU-3A(P6) Total Gravity Field Strength: 1001.3388m9n(980665 Based) Survey Date: December 13,2016 Gravity Model: DOX Tort/AHD I DDI/ERD Ratio: 191.649°/10360.393 ft/6413/0.803 Total Magnetic Field Strength: ' 55389.769 nT Coordinate Reference System: NAD27 Alaska State Plane,Zone 04.US Feet Magnetic Dip Angle: 73.610° Location Lat/Long: N 60°41 43.68699°.W 151°40 1460029' Declination Date: December 31,2016 Location Grid N.Y/X: N 2449933.264 0US.E 200627.483 SUS Magnetic Declination Model: BGGM 2018 CRS Grid Convergence Angle: -1.4670° North Reference: Grid Nath Gdd Scale Factor: 1.00000199 Grid Convergence Used: -1.4570° Version/Patch: 2.10.254.0 Total Corr Meg North-9Grid North: 17.5594° Local Cwrd Referenced To: Well Heed Comma. MD Incl Azim GTVDSS TVD VSEC 449 EW TF DLS Directional Exclusion Zone Exclusion Zone N GwMaO Th Northing Eaeting An (ft) C) (°)) OE IR/ (0) 00 OE 0 C/1000) Dliflculty Index ANd a,1 (nT) (NUS) (595)flUa) RTE 0.00 0.00 0.00 -90.00 0.00 0.00 0.00 0.00 OM N/A 0.00 18.39 15829.98 2449933.25 200827.48 93.00 0.00 0.00 3.00 93.00 0.00 0.00 0.00 276M 0.00 0.00 16.39 15830.19 2449933.25 200827.48 177.00 0.25 275.00 87.00 177.00 -0.16 0.02 -0.18 237.88M 0.30 0.00 16.45 1588243 2449933.27 200627.30 90' 20080 0.310 197.88 11000 100.00 412 .001 428 20280 060 000 1062 1684013 144989324 200617.20 267.00 0.75 202.00 177.00 267.00 -0.17 -0.51 -0.60 1813M 0.80 0.00 17.14 16322.86 2449932.74 200626.88 351.00 2.60 188.00 260.96 350.96 0.96 -2.92 -1.00 180M 2.26 0.98 18.94 17903.52 2449930.34 200628.48 448.00 4.50 180.00 365.77 445.77 4.32 -8.79 -1.23 173M 2.04 1.84 20.72 19601.95 2449924.47 200626.25 635.00 6.00 173.00 444.40 53440 9.68 -16.90 -0.66 50.071 1.83 2.06 21.99 20738.12 2449916.38 200626.82 624.00 7.00 164.00 532.83 622.83 17.24 -26.73 1.40 41.071 1.60 2.33 22.65 21242.33 2449008.53 200628.88 715.00 8.00 158.00 623.05 713.05 27.11 37.93 6.30 41.161 1.39 2.66 23.11 21743.42 2449895.32 200632.78 827.38 10.04 14842 734.04 824.04 42.95 -53.53 13.36 4.53L 2.26 2.82 24.15 22683.20 2449879.73 200640.84 917.68 11.82 147.70 822.68 912.68 59.01 -68.12 22.47 11.02R 2.09 3.00 25.70 24020.77 2449805.14 200649.96 006.98 13.20 148.79 909.64 999.84 77.12 -84.63 32.68 2.481 1.48 3.14 28.93 25091.62 2449848.62 200880.16 097.28 16.01 148.49 997.42 1087.42 97.69 -103.42 44.13 5.371 2.01 3.29 28.51 26900.91 2449829.83 200671.62 190.98 16.30 148.04 1087.62 1177.62 121.21 -124.96 67.40 4.21 1.45 3.41 29.87 27420.31 2449808.29 200684.94 288.38 19.08 147.43 1180.39 1270.39 148.98 -160.02 73.29 2.871 2.80 3.55 32.06 29404.03 2449783.23 200700.78 381.78 21.49 147.10 1268.00 1368.00 179.35 -177.26 90.81 18.911 2.68 3.88 34.22 31158.18 2449758.00 200718.29 475.18 23.05 145.74 135443 1444.43 21276 -206.73 110.40 3.731 1.76 3.78 35.46 32144.06 2449726.62 200737.88 567.08 25.28 145.40 143827 1528.27 248.44 -237.76 131.67 10.418 2.43 3.88 37.48 33711.98 2449695.49 200769.15 ' 857.38 28.70 140.08 1519.43 1608.43 285.94 -270.45 163.97 68.479 1.60 397 38.90 34788.94 2449662.81 200781.45 752.08 27.16 148.16 1603.87 1893.87 326.24 308.44 177.27 10.670 1.16 4.04 39.66 35359.78 2449626.82 200804.76 847.98 30.14 149.26 1688.02 1778.02 368.96 345.73 201.12 6.91 3.17 4.14 42.66 37546.20 2449687.52 200828.60 • 944.28 31.84 148.89 1770.68 1880.58 414.94 388.27 226.80 3.141_ 1.78 4.21 44.22 38839.21 2449544.90 200854.08 2040.08 36.26 14848 184993 193993 484.81 -434.08 254.48 8.391 4.62 4.32 48.37 41416.39 2449490.18 200881.96 135.88 40.40 147.54 1925.14 2015.14 520.37 -084.50 288.00 110.721 4.36 4.41 52.19 43772.38 2449448.76 200913.48 2230.98 40.13 146.41 1997.64 2087.64 678.11 -535.98 319.46 20.12L 0.82 4.47 61.73 43497.77 2449397.28 200946.94 2326.98 40.81 148.14 2070.01 2160.01 636.23 -587.16 353.62 32.786 0.64 4.52 62.14 43743.90 2449348.10 200981.11 2421.08 42.00 147.47 214145 2231.45 905.32 -639.88 387.98 22.331 1.73 4.57 53,72 44683.88 2449293.57 201016.48 2514.28 43.34 148.67 2209.98 2299.98 754.90 -692.70 422.32 45.121 1.65 4.62 54.80 46310.90 2449240.56 201049.80 2609.28 43.86 145.92 2278.78 2368.78 816.6 -747.20 458.88 142.79L 0.77 4.67 65.22 45512.06 2449186.06 201086.16 2703.58 43.57 145.60 234693 2436.93 878.31 -801.07 495.34 36.141 0.39 4.71 64.88 45324.74 2449132.18 201122.83 2798.28 44.28 144.86 2416.14 2505.14 940.74 355.03 632.81 115.731 0.93 4.76 65.43 45625.62 2449078.22 201100.29 2889.98 44.12 144.38 2480.88 2570.88 001.70 407.18 690.83 176.416 0.40 4.78 65.18 46490.82 2449026.10 201197.31 2886.98 42.09 144.57 2550.97 2640.97 064.31 -980.54 607.94 171.46 2.12 4.82 53.27 44409.96 2448972.71 201236.43 3079.38 40.71 144.89 262103 2711.03 123.18 -1010.97 043.61 3.99R 1.49 4.88 62.00 43608.16 244892229 201271.09 3176.18 43.37 145.16 2692.91 2782.91 184.84 -1084.08 880.76 137.71 275 4.91 54.61 45173.66 2448889.17 201308.24 3272.28 43.13 144.84 276291 2862.91 247.60 -1118.02 718.53 106.41 0.34 4.93 54.32 46010.63 244881523 201340.01 3368.08 43.08 144.69 2832.86 2922.85 309.90 -1171.46 766.34 3.099 0.19 4.96 64.22 44967.16 2448781.80 201383.82 3452.78 43.72 144.84 2894,39 2984.39 365.40 -1218.90 790.04 10.41R 0.78 4.98 54.85 45308.05 2448714.35 201417.52 134, 350700 44.01 144.72 293.40 302949 401.22 -1240.56 611.76 10.808 0.54 600 5814 45470.11 2446663.70 20143920 366.02 4429 144.79 2971.53 3061.53 438.41 -1279.72 833.08 127.421 0.54 5.01 55.42 45627.48 244865364 201460.58 3655.72 44.12 144.47 3040.13 3130.13 500.03 -1334.13 871.70 147.566 029 5.03 5520 45504.32 2448599.13 201499.18 3751.72 43.74 144.82 3109.27 3199.27 583.54 -1388.45 91024 100.811 0.47 5.08 54.90 46339.32 2448544.81 201537.72 3847.6 43.35 144.02 3178.78 3268.78 628.51 -144238 948.40 90.181 0.43 5.08 64.49 45109.03 2448490.87 201575.88 3944.02 43.29 143.77 3248.92 3338.92 680.72 -1496.02 987.09 6.019 0.61 5.10 5427 44985.54 244843724 201614.57 4040.02 43.58 145.84 3318.64 3408.64 762.68 -1549.94 025.12 63.356 1.51 5.13 54.92 45351.25 2418383.31 201652.6 4136.12 44.09 147.33 3387.98 3477.98 815.31 -1806.49 061.76 23.641 1.21 5.15 55.71 45784.36 2448327.77 201689.24 4231.02 44.17 147.28 3456.09 3646.09 877.32 -1861.09 097.45 68.621 0.00 5.17 55.77 45821.90 2468272.16 201724.93 4324.72 44.36 146.66 3523.19 3613.19 938.83 -1716.92 133.10 157.641 0.50 5.19 56.84 45880.00 244821733 20176.58 441902 44.14 148.53 3590.74 3680.74 2000.88 -1770.85 16933 80.371 0.25 6.20 56.61 45731.83 2448162.40 201796.81 4514.12 44.22 145.87 3658.94 3748.94 2063.49 -182593 206.20 6.761 0.49 6.22 55.58 46707.27 244810733 201833.68 4806.32 4478 145.78 3724.70 3814.70 2124.6 -1870.40 242.49 148.989 0.61 6.24 50.09 46992.76 2448053.86 201869.97 4702.42 44.11 148.37 3793.31 3883.31 2188.33 -1935.23 26.04 106.93R 0.82 6.26 65.65 46701.26 2447998.02 201907.63 4797.72 44.01 146.88 3881.79 3951.70 2250.79 -1990.58 316.60 179.729 0.39 6.27 55.55 45700.57 2447942.68 201943.98 4892.42 42.64 146.89 3930.88 4020.68 2311.03 -2045.00 362.00 165.556 1.45 5.30 54.23 44967.51 244788825 201979.48 4988.12 41.95 147.36 4001.47 4091.47 2372.44 -2099.09 388.98 98.051 0.79 531 53.65 44838.09 2447834.17 202014.44 5083.42 41.90 146.36 4072.40 4162.40 2432.34 -2152.38 421.76 71286 0.71 5.33 53.38 44484.41 2447780.87 20204924 5178.82 41.91 146,58 4143.42 4233.42 2492.43 -2205.48 456.94 156.79 0.16 5.34 53.47 44535.78 2447727.78 202084.42 6274.22 41.74 146.69 4214.52 4304.52 255238 -2258.61 491.92 138.231 0.19 5.35 53.33 44453.50 244787465 202119.41 5370.12 41.43 14624 4286.26 437626 2812.44 -2311.6 527.09 6.11 045 5.37 52.95 44233.42 2447821.59 202154.57 5468.12 41.86 14529 4357.98 4447.98 2672.87 -2364.40 662.98 139.939 0.80 5.38 53.18 4437223 2447588.85 20216.46 6661.82 41.60 145.62 4429.40 4519.40 2733.33 -2416.87 699.10 84.850 0.38 5.39 53.00 4428321 2447516.38 202226.58 5666.12 41.66 146.81 4499.89 468989 2792.70 -2488.63 634.39 110.761 0.15 5.41 53.09 44317.62 2447484.62 202281.87 5761.92 41.57 145.45 4671.51 4861.61 2853.03 -2621.16 670.30 130.719 0.27 6.42 52.93 44229.09 2447412.11 202297.79 6845.92 41.12 146.26 4642.08 473208 2911.83 -2672.53 705.16 90.999 0.74 5.43 62.65 44062.71 244736.72 202332.85 5939.62 41.03 147.16 4712.64 4802.64 296.76 -2623.93 738.93 120.57L 0.84 5.44 52.73 44107.92 244730932 20236.41 6037.02 40.80 140.65 478832 4876.32 302986 -2077.40 773.84 130.33R 0.47 5.45 62.40 43814.80 2447255.86 202401.33 6130.22 40.64 146.84 486.96 4946.96 3087.14 -2728.21 67.23 140.851 0.27 5.47 62.30 43855.34 2447205.04 202434.71 6225.22 40.37 146.50 4929.19 619.19 3146.28 -2779.76 841.13 118.11 0.37 5.48 61.97 43685.41 2447153.49 202488.62 620.72 40.26 146.18 6002.01 6092.01 3203.82 -2831.19 87638 158.4R 0.25 5.49 51.81 436618.29 2447102.06 202502.88 6415.12 39.39 146.78 6074.51 5164.51 326.65 -2881.6 908.77 127.6551 1.01 5.50 51.08 43130.40 2447051.68 20253825 6509.72 39.09 146.16 5147.78 5237.78 3317.11 -2931.48 941.82 120.82R 0.52 5.51 60.6 42887.51 2447001.78 20266.30 8604.52 39.03 148.32 5221.39 5311.39 337384 -2981.14 975.02 75.21 0.12 5.62 50.66 42870.35 244652.11 202602.6 676.22 39.04 146.28 5295.73 5385.73 3430.47 3031.28 2008.47 61.320 0.04 5.53 50.6 42870.13 2446901.98 202635.96 676.52 39.84 147.6 6370.10 546.10 3487.97 -3082.6 2041.75 6.14R 1.31 5.54 61.70 43502.48 2446850.85 20266.24 6889.52 41.25 148.03 6440.77 5530.77 3544.48 3133.82 2073.88 16.61 1.62 5.58 6.10 44328.07 2448799.43 202701.34 6983.72 42.04 147.6 5511.16 5801.16 3603.01 3186.82 2107.16 141.909 0.87 6.57 6.80 44732.25 2446746.43 202734.65 7077.72 41.81 147.96 5581.10 5671.10 3681.78 -3239.09 2140.61 136.621_ 0.31 6.58 53.62 44633.43 244689327 202788.09 7171.22 41.40 147.37 5651.01 5741.01 3719.88 -3292.44 2173.81 10129L 0.61 6.69 6.12 44345.13 2440840.81 20261.30 7267.12 41.28 148.43 5723.01 5813.01 3779.48 -3345.61 2208.40 17625L 0.68 5.00 62.84 44179.48 2440587.75 202835.6 7361.82 40.98 14040 5794.19 6884.19 3838.14 8387.29 2242.79 136.860 0.32 5.61 52.64 44007.69 2446535.97 202870.27 746522 40.73 146.76 5884.90 654.90 3895.87 -3448.39 2276.51 116.91 0.37 5.022 52.37 4390494 2448484.88 202901.00 764922 4045 145.86 63637 8026.37 3953.62 -349028 2310.44 170.448 0.6 5.6 51.94 4364886 2446433.97 202937.92 7643.62 40.03 145.97 6008.43 609843 4011.35 -3549.79 2344.61 132.541 045 6.63 61.65 43419.94 2448383.47 202972.6 7736.82 39.93 145.80 679.85 616.86 4068.04 -3599.38 2378.20 68.991 0.16 664 5143 43344.02 2448333,6 20306.6 7828.12 40.6 145.32 6149.6 6239.80 4123.70 -3647.75 2411.38 125.826 0.36 5.65 5145 4336.95 2446285.50 2668.86 7922.52 39.77 145.93 622221 6312.21 4181.12 -367.74 2445.58 16.380 0.51 5.6 5130 43268.50 2446236.61 203073.6 61722 39.63 146.6 6295.07 6385.07 4238.25 3748.07 2470.13 31.816 0.63 5.67 51.30 43208.6 2446185.18 20316.61 8114.22 40.47 147.48 836.32 645832 4296.90 386.47 2513.04 177.499 1.02 5.08 52.26 43837.83 2446132.78 203140.62 8215.42 39.74 147.54 6448.73 6636.73 4358.6 -3855.46 2548.6 16.091 0.72 5.6 51.6 43424.61 2440077.79 203176.63 8307.02 39.58 146.71 6517.28 6807.26 4412.91 -3904.55 2579.78 30.081 0.61 5.70 51.24 43231.67 244628.70 203207.26 8402.92 40.14 148.18 6590.88 68880.88 4470.89 -3956.76 2613.74 150.731 0.70 5.71 51.70 43511.31 244677.49 203241.22 8497.32 39.64 146.76 6683.31 6763.31 4528.18 -400594 2847.82 16.289 0.61 5.71 51.14 43174.22 24462732 203275.10 862.02 39.55 146.24 6736.28 11826.28 465.29 -405597 2681.37 162.161 0.34 5.72 51.14 43176.17 244587728 203308.90 888322 39.08 148.6 8808.84 6898.84 4639.91 -4103.94 2713.58 148.111 0.54 6.73 50.65 42875.22 244582831 203341.07 8776.62 38.58 145.50 6879.6 696.6 466.40 -415235 2748.54 151.879 0.83 5.74 6.08 42524.38 244576.90 203374.6 8871.02 37.72 148.26 653.64 7043.84 476.81 -42682 277925 140.771 1.04 5.75 49.38 42095.37 2445732.63 203406.74 8905.72 3724 145.81 7028.99 7118.99 4805.15 -4248.36 2811.53 172.711 0.688 6.76 48.82 41731.72 2445684.90 203439.01 9080.02 3636 145.42 7104.60 7194.50 4868.74 -4294.92 2843.51 158.688 0.94 5.76 47.94 41170.46 244583833 203470.00 9158.72 36.88 146.74 7182.61 7272.61 4912.81 -4341.94 2876.73 155.21 0.53 5.77 47.54 40009.92 24456131 203503.22 923332 34.88 144.93 7245.6 7335.6 4954.93 -4378.42 2900.95 176.329 1.44 6.78 48.45 40187.27 2445504.83 203528.44 9276.92 3444 144.98 7250.10 7370.10 4077.6 -4398.26 2914.87 16.351 104 5.78 46.04 39913.48 2446636.6 203642.35 933200 9399 144.08 7320.48 741048 500009 4424.03 293.03 18911 0.85 5.79 4558 3961.05 2445509.22 203560.51 9382.6 33.59 144.40 7368.46 7468.46 634.82 -4446.91 2949.32 2.146 0.85 5.79 45.13 39298.37 244548634 203576.81 9476.70 36.79 144.6 7444.60 7534.60 5086.07 -4490.63 296.61 11.286 3.44 681 4821 41342.62 2445442.62 20367.6 9571.80 40.16 145.84 7519.83 786.83 5142.91 4539.88 3014.68 2.86 3.67 5.83 51.82 434099.07 2445393.57 203642.16 9666.40 42.61 145.81 7600.10 7680.10 5201.49 4500.77 3049.49 2.976 2.61 5.86 6.91 44809.48 244642.49 203876.97 9757.6 4454 146.96 7657.10 7747.10 5281.73 4843.45 365.17 18.929 220 6.86 55.6 46913.05 2445289.81 203712.6 9863.70 45.99 146.86 7724.6 7814.6 5326.06 4700.13 3122.96 116.471 1.60 5.87 5742 40726.43 2446233.13 20376.44 9951.10 45.76 145.97 779241 7882.41 5392.08 4758.30 3181.74 118.719 0.66 588 57.07 40643.74 2446174.96 20376.22 9993.77 4542 146.93 782227 7912.27 5420.84 -4783.70 3178.59 72359 1.79 5.89 6092 46466.71 2445149.66 203806.07 1004427 46.63 147.41 7857.68 7947.68 6454.68 4813.96 3198.11 HS 0.71 5.89 57.11 40668.71 2445119.30 203825.6 10139.77 46.69 147.41 7924.54 8014.54 5518.81 4871.41 323483 96.619 0.6 5.90 57.17 46599.64 2445061.85 20362.32 10236.97 45.66 147.78 7991.88 8081.88 5582.98 492841 3271.65 121.161 028 6.90 5721 48820.68 2445003.84 203899.13 163187 4527 147.10 66.6 8149.06 5846.87 -4988.86 3308.33 37921 0.6 691 68.81 46407.48 2444948.40 203935.81 1042727 45.61 148.73 8126.14 8216.14 6710.95 -504393 3345.52 169.016 0.45 5.92 57.07 48546.05 2444889.33 203973.6 1062137 4539 146.79 8192.09 8282.09 6774.18 -5100.6 3382.31 82349 024 5.93 58.86 48439.38 2444833.19 20406.79 Drilling Office 2.10.254.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) 1/3/2017 4:57 PM Page 1 of 2 • • Commend MD Incl Axlm Grid TVDSS TVD VSEL 449 EW TF 1318Exclusion Zone LS Directional Exclusion Zone M N GeoMeg Th Northing Easting (fl) (y C) (ft) (fl) (fl) (fl) (5) (°) (•71006) Difficulty Index Alert P1 (nT) (SUS) (SUS) 0620.77 45.43 47.20 8261.87 835187 5840.72 -5159.43 342088 28.17R 0.30 593 56.98 46500.42 2444773.83 204048.35 0716.07 45.65 47.29 8328.68 8418.68 5904.63 -5216.58 3457.63 41.79L 0.14 6.94 67.11 48570.89 2444716.87 204085.12 0810.77 45.88 40.88 8394.81 8484.81 5968.24 -527349 3404.47 176.86R 0.47 596 67.35 48698.33 2444659.76 204121.06 0807.07 45.39 46.93 8482.14 8552.14 6033.01 -5331.17 3532.06 108.381 0.51 596 68.89 40455.10 2444602.09 204150.55 1001.87 45.24 48.20 8528.81 8618.81 8096.56 -5387.41 3589.20 859.32L 0.67 5.98 58.61 46306.49 2444545.84 204106.68 1081.27 44.70 65.91 8592.05 8682.05 6156.32 -5439.83 3604.48 HS 0.65 5.97 58.03 45998.29 2444493.43 204231.96 1188.67 44.82 46.91 8681.21 8761.21 6221.24 -5496.83 364292 139.841_ 0.12 5.97 66.15 48061.24 2444436.83 204270.40 1283.17 44.72 46.79 8728.30 881830 6284.26 -5551.70 3680.28 135.791 0.14 5.08 58.03 46997.60 2444381.65 204307.78 1374.77 44.44 46.40 8783.55 6883.55 6345.24 -6606.75 3716.61 180.841_ 0.43 5.98 65,69 45811.49 244432660 204344.09 1489.47 44.04 45.20 8881.39 8951.30 6408.00 -6659.07 3764.22 173.681_ 0.45 5.09 55.27 46680.01 2444274.19 204381.70 1563.37 43.79 45.16 8929.04 8010.04 6489.81 -5712.64 3791.41 118.111 0.27 599 66.02 46443.22 2444220.72 204418.89 1657.77 43.47 44.28 890736 9087.36 6531.99 -5765.71 3829.03 168.146 0.73 600 64.64 46178.60 2444167.55 204456.51 1751.87 13.11 44.41 9065.88 8155.88 6593.62 -5818.14 3868.64 89.18R 0.30 6.01 64.22 44998.12 2444115.12 204494.12 1848.87 43.83 48.33 0136.23 9226.23 6656.73 -6872.83 3904.41 108.971_ 1.46 602 55.08 46480.70 2444060.42 204531.89 1941.57 43.43 45.47 0203.58 9293.58 6717.30 -6925.81 3940.28 175.811 0.67 6.02 64.73 45284.79 2444007.44 204587.76 2041.47 43.15 45.44 927830 9386.30 678232 -5982.23 3979.12 107.941 028 6.03 54.45 45131.08 2443951.02 204806.60 2137.57 42.86 43.98 9346.59 9436.59 6844.77 -6035.73 4016.97 44.331 1.08 6.04 53.88 44807.26 2443897.63 204844.45 2233.27 43.05 43.89 9416.64 9508.64 8907.21 -6088.37 4055.44 163.391 0.31 6.04 54.03 44889.77 2443844.89 204682.92 2325.17 41.67 43.07 9484.55 9574.65 8968.65 -6138.07 4092.37 129.351 1.57 6.05 52.58 44056.19 2443795.19 204719.88 2420.17 40.88 41.68 9565.95 9646.96 7027.11 -6187.87 4130.87 46.718 133 6.06 51.54 43436.22 2443746.68 204766.15 251737 41.40 42.41 9629.15 9718.15 7088.81 -8238.06 4170.04 78.098 0.78 6.07 52.20 43829.27 244369520 204797.52 2809.27 41.04 45.87 9697.81 9787.81 7147.31 -6287.57 4205.81 143.181 2.57 6.08 53.37 44516.30 2443845.69 204833.29 2704.07 4129 46.13 9788.68 9858.68 7207.05 833945 4241.47 114.091_ 0.88 6.08 52.61 44073.18 244359380 204868.95 2788.50 41.03 44.27 9839.78 0929.78 7266.20 8390.17 427738 113.11 0.68 6.09 62.20 43831.13 244354308 204904.88 2894.10 40.78 43.36 9912.03 10002.03 7326.24 8440.70 431434 19.431_ 0.68 6.10 51.79 43568.60 244349258 204941.82 2980.70 40.91 43.29 9984.35 10074.35 7388.27 8490.85 4361.68 55.910 0.14 6.10 51.90 43663.50 2443442.41 204979.16 3038.20 41.95 15.64 10020.71 10110.71 7416.91 8516.94 437035 111.021 3.74 6.11 53.32 44488.82 2443416.31 204997.83 3084.80 41.84 44.30 10055.48 10145.48 7446.47 -654236 438820 96.631_ 1.89 8.11 62.70 44180.88 2443390.89 205015.68 3175.00 41.54 42.89 10123.59 10213.59 7504.45 8591.03 4424.08 150.831_ 1.03 8.12 52.43 43966.87 2443342.23 205051.57 3270.80 40.44 41.94 10195.23 10285.23 7564.40 864038 446204 59.340 1.33 8.13 61.10 43228.18 2443292.90 205089.53 3389.10 41.38 44.23 10269.53 10359.53 7828.35 -8691.82 4600.60 146.771 1.79 6.14 52.61 44018.94 2443241.44 206128.17 3460.10 30.77 42.59 10338.66 10428.66 7683.13 -673033 453595 133.161 2.10 6.15 50.68 42916.43 2443193.92 205103.43 350511 39.13 41.50 10373.42 10463.42 7710.77 -676188 4553.63 155.540 2.10 8.15 49.88 42408.41 2443171.37 205181.02 3586.40 38.66 41.85 10421.12 10511.12 7748.01 8792.07 4577.40 61.57R 0.86 6.15 49.47 42184.04 2443141.18 205204.88 3659.21 39.36 43.84 1040325 10583.25 780421 8838.62 4812.68 24.63R 1.55 6.16 60.51 42816.28 2443004.63 205240.15 3755.71 41.76 45.49 10566.57 10656.57 7864.02 8889.81 4848.93 41.962 2.73 6.17 63.13 44381.47 2443043.44 205276.41 3848.01 42.47 46.43 10635.03 10725.03 7022.50 8041.10 4683.57 15.688 1.03 6.18 53.99 44874.32 2442992.15 205311.05 3042.21 43.56 4887 10703.91 10783.91 7083.15 8996.78 4718.90 48.480 1.20 6.19 65.12 46509.71 2442938.47 205348.38 4040.61 44.36 48.15 10774.74 10884.74 9047.16 -705240 4755.58 124.571_ 1.22 6.19 56.12 48059.78 2442880.86 205383.06 4135.41 43.98 4735 10842.74 10932.74 8108.97 -7108.28 4790.83 1611.781 0.71 620 55.61 45781.90 2442824.99 205416.31 4229.21 42.88 48.07 10010.86 11010.86 8160.64 -7162.44 4825.79 39.28R 121 621 54.48 45155.64 2442770.81 205453.28 Tie-In Survey 4323.91 44.57 48.92 10079.30 1108930 8230,70 -7217.92 4860.51 63.1R 228 622 58.48 46244.64 244271533 205488.00 Top Whipstock(NOP) 4362.00 44.73 49.36 11006.39 1109630 8255.51 -7240.90 4874.24 301 0.92 622 56.60 46368.91 2442602.35 205501.73 Bees Whipstock 4378.00 16.47 4788 11017.59 11107.50 8266.14 -7260.68 4880.19 HS 12.50 623 58.13 47117.52 2442682.58 205507.67 Cis2/100 4398.00 46.47 47.98 11031.36 11121.38 8270.69 -7262.96 4887.88 03.861 0.00 6.23 58.13 47117.62 244267030 205515.38 4400.00 46.47 47.03 11032.74 11122.74 8281.05 -7264.19 4888.85 03.821_ 2.00 6.23 58.12 47111.13 2442669.07 205516.13 4500.00 4837 45.17 11101.60 11101.69 8349.34 -7324.61 4928.58 91821_ 2.00 624 5750 48784.43 244260884 205568.06 4800.00 48.33 42.41 11170.72 11280.72 8418.63 -7382.98 4971.30 90 011 2.00 625 66.03 40493.77 244265027 205508.78 4700.00 4637 39.64 11239.76 11329.75 8488.85 -7430.23 5018.80 88.111 2.00 6.28 56.40 46210.93 2442494.03 20584420 4800.00 46.46 36.89 11308.70 11398.70 8559.90 -7403.27 6065.02 88.21_ 2.00 6.27 55.91 45947.63 2442439.98 205882.50 4900.00 46.63 34.14 11377.49 11487.49 8631.70 -7545.05 6115.88 84321 2.00 6.27 55.48 45705.52 244238821 20574336 5000.00 46.86 31.41 11448.02 11636.02 8704.17 -7594.50 518933 82451_ 2.00 6.28 55.06 45488.13 2442338.76 205706.81 5100.00 47.16 28.71 11514.21 11804.21 8777.20 -7661.58 522531 80.61 2.00 6.29 54.71 45290.85 2442291.69 205852.79 5200.00 47.51 28.03 11581.99 11671.99 8850.72 -7688.18 5283.74 78.791_ 2.00 8.30 54.61 45120.98 2442247.08 20591122 5300.00 47.83 23.39 1164927 11739.27 8924.63 -772830 6344.66 77.011_ 2.00 8.31 54.15 44977.62 244220496 205972.04 End Cry 5314.81 48.00 23.00 11650.18 11749.18 8835.60 -7734.32 6353.78 HS 2.00 6.31 64.12 44958.71 244210894 206881.24 5400.00 48.00 23.00 11718.19 11806.19 8998.75 -7768.80 640685 HS 0.00 8.32 64.12 44958.10 2442164.45 208034.34 5603.00 48.00 2300 11783.10 11873.10 9072.88 -780028 5489.18 HS 0.00 8.32 54.12 44959.57 2442123.98 206096.66 5800.00 48.00 23.00 11850.01 11940.01 9147.00 -7840.75 5531.60 HS 0.00 6.32 64.12 44960.03 2442093.60 208158.99 Cry 223/100 5689.65 46.00 23.00 11910.00 12000.00 9213.45 -]686.03 5587.38 168.421_ 0.00 8.33 64.12 44960.45 244204722 206214.88 5700.00 47.]] 22.94 11916.94 /2006.94 8221.11 -7890.21 6693.82 188.38E 2.23 8.33 63.88 44830.65 2442043.01 206221.30 5800.00 45.60 2231 11985.64 12075.54 8203.64 -7029.44 6655.09 167.951_ 2.23 8.34 61.69 43540.97 244200381 206282.58 5000.00 43.42 21.63 12056.85 12146.86 9363.48 -7066.57 571455 167.481_ 2.23 6.35 49.49 42187.81 244190669 20634203 6000.00 41.26 20.80 12130.77 12220.77 9430.45 -8001.53 11712.11 168.92E 223 6.35 47.29 40]]3.43 1441831.73 206398.59 8100.00 39.09 20.10 12207.18 12287.18 0404.53 -8034.27 6827.68 166311_ 223 636 45.08 39300.23 2441898.98 206455.16 6200.00 38.93 19.23 12285.97 12375.97 0555.58 -8084.76 6881.17 165.621 223 637 42.89 37770.74 2441888.50 206508.65 6300.00 34.77 18.26 12367.02 12457.02 0613.52 8092.93 5932.61 164.841_ 223 638 40.70 36187.65 2441840.33 206550.00 6400.00 32.63 17.18 12450.21 1254021 986826 8118.74 6981.62 163.041 2.23 639 38.51 34553.83 2441814.51 208608.10 ' 6500.00 30.50 16.96 12535.11 12625.41 0719.72 8142.17 6026.42 162.91 2.23 630 3632 32872.31 244179108 206855.00 6600.00 28.38 14.59 12622.60 12712.50 0767.82 8163.17 6072.86 161.711 223 6.40 34.14 3114636 244177008 206700.33 6700.00 2827 13.01 12711.34 12801.34 0812.40 8181.71 6114.83 180.31 223 6.41 31.96 29379.48 2441751.54 206742.31 6800.00 24.19 11.18 12801.80 12891.80 0853.66 8197.76 6154.30 158.651 223 6.41 29.78 27575.52 2441735.49 206781.70 End Cry/TO 6808.08 24.00 11.00 12810.00 12900.00 8857.18 8109.08 6157.73 223 6.41 29.80 27411.76 2441734.17 206785.21 Survey Type: Def Plan Drilling Office 2.10.254.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) 1/3/2017 4:57 PM Page 2 of 2 • • Schlumberger GLACIER Borehole: Well: Field: Structure: RU-3A(P6) RU-3 Redoubt Unit Osprey Platform Gravity 8 Magnetic Parameters Surface Location NAD27 Alaska State Plane,Zone 04,US Feet Miscellaneous Model: BGGM 2016 Dip:73.61° Date: 31-Dec-2016 Lat: N 6041 43.67 Northing: 5449933,2550 Grid Cony: -1.457° Slot: L3-S15(06) ND Ret: KB(90ft above MSL) MagDec:16.102° FS: 55389.769nT Gravity FS: 1001.339mgn(9.80665 Based) Lon: W 151 40 14.50 Easting: 200627.48ftUS Scale Fact: 1.00000199 Plan:RU-3A(P6) 3500 4000 4500 5000 5500 6000 6500 7000 -4000 -4000 N 4500 -4500 -5000 \ -5000 91/8- 13760 MD 11937 ND 15740 MD 12653 ND 58 RU-5B 15323 MD 12318 ND -5500 -5500 RU-5 g-6000 -6000 0 0 0 N- 03 15 w-6500 7.,.. -6500 13321 MD 11,30 1VD to 2 -7000 -7000 -7500 5-or -7500 16995 MD 12829 ND RU-5A -8000 RU-3A(P6) -8000 15615 MD 11982 ND -8500 -8500 s1 16940 M013017ND / -9000 RU-3 -9000 3500 4000 4500 5000 5500 6000 6500 7000 EW(ft)Scale=1:750.00(ft) Schiumberger GLACIER Borehole: Well: Field: Structure: RU-3A(P6) RU-3 Redoubt Unit Osprey Platform Gravity&Magnetic Parameters Surface Location NAD27 AMska State Plane,Zone 04,US Feet Miscellaneous Model: BGGM 2016 Dip:73.6? Date: 31-Dec-2016 Lat: N 6041 43.67 Northing: 5449933.25ftU Grid Cony: -1.45? Slot: L3S15(06) TVD Ref: KB(90ft above MSL) MagDec:16.102° FS: 55309.769nT Gravity FS: 1001.339mgn(9.80665 Based) Lon: W 151 40 14.50 Easting: 200627.48ftUS Scale Fact: 1.00000199 Plan:RU-3A(P6) 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 -6800 _._..... -6800 7J -7000 • ' . _. . .._ -7000 4 IF \ . 7200 -7200 -7400 S112" -7400 16995 MD 12829 ND RU-5A • -7600 -7600 0 0 0 0 M -7800 -7800 IIm U co co Z -8000 �. -8000 (..5, 15615 MD 11982 ND /RU-3A(P6) -8200 '_J -8200 -8400 -8400 -8600 -8600 -8800 -8800 -112' 16940 MD 13017 ND RU-3 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 EW(ft)Scale=1:300.00(ft) • • RU 3A Sundry Application,Geology 11 14 13 23 14 20 7N/13W 58 - 5A U 3A RU3 26 35 ?< All wells within%2 mile radius of RU 3A. Well Zone open to Production/ API Well Name Type Status Injection Redoubt Unit 50733205040000 3 Producer Shut-In Tyonek, G-O, Hemlock Redoubt Unit Plugged & 50733205130100 5A Producer Abandoned Hemlock Redoubt Unit 50733205130200 5B Producer Shut-In Hemlock Table of Well Name, Status, and Type within a %2 mile radius of RU 3A. Well Head Location: Section 14,T. 7 N., R. 14 W., S.M., 1,962 feet from the south line and 271' from the east line. The RU 3A Well will have a bottom hole location within Section 30,T. 7 N., R. 13 W., 848' from the north line and 762' feet from the west line. The top of the injection zone is anticipated to fall 573' roughly from the north line and 230 feet from the west line of Section 30. CIE is planning to inject into zones within Section 30,T. 7 N., R. 13 W., S.M. Fluids from this injection activity may additionally migrate into Section 19,T. 7 N., R. 13 W., S.M., and into Sections 24 and 25 of T. 7 N., R. 14 W., S.M. 4. • • rfi(rft. ' �F 11 !IV° !(141145114AN I 114. D1 0 9 1111P ! i \, r. 11111111►�A s 114'AVAIIIIP ; 3 I ...,,,, 41 iiiiiallti 11111Wr 141F4A Iry ! stio, ip....._,,,,,,-•„1—. 41.......... iti. .„ . .,... '''.4:44404b:40#... ' 46o#:4 /*' At tit***" ...r „1 PiVIIPP. 174r, ISM. =4---m, 11 . z. ie, �° wY \ry 8° // //777/ / atz ' i r e / t.roro I \ ---.-_ ----- Fault and fractures in%mile radius of RU-3A with all Redoubt field wells. Structural Geology The planned RU 3A injector is intended to be drilled into a down-dip structural position in the Southern fault block on the Redoubt Shoal structure. The RU 3 is currently inactive after being utilized as a gas producer from a lower Tyonek Gas Sand. As designed,the well will be sidetracked and drilled to a penetration point down-dip of and laterally between the RU 5A and existing RU 3 wells. The well is planned to be a water injector for the purpose of pressure maintenance in the Upper and Middle Hemlock zones and enhancement of production in this legacy Cook Inlet field. The well is situated in the hanging wall of a reverse fault bounding the western edge of the field. Structural dips should be flat to dipping southwest at a low dip angle. As designed,this well should be the lowest active well drilled on the Redoubt structure. Reservoir parameters similar to those encountered at RU 3 and RU 5A can be expected for this location. It should be ideally situated to water flood the remaining reserves to the up dip nearby in field producers RU 5B(planned) and RU 2A. No faults will be intersected by the new wellbore sidetrack that kicks out of the existing RU 3 with the top of the whipstock(KOP) at: Top 14,362 MD (11,008 TVDSS).'No faults are intersected by any wellbore within the estimated fracture wings of 117-216' horizontally or vertically in the area. • • The Oligocene Upper and Middle members of the Hemlock formation are the primary reservoir targets of this fracture stimulation with water injection and can be broken into 4 intervals: Upper,Clay/Silt Zone, Middle Hemlock, and the Lower Hemlock.The Miocene lower Tyonek formation overlays the Oligocene Hemlock reservoir which overlays the Eocene West Foreland Formation. The RU 3A injector is planned to be drilled up-dip of the original RU 3 wellbore. Below thicknesses are measured from the two nearby well penetrations RU 3 and RU 5A. RU 3A TD is"'1,100' down dip to the SW and the RU 5A wellbore TD is"'800' up dip of the proposed RU 3A injector. In the RU 3 there is a 15' thick claystone/carbonaceous shale above the upper Hemlock formation 12,130-12,145 ND 15,840- 15,859' MD. Fracture modeling suggest that the expected fracture height is on the order of ^'125-159' with fracture wing lengths of—117-216'. The gross Upper, Silt and Middle Hemlock interval in this fault block is 453'feet thick. Mechanical properties have been modeled using Schlumberger's FracCADE program for shales and Hemlock Formation pressure gradients with depth. The Hemlock formation is estimated to have a fracture gradient in sandstones of 0.776 psi/ft and in situ stress ranging from 8963-9251 psi, a modeled shale fracture gradient of—0.9 psi/ft and in situ stress in shale ranging from 10990-11548 psi. . --.1 ..,ilii, 11----- , .o, , \ / // / - - / I b' i 5- �o/ :77 $ x,,,,, �z 1 1 o / i ,.//s RU 5• ,__.--'' --,, V I \ RU ______:::,..7„� .r� // A radius of 216' shown above with blue circle around the RU-3A proposed location throughout the hemlock formation with the projected top at ^'11'TVD. Edge of fracture wings are greater than 1400' +from nearest faults. /210411 ` • • RU 3 Well Log: .. _ _ .... m 10 nra _ e. a+ ,xra 2 YM Or le rM = ,lost .ae yc� ,IPMWq {. i 1 F I 1 , 11`•sr •W —_- _ - Upper Claystone/Carbonaceous Shale/Coale ,_._..�_ __.-._ -Y` 15,840-15,859' MD (12,130-12,144' TVD) :.Z I ` j H -r yti MAkilt A :1....._..._ _ ? .....�. I c Upper and Middle Hemlock �.-1 - _ = 15,840-16,421' (12,130-12,583' TVD) 1 r ,, I t :- I I i. ti.,. . - = } CIC'' 1 Lower Hemlock I t _ ._.` -Il` ,.r.._ Lower Claystone/Carbonaceous Shale/Coal :l i • EXHIBIT A — LANDOWNERS, OWNERS AND OPERATORS Landowner Owner Operator As defined in As defined in As defined in AS 31.05.170 7 AS 31.05.170(10) 20 AAC 25.990 46 Le.al Descri i tion State of Alaska Cook Inlet Cook Inlet ADL 381203 Energy, LLC Energy, LLC T.7N.,R.14W.,SEWARD MERIDIAN,ALASKA SECTION 13,PROTRACTED,ALL,640 ACRES; SECTION 14,PROTRACTED,ALL,640 ACRES; SECTION 23,PROTRACTED,ALL,640 ACRES; SECTION 24,PROTRACTED.ALL,640 ACRES; SECTION 25,PROTRACTED,ALL,640 ACRES; SECTION 26,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 3,840 ACRES MORE OR LESS. State of Alaska Cook Inlet Cook Inlet ADL 374002 Energy, LLC Energy, LLC T.7N,R.13W.,SEWARD MERIDIAN,ALASKA SECTION 19.PROTRACTED,ALL,615 ACRES; SECTION 20.PROTRACTED,ALL,640 ACRES; SECTION 21,PROTRACTED,ALL,640 ACRES; SECTION 28,PROTRACTED,ALL,640 ACRES; SECTION 29,PROTRACTED,ALL,640 ACRES; SECTION 30,PROTRACTED,ALL,617 ACRES; SECTION 31,PROTRACTED,ALL,619 ACRES; SECTION 3Z PROTRACTED,ALL,640 ACRES; SECTION 33,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 5691 ACRES MORE OR LESS. Contact Information: State of Alaska CERTIFIED MAIL 7015 0920 0002 1701 0089 Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage,AK 99503 907-269-8800 Cook Inlet Energy, LLC CERTIFIED MAIL 7015 0920 0002 1701 0096 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 907-334-6745 • S EXHIBIT B -WELLS WITHIN 'h MILE RADIUS OF PROPOSED OPERATION T. 7 N., R. 14 W., S.M. T. 7 N., R. 13 W., S.M. 4 ,F, ti 7N/13W 5B 5A 3F'%2 mile t't^ 25 27 3A - ..R • S EXHIBIT C- NOTICE OF OPERATIONS GLACIER December 23,2016 CERTIFIED MAIL Landowners,Owners and Operators See Distribution List West Foreland Area Cook Inlet Basin,Alaska Re: Notice of Operations under 20 AAC 25.283 of Cook Inlet Energy.LLC"s Sundry Application for a Fracture Stimulation for the Proposed RU 3A Sidetrack Well Dear Landowner,Owner and/or Operator, Cook Inlet Energy,LLC,a Glacier Oil and Gas company(GLA)is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the proposed RU 3A sidetrack well.This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(l)(A) and 20 AAC 25.283(a)(1)(B). The complete application is available for review upon request.if you wish to review the application,please contact Tim Jones,Senior Landman,at the following: Tim Jones Senior Landman Glacier Oil and Gas Corp. 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 Direct:907-433-3811 tjones(aglacieroil.com GLA,through a search of the public record,has identified you as a Landowner,Owner or Operator(as defined in AOGCC regulations)within 1/2 mile of the proposed RU 3A sidetrack well trajectory and fracture stimulation. Please contact mc should you require additional information. Sincerely, Tim Jones Senior Landman Distribution List:Alaska Division of Oil and Gas Cook Inlet Energy,LLC 601 W S°'Ave.,Suite 310,Anchorage,AK 99501 • Proposed RU 34Detrack Well Fracture Stimulation December 23,2016 EXHIBIT D Affidavit State of Alaska,Third Judicial District Personally appeared before me,Timothy Jones,who,being duly sworn according to law,deposes and says: 1. 1, Timothy Jones, am a Senior Landman for Cook Inlet Energy, LLC and a Registered Professional Landman#84167. 2. The Landowners, Owners and Operators, as defined in relevant state statutes and regulations, identified in Exhibit A are correct to the best of my knowledge. 3. The well location in Exhibit B was taken from Cook Inlet Energy, LLC's Permit to Drill submitted to AOGCC. 4. The Notice in Exhibit C was sent to the Landowners, Owners and Operators identified in Exhibit A by certified mail. Further the affia t sayeth naught. 11.4"4) 12/23/14 Timothy Jon‘ Date RPL#84167 UNITED STATES OF AMERICA § STATE OF ALASKA Subscribed and sworn to before me on the 4 ShC)day of December,2016. fitz4._._ 4,:tailinit ±' Notary Public Notary Public ROWENA KEHR i�- �O�r1 State of Alaska My commission expires: ! My Commission Expires Feb, 14. 2017 • . Client: Cook Inlet Energy Schlumberger Well: Redoub Basin/Field: Redoubt Unit State: Alaska County/Parish: Kenai Peninsula Borough Case: 6967613 Disclosure Type: Pre-Job Well Completed: 3/17/2017 Date Prepared: 2/3/2017 8:21 AM Report ID: RPT-47590 Fluid Name&Volume Additive Additic Description Concentration Volun F103 Surfactant 1 Gal/1000 Gal 129.0 Gal J218 Breaker _ 2.2 Lb/1000 Gal 281.0 Lb J450 Stabilizing Agent 1 Gal/1000 Gal 129.0 Gal J475 Breaker 3.5 Lb/1000 Gal 450.0 Lb J604 Crosslinker 1.6 Gal/1000 Gal 210.0 Gal YF127FIexD:WF127 128,310 Gal 1891 Guar Slurry 6.3 Gal/1000 Gal 810.0 Gal M002 Additive 1.1 Lb/1000 Gal 138.0 Lb M117 Clay Control Agent 250 Lb/1000 Gal 32,077.5 Lb M275 Bactericide 0.4 Lb/1000 Gal 54.0 Lb _ S522-2040 Propping Agent varied concentrations 89,100.0 Lb _ W054 Demulsifier 1 Gal/1000 Gal 129.0 Gal The total volume listed in the tables above represents the summation of water and additives. Water Is supplied by client. CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* '"89% 64-19-7 Acetic acid(impurity) <0.0001 % 67-56-1 Methanol <0.1 % 67-63-0 Propan-2-ol <0.1 % 91-20-3 Naphthalene(impurity) <0.001 % 95-63-6 1,2,4 Trimethylbenzene(impurity) <0.0001 % 102-71-6 2,2',2"-nitrilotriethanol <0.1 % 107-21-1 _ Ethylene Glycol <0.1 % 110-17-8 Fumaric acid <0.01 % 111-76-2 2-butoxyethanol <0.1 % 112-42-5 1-undecanol <0.01 % 122-18-9 Benzyldimethylammonium chloride <0.0001 % _ 127-08-2 Acetic acid,potassium salt <0.001 % 139-07-1 Benzyllauryldimethylammonium chloride <0.01 % 139-08-2 Dimethylbenzylmyristylammoniumchloride <0.001 % 143-18-0 Potassium oleate <0.001 % - 1310-73-2 Sodium hydroxide <0.1 % _ 1319-33-1 Boronatrocalcite <0.1 % 1330-43-4 Sodium tetraborate <0.01 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 7447-40-7 Potassium chloride -3 % _ 7631-86-9 Silicon Dioxide <0.001 % 7647-14-5 Sodium chloride <0.1 % 7704-73-6 Monosodium fumarate <0.01 % 7727-54-0 Diammonium peroxidisulphate <0.1 % 7786-30-3 Magnesium chloride <0.001 % 9000-30-0 Guar gum <1 % 9002-84-0 poly(tetrafluoroethylene) <0.0001 % 9003-11-6 Methyl oxirane polymer with oxirane <0.01 % 10043-35-3 Boric acid <0.01 % 10377-60-3 Magnesium nitrate <0.001 % 14464-46-1 Cristobalite <0.0001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 14808-60-7 Quartz,Crystalline silica <0.0001 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.01 % 25322-68-3 _ Poly(oxy-1,2-ethanedlyl),a-hydro-w-hydroxy-Ethane-1,2-diol,ethoxylated <0.01 % 26062-79-3 - Ammonium,diallyldimethyl-,chloride,polymers <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % _ 30846-35-6 Ethoxylated propoxylated 4-nonyiphenol-formaldehyde resin <0.01 % 34398-01-1 Alcohol,C1i linear,ethoxylated <0.1 % 64742-47-8 Distillates,petroleum,hydrotreated light <1 % 0 Schlumberger 2017.Used by Cook Inlet Energy by permission. Page:1/2 • • Client: Cook Inlet Energy Schlumberger Well: Redoub Basin/Field: Redoubt Unit State: Alaska County/Parish: Kenai Peninsula Borough Case: 6967613 Disclosure Type: Pre-Job Well Completed: 3/17/2017 Date Prepared: 2/3/2017 8:21 AM Report ID: RPT-47590 CAS Number Chemical Name Mass Fraction 64742-94-5 Heavy aromatic naphtha <0.01 % 66402-68-4 Ceramic materials and wares,chemicals —8% 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 68153-30-0 Amine treated smectite clay _ <0.01 % 78330-19-5 Alcohol,C7-9-iso,C8,ethoxylated <0.01 % 78330-20-8 Alcohol,C9-11-iso,C10,ethoxylated <0.01 % 78330-21-9 Alcohol,C11-14,ethoxylated <0.01 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 125005-87-0 Diutan gum <0.001 % Total 100% •Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. "The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC-Chemicals as of the dote of the document was produced.Any new updates will not be reflected in this document. 0 Schlumberger 2017.Used by Cook Inlet Energy by permission. Page:2/2 • 0 RU-03A WI-Current Wellbore Schematic Date: 20-Apr-17 Version: Final GLACIER ill + 30" 1500 A-36 260'MD ID-28" Welded 260'TVD 1 i cI ti r 41/2"15.18 P110 Geoconn-ID 3.83r 7500'MD F I t0 1 2. 318" 898 L-60 3,507'MD 18 1/2"Hole i_ 1 I ^11 13 -12.25" BTC 3,024/TVD ILiu 1---) ,61,1',.. , I9 1 4112 X 95/8"Liner Hanger r TOL 7,500'MD }� r �__d Perforations n MD TVD Feet "�leet ? 1 eP 7,780-7.800 6,203-8219 20 ja• L.i 7,805-7.818 6.223.6+233 13 `�} i. .� trr . iF Top of 7-518'x 95/8"Liner 9,103'MD - t i', .r� ti(t 9 Syr" 418140 8,332'MD 12114'Hole D-9.50" BTC 7,416'TVD 14 :4 c,; : 4 TOC(CBL):12,975'MD --1 l', '.i J. Window 8112"Hole Y, 7 sir 29.7#LSV 14,176'MD ID-6.75' Hydrll 521 10,982•TVD Y 4 fIis C 5 .I Aw t, rl- 1 54 b. �� (L,,l 1.' A411T 15.19P-110 1848711D 6314"Hole , _D-3.932"_ Geoconn 12650'TVD PBTD:16390 MD/12579'TVD T • Bettis, Patricia K (DOA) From: Anna Belanger <abelanger@glacieroil.com> Sent: Tuesday, February 21, 2017 9:45 AM To: Bettis, Patricia K(DOA) Subject: Type-0 RU 3A Sundry G &G Patricia, I noticed a type-O in the G &G sundry application. Please update this text for the third figure,the only thing that is different is the Top Hemlock depth in TVD highlighted in red. "A radius of 216' shown above with blue circle around the RU-3A proposed location throughout the hemlock formation with the projected top at —12,041' ND. Edge of fracture wings are greater than 1400' +from nearest faults." Thank you, Anna Anna M. Belanger Senior Geologist Glacier Oil &Gas Office: (907)433-3837 1 • S Bettis, Patricia K (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Tuesday, February 21, 2017 9:23 AM To: Bettis, Patricia K(DOA);Anna Belanger Cc: Stephen Ratcliff; George Morris;Amanda Dial Subject: Re: RU-3A (PTD 216-170): Hydraulic Stimulation Sundry Application Patricia, Please review the information that Anna put together and let me know if this meets your request. The upper confining zone for the Hemlock Reservoir in RU-03A: RU-03A Predicted Confining Zone: 12,026-12,041'TVD, 15,694-15,716' MD Lithologic Description: This zone is composed of a mixed lithology of coaly material and tuffaceous siltstone and is 15 ft TVD thick,we consider this mixed lithology interval as the confining layer. Please see detailed mud log descriptions below. COAL = GRAYISH BLACK TO BLACK; FIRM; RESINOUS LUSTER; MATTE TEXTURE; IREG FRACTURE; OCC BLACKISH RED CARB SHALE. TUFFACEOUS SILTSTONE= GRAYISH ORANGE; POOR TO MOD INDURATED; EARTHY FRAC; EARTHY TO GREASY LUSTER; SILTY TO ASHY TEXTURE; INTBD WITH ASH_CLAY; COMP OF 60% SILT, 40%ASH, 10% CLAY; REWORKED. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W. 5th Avenue,Suite 310 Anchorage,AK 99501 O-(907)433-3808 C-(907)433-9738 1 II' • From: "Bettis, Patricia K(DOA)" <patricia.bettis@alaska.gov> Date: Friday, February 17, 2017 at 11:33 AM To:Anna Belanger<abelanger@glacieroil.com> Cc:Stephen Ratcliff<sratcliff@glacieroil.com>,George Morris<gmorris@glacieroil.com>,Amanda Dial <adial@glacieroil.com> Subject: RE: RU-3A(PTD 216-170): Hydraulic Stimulation Sundry Application Anna, 20 AAC 25.283(a)(9), requires data for the fracturing zone and confining zones including lithologic description,geological names, measured depth (MD) and true vertical depth (ND) Please describe the upper confining zone(s)for the Hemlock reservoir. Cook Inlet needs to provide estimated tops for this upper confining zones(s)for RU-3A, in both MD and ND. It is unclear whether the operator feels the shale is the confining zone or the coal is the confining zone. Please elaborate. Thank you, Patricia From:Anna Belanger mailto:abelanger@glacieroil.com g [ 1 Sent: Friday, February 17,2017 11:17 AM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Cc:Stephen Ratcliff<sratcliff@glacieroil.com>; George Morris<gmorris@glacieroil.com>;Amanda Dial <adial@glacieroil.com> Subject: FW: RU-3A(PTD 216-170): Hydraulic Stimulation Sundry Application Patricia, I am copying the text in blue below and the RU 3 log from the G &G Sundry for 3A describing the claystone/coal bed in referenceand fracture gradients. "In the RU 3 there is a 15'thick claystone/carbonaceous shale above the upper Hemlock formation 12,130-12,145 ND 15,840-15,859' MD." "The Hemlock formation is estimated to have a fracture gradient in sandstones of 0.776 psi/ft and in situ stress ranging from 8963-9251 psi,a modeled shale fracture gradient of"'0.9 psi/ft and in situ stress in shale ranging from 10990-11548 psi." The depths of the confining layer were provided in ND and MD from the RU 3 parent wellbore as well as the range of frac.gradients in sandstone and mudstonesmodeled for 3A.Are you wanting a projection of this^'14-15 ft claystone/coal for RU 3A? If so we have estimated Top Hemlock will be coming in at 12,041 ND 15,716' MD.The claystone is right above Top Hemlock in between the Top Hemlock Coal and Top Hemlock as shown on the RU 3 log in the Sundry application. 2 • 41110 RU 3 Well Log: r W a- -# .. .. ...: r• .111, » * NW_ _ _........_.... .. .. r . �,�,,�,,,,r I, Upper Claystone/Carbonaceous Shale/Coal: �" �" E._-__. _�- \t15,S40-15,859' MID(12,130-12,144 TVD) — t Wrill9":' , { r�: 4 — "` _--- ' \ Upper and Middle Hemlock ' 15.S40-16,321'(12,130-12,583'TVD) . , 61111=liAlla ... ��. I _- ) I .E t 1 f . ' iMill iN Lower Hemlock ;_l_____,,r,_,.:47:' o .. I 1 i 'i-- . ► Lower Claystone/Carbonaceous Shale/Coal Please respond to the group, so that we are all in the know of anything in addition you would like from what we have provided. Best Regards, Anna Anna M. Belanger Senior Geologist Glacier Oil &Gas Office: (907)433-3837 Cell: (225)287-5921 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, February 17, 2017 9:07 AM To: Anna Belanger<abelanger@glacieroil.com> Subject: RE: RU-3A (PTD 216-170): Hydraulic Stimulation Sundry Application Anna, Cook Inlet states that the upper confining zone is a 15' claystone/coal bed. No estimated depth in MD or TVDss was provided for RU-3A. If this is not the case, I need Cook Inlet to describe the upper confining zone, in terms of lithology, fracture gradient and provide the depth to the zone in both MD and TVDss. 3 • • Thank you, Patricia From:Anna Belanger [mailto:abelanger@glacieroil.com] Sent:Thursday, February 16, 2017 5:00 PM To: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Cc:Amanda Dial <adial@glacieroil.com>; Stephen Ratcliff<sratcliff@glacieroil.com>; George Morris <gmorris@glacieroil.com> Subject: RE: RU-3A(PTD 216-170): Hydraulic Stimulation Sundry Application Patricia, Please see the attached RU-3A fracture modeling which shows the three planned frac. stages,their heights,widths and where they are modeled to terminate. The fracture model is based on a mechanical earth model derived from Redoubt Field Dipole Sonic, Log and Core data. Therefore it should be more accurate on estimating the fracture termination than a thickness estimate of a non-porous interval as it is accommodating for the young's modulus, poisons ratio and stress and strain in the earth in these specific zones at depth. Best Regards, Anna Anna M. Belanger Senior Geologist Glacier Oil &Gas Office: (907)433-3837 GLACIER From: "Bettis, Patricia K(DOA)" <patricia.bettis@alaska.gov> Date:Thursday, February 16, 2017 at 11:01 AM To:Stephen Ratcliff<sratcliff@glacieroil.com> Subject: RU-3A(PTD 216-170): Hydraulic Stimulation Sundry Application Good morning Stephen, Please provide the estimated depth, both MD and TVDss,for the following: 1. Upper Claystone/Carbonaceous Shale/Coal Marker for the upper Hemlock. This would be the upper confining zone. 2. West Foreland Fm. Thank you, Patricia Patricia Bettis 4 • Senior Petroleum Geologist • • Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 5 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, February 13, 2017 1:41 PM To: sratcliff@glacieroil.com Subject: Hydraulic Fracturing Application Sundry 317-070 RU 3A (PTD 2161700) Stephen, We are reviewing the Frac stimulation sundry for RU 03A. 20 AAC 25.283(a)(12)(c) requires the chemical ingredient name and chemical abstracts service registry number of each additive. I am not finding that in the application? In the past,Schlumberger etc has provided this in a format very similar to the FracFocus chemical disclosure. Please provide at your earliest so we can progress the sundry application. Thanks and Regards, Chris Wallace,Sr.Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, February 16, 2017 11:02 AM To: 'Stephen Ratcliff' Subject: RU-3A (PTD 216-170): Hydraulic Stimulation Sundry Application Good morning Stephen, Please provide the estimated depth, both MD and TVDss,for the following: 1. Upper Claystone/Carbonaceous Shale/Coal Marker for the upper Hemlock. This would be the upper confining zone. 2. West Foreland Fm. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • s Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Wednesday, May 10,2017 9:53 AM To: Stephen Ratcliff(sratcliff@glacieroil.com) Subject: RU -3A Frac and update (PTD 216-170) Stephen, Since you issued sundries 317-107 to change the tubing completion (high packer) 317-150 to perf well and do some injection breakdowns before stimulating the well the procedure I have to stimulate the well seems to be outdated somewhat. With perforations in the well how will you pressure test the tubing before the stimulations start? What is the well status of the CT cleanout and well activity? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 s s Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,June 19, 2017 1:02 PM To: Stephen Ratcliff Cc: samantha.carlisle@alaska.gov Subject: RE: RU -3A frac sundry(PTD 216-170) OK..AOGCC will withdraw sundry as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Stephen Ratcliff[mailto:sratcliff@glacieroil.com] Sent: Monday,June 19,2017 12:46 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Conrad Perry<cperry@glacieroil.com>;Amanda Dial<adial@glacieroil.com>; Leland Tate<Itate@glacieroil.com>; Stephen Ratcliff<sratcliff@glacieroil.com> Subject: Re: RU-3A frac sundry(PTD 216-170) Guy, Per our previous conversation,we would like to formally withdraw the RU-03A Frac Sundry. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 O-(907)433-3808 C-(907)433-9738 From:"Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Monday,June 19,2017 at 10:27 AM To:Stephen Ratcliff<sratcliff@glacieroil.com> Subject: RU-3A frac sundry(PTD 216-170) Stephen, Can you request by email to withdraw the hydraulic stimulation sundry(317-070)that you submitted. Per our conversation recently you said you were not going forward with the work. The sundry has not been approved as of now. 1 • S Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or (Guy.schwartzPalaska.gov). 2 oF • V 1)"%* I//y,.c,4. THE STATE Alaska Oil and Gas tip► of Conservation Commission LAsSr# = KA 333 West Seventh Avenue '-- — / Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 SFA *Q' Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC 601 W. 5th Ave., Ste. 310 Anchorage, AK 99501 Re: Redoubt Shoal Field, Undefined Oil Pool, RU 3A Cook Inlet Energy, LLC Permit to Drill Number: 216-170 Surface Location: 1910' FSL, 314' FEL, Sec. 14, T7N,R14W, SM Bottomhole Location: 848' FNL, 762' FWL, Sec. 30,T7N, R13W, SM Dear Mr. Ratcliff: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicableprovision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, PP P or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P Foerster Chair Sf- � DATED this day of February, 2017. STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMMIllpN DEC 2 3 2016 PERMIT TO DRILL AOGCC 20 AAC 25.005 1a.Type of Work: lb.Proposed Well Class: Exploratory-Gas LI Service- WAG ❑ Service-Disp LrJ'il 1c.Specify if well is proposed for: Drill ID Lateral CI Stratigraphic Test CI Development-Oil CI Service- Winj ❑i Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑✓ Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q v Single Well ❑ 11.Well Name and Number: COOK INLET ENERGY,LLC Bond No. 61212870 , REDOUBT UNIT#3A 3.Address: 6.Proposed Depth: 12.Field/Pool(s): ..?/O 601 W 5TH AVE STE 310,ANCHORAGE,AK,99501 MD: 16809' ` TVD: 12900'' 4a. Location of NII(Governmental� � Section): 7.Property Designation(Lease Number): REDOUBT SHOAL UNDEFINED/ Surface: ; FSL,37'1y'FEL,Sec.14,T7N,R14W,SM ' ADL 381203(surface),ADL 374002(TD) • UNDEFINED G.O.-WeNE•K Oil Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 573'FNL,230'FWL,Sec.30,T7N,R13W,SM LOCI 01-004 2/1/2017 Total Depth: 9.Acres in Property: rp3 14.Distance to Nearest Property: 848'FNL,762'FWL,Sec.30,T7N,R13W,SM 5Vf 91531 230'FWL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 90 • 15.Distance to Nearest Well Open Surface: x-200627.483 y-2449933.254 Zone-4 $ GL Elevation above MSL(ft): N/A to Same Pool: 2164' 16.Deviated wells: Kickoff depth: 14362 feet ' 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 48 degrees • Downhole: 5634 psi+ Surface: 4344 psi r 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6 3/4" 41/2" 15.1# P-110 DWC/C 2589' 14030' 10979' 16809' 12900' 487 cu ft 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 16940' 13016' 15691' 15691' 12034' unknown Casing Length Size Cement Volume MD ND Conductor/Structural 200' 30" N/A 200' 200' Surface 3507' 13 3/8" 6640 cu ft 3507' 3024' Intermediate 9332' 9 5/8" 645 cu ft 9332' 9416' Production — -- -- -- — Liner 5315' 7 5/8" 173 cu ft 14362'(KOP) 11096'(KOP) Perforation Depth MD(ft): 7780-7818'MD;14803-14860'MD;P&A'd Perforation Depth TVD(ft): 6203-6232'TVD;11410-11450'TVD perfs below 15691'MD P&A'd perfs below 20. Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program Q Time v.Depth Plot ❑✓ Shallow Hazard Analysis Diverter Sketch El Seabed Report❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name Stephen Ratcliff Title Sr.Drilling Engineer Signature \\ Phone 907-433-3808 Date 1 i-I i ( , Commission Use Only ` I Permit to Drill API Number: Permit Approval See cover letter for other Number: I(2— 1 '0 50- 733—a03_0—0/— Q0 Date: C9 it 1l requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: Z Other: SGC) /3,,.; 5_ Fre—:5' 1L Samples req'd: Yes No 0 Mud log req'd:Yes❑ No[/ /,./ ii-- HzS measures: Yes No❑ Directional svy req'd:YesQ'No❑ // Spacing exception req'd: Yes❑ No Z Inclination-only svy req'd:Yes III NoZ ie L4_Li:/ '. a ,.`�(1 Ce. c:� eti f y' ' • .,,,ems 1 ,c /« Post initial injection MIT req'd:Yes No❑1E- U l —;i��4,E-- id .. � ,`PA.. ;. aC., P. `"1 At 8 32_ l APPROVED BY Approved by: y- ;i43 rz��;�lr,-4 COMMISSIONER THE COMMISSION Date:2. ^l"[ / A, tz���6 � �-3� - 1T Qe 1 /..>\ Submit Form and o {b 0 e e 1 /��15T1 This permit is valid for 24 months from the date of approval(20 AAC 25.005(8)) Attachmerns in Duplicate • • GLACIER December 23rd, 2016 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 RECEIVED- Anchorage,Alaska 99501 DEC 232016 RE: Application for Permit to Drill Cook Inlet Energy, LLC: RU-03A AOGCC Dear Ms. Foerster, / Cook Inlet Energy (CIE) hereby applies for a Permit to Drill for Redoubt Unit 03A, located on CIE Lease Number 31203 and 374002, in the Redoubt Unit. RU-03A will be completed as a water injection well under Areawide Injection Order (AIO) 32. I Please find attached for review of the Commission the 10-401 Form, Drilling & Completion Procedures, Geological Information, Proposed Well Schematics, and Hazard Analysis, as required by 20 AAC 25.005. Additional information includes, MASP Calculations, Rig Layout, BOP&Choke Diagrams,as well as Mud, Cement, and Directional Programs. Glacier Rig 35 will be used to complete this work, commencing approximately February 1, 2017. If you have any questions,please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy(a Glacier Oil &Gas Corp. owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Stephen.Ratcliff@CookInlet.net 0: 907.433.3808 C: 907.433.9738 1 • • GLACIER F: 907.334.6735 1. RU-03A Requirements of 20 AAC 25.005(f) Well Summary Current Status: S avi-661 a- 3 Well is currently shut-in. e4 A- 5L-""°49 Scope of Work: 316 ' 612- • 1z• Set whipstock in 7 5/8" casing with top of window at+/- 14,362' M • Mill window in casing with 6 3/4" BHA • Drill 6 3/4" hole from KOP of 14,362' MD to 16,809' MD • Run 4 i" liner and cement • Complete 4 stage Frac o Frac Sundry to follow • Run completion o Completion Sundry to follow General Well Information: Reservoir Pressure /TVD: 5,634 psi @ 16,809' MD / 12,900'TVD MASP: 4,344 psi Wellhead Type/Pressure Rating: Vetco Gray- 5M -Wellhead Assembly BOP Configuration: 13 5/8" 10M BOPE -Annular/VBR/ Blind / Kill Line/VBR Well Type: Water Injector V Estimated Start Date: February 1, 2017 Drilling Manager: Conrad Perry (907) 727-7404 cperry@glacieroil.com Drilling Engineer: Stephen Ratcliff (907) 433-9738 sratcliff@glacieroil.com Production Manager: David Kumar (907) 433-3822 2 • • GLACIER dkumar@glacieroil.com 2. Location Summary Requirements of 20 AAC 25.005(c)(2) • General Location Kenai Peninsula Borough,Alaska • Osprey Platform Center Leg 3 - Slot#15 • Ground Elevation Offshore- N/A • Sea Bottom Elevation 45'to Mud Line • RKB 89' above MSL X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec/T/R Surface Location 200623.926' 2449936.607' 1962'FSL 271'FEL 14/7N/14W Kick Off Point 205501.73' 2442692.35' 120'FNL 572'FEL 24/7N/13W `Top of Injection Zone 206214.86' 2442047.22' 573'FNL 230'FWL 30/7N/13W l Bottom Hole Location 207093.64' 2440304.46' 848'FNL 762'FWL 30/7N/13W See Attachment 1: Slot Location See Attachment 2: Rig Schematic&Well Slots 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) BOP Configuration: 13-5/8" 10M BOPE -Annular/VBR/ Blind / Kill Line /VBR See Attachment 3: BOPE Schematic See Attachment 4: Choke Manifold Schematic See Attachment 5: Wellhead/ Tree Schematic 4. Drilling Hazard Analysis Requirements of 20 AAC 25.005(c)(4) Maximum Down Hole Pressure: Normal Pressured Reservoir Expected Reservoir Pressure = (0.052)*(8.4 ppg)*(12,900' TVD) = 5,634 psi . Maximum Anticipated Surface Pressure: MASP = (5,634 psi)-(0.1 psi/ft*12,900' TVD) = 4,344 psi . 3 • • GLACIER Shallow Gas Analysis: The wellbore is not expected to encounter any shallow gas. Potential Gas Zones: RU-03A has potential for encountering a depleted gas interval at+/- 11,300' TVD previously produced in RU-03. Potential Hole Problems Lost Circulation, Hole Stability, Stuck Pipe, & Coal Drilling, etc. 5. Formation Integrity Test Procedure Requirements of 20 AAC 25.005(c)(5) Prior to drilling out of casing strings, test BOPs,and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: • Drill 20' to 25' of new formation from the milled casing window and condition the mud to the same properties in and out. • Pull drill bit into the window and close pipe ram preventer. Line up to the choke manifold with a closed choke. • Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drill pipe pressures at 1/2 bbl intervals. • The Drill Site Manager will keep a running plot of pressure versus volume while the test is in progress. • Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. • Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) See Attachment 6: Casing Design Program See Attachment 7: Cement Program 7. Diverter System Information Requirements of 20 AAC 25.005 (c)(7) Not applicable for Sidetrack Operations 4 S GLACIER 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) INTERVAL MUD DEPTH I MUD WT PV YIELD FLUID LOSS CI LGS SYSTEM (ppg) (1b/100 ft2) POINT (m1/30min) (mg/1) (%) Surface N/A N/A N/A N/A N/A N/A N/A N/A Intermediate 11 N/A N/A N/A N/A N/A N/A N/A N/A Intermediate II N/A N/A N/A N/A N/A N/A N/A N/A Production I OBM 14,362'-16,809' 10.0-10.5 10-20 25-35 <5 160,000-200,000 <6% Production II N/A N/A 1/A N/A N/A N/A N/A N/A See Attachment 8: Drilling Fluid &Mud Program 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) Only applicable for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f). 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) Only applicable for an exploratory or stratigraphic test well, a seismic refraction, or reflection analysis as required by 20 AAC 25.061(a). 11. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) Only applicable for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of conditions as required by 20 AAC 25.061(b). 12. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of Bonding is on file for Cook Inlet Energy with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) 5 < 4110 • GLACIER December 9th, 2016 General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. Drilling Procedure Note: This is a continuation from the RU-03 Plug for Redrill Sundry procedure. The plug for redrill and sidetrack operationally is intended to be consecutive,pending AOGCC approval. 1. P&A Sundry Submitted separately. ——2,/6 " a. Verify timing for next BOP test and provide AOGCC with 48 hours notice if necessary. lr b. Verify 10.2 ppg mud volume and build additional if necessary prior to milling i°4( window. c. Verify 6 3/4" Mill/Whipstock/MWD BHA is set with top of window at 14,362' MD. i. Depth of Whipstock is shallower than originally planned to avoid milling a collar and into a coal. 2. Prepare to mill window. 3. Start milling window, per Service Company Procedure. a. Drill additional rat hole to clear the BHA, motor, and MWD tools. . b. Ream window as needed to assure there is little or no drag. 1(P� v c. After reaming: KO i. Shut off pumps and rotary (if hole conditions allow). ii. Pass through window checking for drag. 4. Drill 20' of new formation and circulate and condition mud. IP( a. If 20 ft of new hole is achieved with Milling BHA, Perform LOT. P" i:-.. �� 1 <1\- b. FIT/LOT Procedure included in Section 5 of PTD. 7 I e��, \- 5. POH and gauge mills for wear. a. Make additional run if window&mill are out of gauge. 6. Pick up 6-3/4" LWD. a. 6-3/4" SK613M-E1D PDC bit b. 4-3/4" Ultra Extreme Mud Motor- Need to Discuss Motor Bend with Engineer/Supt (Expect 1.5 degree setting) c. Stabilizer d. 4-3/4" Navi-Gamma, Density/Neutron LWD/MWD e. Stabilizer f. NM Drill Collars g. HWDP h. Jars i. HWDP j. 4" and 5" drill pipe so surface 6 • • GLACIER i. Detailed BHA and Hydraulics in SLB RU-03A Well Plan 7. RIH to 1000' &perform shallow MWD test. 8. Continue RIH to Window. 9. If Mill did not achieve 20 ft of new hole, drill additional new hole required for a total of 20' of new formation and circulate and condition mud. a. Perform LOT. 1 ,;w b. FIT/LOT Procedure included in Section 5 of PTD. 10. Directionally drill 6-3/4" hole to +/- 16,809' MD / 12,900'TVD, per directional plan. 11. Circulate hole clean with minimum of three bottoms up, or until hole is clean. 12.Short trip to window and CBU. a. Avoid back reaming if possible. 13.RIH to TD and circulate a minimum of three bottoms up, or until hole is clean. 14. POH to window and CBU. 15.Continue POH to surface. 16. Lay down BHA. 17. Rig up to run 4-1/2" Liner. 18. P/U 4-1/2", 15.1#, P-110 GeoConn Liner. a. This is a rotatable connection. i. Max torque of 13,000 ft-lbs ii. Max MU of 11,000 ft-lbs iii. Min MU of 9,000 ft-lbs b. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through top of Hemlock. ii. 1 Solid body spiral centralizer every other joint thereafter. c. Break circulation at Mill Window. d. Note: Swab and surge pressures of tripping are excessive with 4-1/2" liner in 6- 3/4" hole at this depth. e. Planned Liner Hanger depth at 14,030' (+/- 300' inside 7-5/8" casing shoe). 19. PU TIW Liner Hanger and Running tool BHA and RIH on 4" drill pipe to window. a. Establish P/U and S/O weights. 20.Continue to RIH to bottom. 21.Circulate and condition hole. a. Reciprocate liner while circulating. 22. Rig up and test cementers. .<23. Cement 4-1/2" liner per cement program. a Continue reciprocating liner while pumping cement. 12 b. Bump plugs with 3,000 psi - DO NOT over displace. 7 • • GLACIER 24.Set Liner/Hanger-Packer, per TIW Procedure. a. Release pressure and check floats and un-sting from liner. 25.Reverse out excess cement. 26. POH and L/D Running Tool. 27. Pick up Polish Mill BHA. 28. RIH and Clean out casing,liner top, and latch assembly in Liner Hanger. x`1'7 7c — ?da 29. Circulate hole clean. c kst j P 30.Test casing and liner lap to 3,500 psi for 30 minutes an d chart if past 24 hour CIP. 31. POH and L/D Polish Mill BHA 32. P/U +/- 2,600' of 2-7/8" drill pipe and MI Swaco Well Commander. a. Well commander in 4" DP section about 200' above liner top. 33. RIH to bottom and prep to displace OBM to fresh water+ 3% KCL. 34.Change over to completion fluid using appropriate spacers. a. Mix and displace with 8.5 ppg Water and KCl. b. After well has been displaced, filter brine as necessary to less than 20 NTU's. 35. POH and lay down all 2-7/8" and 4" drill pipe. 36. Rig up wireline and run CBL in 4-1/2" liner. rsr ,Ci. c 'Ih j 37. Evaluate Cement Bond Log. a. If squeeze is needed, confirm with CIE office on equipment and procedure. 38.P/U 4-1/2" 15.1# P-110 Geoconn Frac String. 'v-c skr -- 39. RIH to Liner top and latch per TIW Running Procedure. 40.Space out and land Frac tubing hanger. Completions Procedure 1. Frac Sundry and Completion Sundry to follow. See Attachment 9: Proposed Wellbore Schematic 8 • • GLACIER 14. Time vs Depth 4,1 i .....,...„ V ..rn4 m , • • $ ; as o _ L V « 0 J • 4+ o < a . on ar o . __ fi E F- 3 v QJ 1 .r _ w t o S. ......._«-..___. _.... .._ ..._._...�.��_.. N T a c T1 0 U ' 0 0 t _— ---- V ` r oa ' 8 8 H 8 8 H 8. 8, 8 8 8 8 U 4 8 y P 8 y (u)atni 9 • GLACIER See Attachment 10: Directional Program 15. Bit Program Size Description Nozzles TFA HSI Primary _ 6-3/4" PDC SK613M-E1D 3 x 14s 0.451 0.94 Backup 6-3/4" PDC SK613M-G1A 6 x 10s 0.46 0.90 16. Bottom Hole Assembly 6-3/4" Drilling BHA 6-3/4" bit 4-3/4" Mud Motor w/Stabilizer LWD/MWD (Triple Combo) / 4-3/4" NM Drill Collars 4" HWDP 43A" Jars 4" HWDP 4" Drill pipe 5"Agitator 4" Drill pipe 5" Drill pipe 17. Drilling Waste Storage Requirements of 20 AAC 25.005(c)(14) Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings and fluids will be disposed of in: f' Redoubt/Osprey Wells RU-D1 with the Grind &Inject Facility West McArthur Wells WMRU-D1 with the Grind &Inject Facility West Foreland Wells WMRU-D1 with the Grind &Inject Facility North Fork Wells TBD CIE will not request authorization under 20 AAC 25.080 for an Annular Disposal Operation in the well. / 10 . • GLACIER Solids Control and Equipment Item Equipment Specifications Shakers Derrick Hyperpool Shakers Desander 3 Cone Desander Desilter 24 Cone Desilter Centrifuge BOS Misc Equipment None 18. Geological Formation Tops Requirements of 20 AAC 25.071 Formation MD TVD Potential Kick Off Point 14,362' 11,096' Sidetrack Hemlock 15,750' 12,041' Oil (Injection) West Forelands 16,700' 12,801' Total Depth 16,809' 12,900' Additional detail provided in Geological Summary/Geo-Prognosis. See Attachment 11: Geo-Mechanical Plot See Attachment 12: Geological Prognosis 19. Logging Plan Requirements of 20 AAC 25.071 (a) Open Hole Logging • Production I Hole Section MWD/Gamma/Resistivity/Neutron/Density LWD logs are to be run continuously from kickoff point to Total Depth. A 1"=100', 2"=100', and 5"=100' MD and TVD log to be provided twice daily no later than 4:00 am and 2:30 PM Alaska time. Data to be emailed in pdf format and las format to personnel on list to be provided separately. Final Data in a las, pdf, and tiff formats to be provided on disc to Cook Inlet Energy in the Anchorage office, as well as to the State of Alaska AOGCC after logging concluded. 11 • • GLACIER Cased Hole Logging Engineers are to be provided a Borehole volume survey at TD in order to assist in determining cement volumes necessary. If well is cased for production, a Cement Bond Log / Cement evaluation Type survey is to be run from TD to shallowest potential evaluated in wellbore. A 1"=100' and 5"=100' MD and TVD log to be provided after each run. Number of copies to be determined and will include both paper copies and digital data. Data in a LAS and PDF format to be provided to Company man, Cook Inlet Energy Anchorage office, geologist, and State of Alaska AOGCC after logging concluded. A copy of the signed transmittal form, from AOGCC receipt of logs,will be provided to Cook Inlet Energy,Anchorage Office. Mud Logging Plan Mud Logging will not be conducted during RU-03A. 20. Regulatory Waiver and Special Procedures Requests AOGCC Regulation 20 AAC 25.071 Geologic Information Not Applicable AOGCC Regulation 20 AAC 25.235 Gas Disposition Not Applicable AOGCC Regulation 20 AAC 25.265 Automatic shut-in equipment SSSV o�r-The RU-03A w- as both an offshore BHL and SHL, ho . - - -, - expected bottom hole Ix pressure and oil comp• •n make it hi• I . i e y that the well will flow to surface Y ) 4 Y unassisted. CIE will install the c•' - ion and request a no flow certification under 20 AAC 25.265 (k) after stabiliz-• ` •w is establis - •. 1/`-' IE Re• s an extension of the time permitted to perform .1 •o flow test from 5 days to 30 J3 • - after start of production. AOGCC Regulation 20 AAC 25.265 Automatic shut-in equipment SSV CIE requests permission to install the Surface Safety Valve in the RU-03A completion in accordance with the AOGCC approved Surface Safety Valve arrangement for the other Redoubt Unit wells. The Surface Safety Valve will be located out of the vertical run of the tree. Vc. ! ! GLACIER Attachments 1. Slot Schematic 2. Rig Schematic &Well Slots 3. BOPE Schematic 4. Choke Manifold Schematic 5. Wellhead / Tree Schematic 6. Casing Design Program 7. Cement Program 8. Drilling Fluid &Mud Program 9. Proposed Wellbore Schematic 10.Directional Program 11.Geo-Mechanical Plot 12.Geological Prognosis TITLE NAME SIGNATURE DATE APPROVED Engineer- Originator Amanda Dial Engineer- Review Stephen Ratcliff Drilling Manager Conrad Perry 13 1 ill IP _._____. SECTION 14 T7N R1 SM A _ Mgr 10300 450 600 O RE PLATF•RM SCALE 1 inch =300 ft. �' 322' FEL GRID See Deta' •0, 269' FEL-- 7 WELL SLOT #8 WELL SLOT • #22 #12 WELL SLOT PT.NO.21 WELL RU-7 a e #g ,( CENTER LEG 3 e • WELL SLOT ` LAT:60°41'43.698"N #10 LON: 151°40'14.573"W #11 WELL SLOT N:2449936.607' WELL SLOT t...\V E:200623.926' OSPREY PLATFORM \V. ASP ZONE 4 NAD 27 ELEV SEA BOTTOM:-45'MLLW DETAIL 1"=20' #17 WELL RU D-1 PT.NO.6 #18 CENTER LEG 2 O WELL RU-2 LAT:60°41'44.155"N #19 LON: 151°40'13.520"W G0 WELL RU-1 N:2449981.637' Y Y, E:200677.509' e #14 ASP ZONE 4 NAD 27 WELL RU-4 ELEV SEA BOTTOM:-45'MLLWLL e #15#14/ CO #20 WELL Ru-3 rn rn #16 WELL RU-5 See Tabular Sheet for Well Slot Coordinates aw 1.BASIS OF HORIZONTAL AND VERTICAL ���`"\\,�' CONTROL WAS DETERMINED BY AN OPUS 41... OF A4,gsl�, SOLUTION FROM CORS BASE STATIONS Aliv"AC23 PID DM748"&"AC51 PID DD1812"& � . �� .. 4.- "KEN5 PID DJ3029"ALASKA STATE PLANE CO. Ili�\ •7 ,/ O NAD 83 ZONE 4 EPOCH 2010 HORIZONTAL / * J * � N DATUM AND NAVD88 VERTICAL DATUM /- nn / UTILIZING GEOID12A. / e'� •`;" - CO oil 2)SECTION LNE OFFSETS DETERMINED e• M.SCOTT McLANE . FROM PROTRACTED SECTION CORNER 4 VALUES. f,4928-S ••$ept 15,2015.•' 3)MLLW ELEVATIONS WERE DERIVED �1 FROM NOAA NAUTICAL CHARTS. /� NOTES '1%XN.N.S` Section Line , t /IIOSPREY PLATFORM COOK INLET, ALASKA ENGINEERING-TESTING WELL LOCATIONS NAD27 SURVEYING-MAPPING MCL,aNc_ P.O.BOX 468 CLIENT: SOLDOTNA,AK.93669 COOK INLET ENERGY, LLC VOICE: 283 32658 SUITE 310 Cook Inlet Energy ANCHORAGE,AK 99 01 FAX:(9 WWW.MCLANECG,COM Consulting Inc PROJECT NO. DRAWN BY: DATE: LOCATION: 133075 PROTRACTED SECTION 14 msm Sept 15,2015 TOWNSHIP 7 NORTH, RANGE 14 WEST SEWARD MERIDIAN,ALASKA ill • C Z W LU o 1- GO � � (w7L9oow LD w p U Z 3 I- I- I- F- F- n F- J v) Z • 01 CC 00000 O .-I Q In C V1 0 N N N N V)i K VJi '� f17 l0 p N ei L11 w U O d N J . . . . . . 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K a)- LL C C Z Z o 0 LU 1D N co 01 co) ,1 N N ,1 V V) LD N. co 01 O O yr U0 J ,1 ,--I ,-i N N ,1 ,1 ,--1 ,--1 ,1 ,--I N E (n o 4 s_vi L ELu en 0) a1 L- I- 1a p c a -07: '^ 2 co a T v Y 0 , p Y al in W 0 a < F ,.../ Q 1- CC p U• 0 4 a Z ci N m • MILLER RIG - 35 - Schematic acs leiiE *A ID.* 1 tri IIor t 1111 ! \.\\\)4, ,, MO A600 Leo iy. arl M !0 n ,`lw �. `r. ♦4 w r 1 __ C7g1�toGYt- 4t- ¢ it Et ISM , I i 4--. V s ' • . " t ' WO MI ' • 1 Imo 1 Ili , 1 it I _ . .> ..�,»---^ r/ A�4�bt S 117 nl - OSPREY _ 7 KILLING RIG ARRANGE.MI NT LAST SIDE APPiost DAG ___ a 3 VO LLS... TMMMMzhv. >pt I,�V9 ._.�_� _.. s OSPRIY (Yin. It g qt; _ . • CIE Rig 35 Redoubt Unit 13 5/8" 10,000 PSI BOP STACK 5000 psi Annular 10,000 psi 4" pipe rams Double Gate 4" outlets 10,000 psi DSA T/3" Both sides Blind Rams Double Gate 3" Kill line 3" Choke line Mud Cross 2 2 2 1 1= HCR Valve 10,000 psi 2=Gate Valve 4" Pipe Rams Single Gate 13 5/8" 5M Wellhead 13 3/8" Surface Casing 9 5/8" Intermediate Casing • o, _s o tn 6 -f-, u 3-6 d• le 5 pti a i L — --411111—k Of'W. _.--- n, ICU 1 E WOVE , ----4, --- _ 1 I _ c„. , __ i f c tn Co a) o A.111111 a -7:5' Y IP Lri V4 co> in O. o el> -0 (t10 ( 0 o., — 1.- 4011p-ic — 1 4411-1* Am.. - -.- c _ cu % — L = • E el iii = ECU igeesop ( tr 0 _() <407 , .4.0 . .0 6_,- 4, • ._____ cs I cL in OD 11) T.) `,. > c) '-'76 0 a — MI r1> Y In o cl .6 12I._.•, 71_+.0c 1 ro> #44!) TS /41Y CO X CO d — I I i ft-J. -'-. OrkAp\ — .-*-- * ___ _ O 111 S2 0 E 11101,11 II 0 11 - 1 :1 L d vroc4.00,..Af`..7 - v<44411110N. — 0 Cto til U Ln UD 3 d 11 03 (1) • 0-00 CO 0.. S U CO> • i Gri GE Oil & Gas ...'....,4 rrrr3fi.6' (16111..m.rn:::: 3-1/E"5M 1 O O o � StI6"SM i a...,.1114: : -al :' — la0).igl it, 3-1/8"5M It U.0 Jf. ,),"&$`,7‘:, N-IN 1� J V 11J.5' 13-5,8.5M of 200" Li— 29.9" , LLL l 0Ilel 27 2'to f it I' �' j:,t.1 PHI is ENIIlittillIll • /♦ e M 2-116.5 a61' Ed' d Y,02 ' I I .; 1,Ai 1 10 1 ',' I I. 1 13-3/B"Casing -5.Er Casing ALL DIMENSIONS ARE APPROXIMATE t II CT ENERGY This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing, COOK I I V LE I CI V ERGY neither it nor its contents may be used,copied.transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. OSPREY PLATFORM RU-03A W 13-3/8" x 9-5/8" x 3-1/2" x 2-7/8" 5M Multibowl Wellhead DRAWN CR 06DEC16 APP RV KN 06DEC16 Assembly With MB-205 Tubing Head and Tubing FOR REFERENCE ONLY Hanger and Adapter Flange DRAWING NO. HP160203-3 Cook Inlet Energy Casing Plan WELL NAME: RU-03A Well Information ENGINEER: Amanda Dial DATE: 20-Dec-16 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Weight(ppg) Pressure) Shoe 30 200 200 -- -- -- -- -- Conductor pipe 16" 13 3/8" 3,507 3,024 8.3 15.0 9.5 10 -- Previously Set on Original RU-03 Well 12 1/4" 9 5/8" 9,332 9,416 8.3 15.0 9.5 10 -- Previously Set on Original RU-03 Well 8 1/2" 7 5/8" 14,362 11,096 8.3 14.0 9.5 10 -- Whipstock and Window Lower Hemlock&West Forelands- 6 3/4" 4 1/2" 16,809 12,900 8.4 15.0 10 10.5 OBM Abnormal Pressure Gradient Casing Plan 'ENTER YELLOW CELLS MANUALLY Casing Size Connection API rating Wt(lb/ft) Grade Collapse Tension MD(ft) TVD(ft) (in) Type OD(in) Burst(psi) (psi) (kips) 30 150 A36 PE -- -- -- -- 200 200 13 3/8" 68 L80 BTC 10.63 5020 2260 952 3507 3024 9 5/8" 47 L80 BTC-M 10.625 6870 4760 1122 9332 9416 7 5/8" 29.7 L80 Hydril 521 8.5 6890 4790 683 14362 11096 4 1/2" 15.1 P110 U-DQX 5 14420 14350 406 16809 12900 Variables & Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.433 psi MAWP=(0.80 X CASING BURST) or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.Sppg SF)X TVD)-GasGRD X TVD)) or (Max Pore Pressure-(GasGRD X TVD)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X TVD SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) IPMax Allowable Working Pressure =(0.80 X CASING BURST) or Limiting Wellhead Pressure Hole Sizes Casing Size Safety Wellhead MD(ft) TVD(ft) Burst(psi) MAWP(psi) (in) (in) Factor (psi) 16" 13 3/8" 3,507 3,024 5020 0.8 5,000 4016 12 1/4" 9 5/8" 9,332 9,416 6870 0.8 5,000 5496 8 1/2" 7 5/8" 14,362 11,096 6890 0.8 5,000 5512 6 3/4" 4 1/2" 16,809 12,900 14420 0.8 5,000 11536 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg)X TVD)-GasGRD X TVD)) or (Max Pore Pressure-(GasGRD X TVD)) Hole Sizes Casing Size Max EMW Frac Grad at MW Safety Gas Frac Max PP at MD(ft) TVD(ft) Pressure at MASP(psi) (in) (in) (ppg) Shoe Factor Gradient Next TVD Shoe 16" 13 3/8" 3,507 3,024 8.3 15.0 0.50 0.10 2135 364 364 12 1/4" 9 5/8" 9,332 9,416 8.3 15.0 0.50 0.10 6648 2,954 2,954 8 1/2" 7 5/8" 14,362 11,096 8.3 14.0 0.50 0.10 7257 3,499 3,499 C4,345 6 3/4" 4 1/2" 16,809 12,900 8.4 15.0 0.50 0.10 9107 4,345 Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X TVD Hole Sizes Casing Size Safety Max EMW MD(ft) TVD(ft) Burst(psi) MW (Pore MASCP(psi) (in) (in) Factor Pressure) 16" 13 3/8" 3,507 3,024 5020 0.8 10 8.3 3749 12 1/4" 9 5/8" 9,332 9,416 6870 0.8 10 8.3 4664 8 1/2" 7 5/8" 14,362 11,096 6890 0.8 10 8.3 4531 6 3/4" 4 1/2" 16,809 12,900 14420 0.8 10.5 8.4 10127 Safety Factors Hole Sizes Casing Size Collapse Tension Liner Length SAFETY FACTORS MD(ft) TVD(ft) Burst(psi) Wt(lb/ft) (in) (in) (psi) (kips) (ft) Burst Collapse Tension 16" 13 3/8" 3507 3024 5020 2260 952 68 - 13.8 2.3 4.0 12 1/4" 9 5/8" 9332 9416 6870 4760 1122 47 - 2.3 1.5 2.6 il 8 1/2" 7 5/8" 14362 11096 6890 4790 683 29.7 5259 2.0 1.3 4.4 6 3/4" 4 1/2" 16809 12900 14420 14350 406 15.1 2779 3.3 3.3 9.7 SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) • • TECHNICAL DATA SHEET 4.5 " • 15.10 # • P-110HC ULTRA-DQXTM Premium Connection ULTRA Premium Oilfield Services is one of North America's leading manufacturers of Premium threaded connections for the global exploration and recovery of Oil and Gas Ultra connections date back to the early 1990's, when two engineers.the late Erich F Kiementich. PE and ULTRA's Ed Banker PE designed a unique full contact thread form with run-in/run-out threads to produce the strongest connections in the industry today The ULTRA DCA is a threaded and coupled casing connection designed for drilling with casing and rotating with casing applications It has a low cost high tech premium thread form which resists fatigue stresses more effectively than API Buttress threads Connection Parameters Efficiency-Tension 100% Efficiency-Compression: 100% Optimum Torque' 8,300 ft-lb Yield Torque 13,200 ft-lb Max Uniaxial Bend* 112 deg1l00f1 Minimum Internal Yield Pressure 100% Collapse Pressure: 100% 'Maximum uniaxial bending is the calculated value at which the connection would yield in simple 2-dimensional bending Note The information in this Technical Data Sheet is for general information only tl shotAd not be used or relied upon for any specific application without being independently verified by competent professional examination for accuracy suitability and applicability Anyone utilizing the information contained herein does so at their own risk phone:281-949-1023 T toll free:888-258-2000 MK 4 5 x 15 1 P-110HC DQX Data Feb 2012 Rev 0 I f P rJ C ) • I TECHNICAL DATA SHEET 4.5 " • 15.10 # • P-110HC ULTRA-DQXTM Premium Connection Pipe Dimensions �_._. Size. 41/2 inches Nom Wt-ft: 15.10 ibsttt Grade P-110 PE Weight 14.98 lbs/ft Wall Thickness 0.337 inches Nominal ID 3.826 inches Drift Diameter 3.701 inches Nominal Pipe Body Area 4.407 sq-inches Pipe Parameters Minimum Yield 110,000 psi Minimum Ultimate 125,000 psi Pipe Bow Performance Yield Strength 484,800 lbs Tensile Strength 550,900 lbs Minimum Internal Yield Pressure 14,420 psi Collapse Pressure 15,500 psi Connection Parameters Coupling 00(Nom) 5.000 inches Coupling ID 4.271 inches Coupling Length 7.544 inches Box Critical Area 104.4% %PBYS Pin Critical Area 100% %PBYS Yield Strength in Tension 484,818 lbs Fracture Strength 535,400 lbs Make-Up Loss 3.772 inches Percent of Pipe Body Fracture 97.2% Max.Uniaxial Bend Rating 112 deg/100ft Min. Internal Yield Pressure 14,420 psi Collapse Pressure 15,500 psi Minimum Make-Up Torque 7,470 ft-lb Make-Up Torque 8,300 ft-lb Maximum Make-Up Torque 9,130 ft-lb Yield Torque 13,200 ft-lb Tension Efficiency 100.0% Compression Efficiency 100.0% t dole The inlormation in this Technical Data Sheet is for general information only It should not be used or relied upon for any specific application without being independently verified by competent professional examination for accuracy. suitability and applicability Anyone utilizing the information contained herein does T, • rin so at their own risk. phone:281-949-1023 r r toll free:888-258-2000 45, 151 P-110HC DOX Data Feb 2012 Rev 0 I PSCO TECHNICAL DATA SHEET 4.5 " • 15.10 # • P-110HC ULTRA-DQXTM Premium Connection Make-Up Torque(Ft-Lbs) Minimum Optimum Maximum Yield 7,470 8,300 9,130 13,200 Maximum Makeup Torque Torque +10%of Optimum Makeup ._...... ».._...».».. ....»...»...........»......».»......_..... . .._.. Optimum Makeup Torque Minimum Makeup Torque -10%of Optimum Makeup Maximum Shoulder Torque 70%of Optimum Makeup r i1.Thread Interference 2.Shoulder Torque 2 ) Optimum Shoulder Torque 1 ' Minimum Shoulder Torque . — ___._._...._.._ »._ 10%of Optimum Makeup No Interference --•`"': Turns For Help Please Call Our ULTRA Field Service Manager: Mobile(432)557-1916 Office(432)367-3201 Fax(432)332-5019 Note. The information in this Technical Data Sheet is for general intornrauon only --- It should not be used or relied upon for any specific application without being independently verified by competent professional examination for accuracy. suitability and applicability Anyone utilizing the information contained herein phone:281-949-1023 rt does so at their own risk toll tree:888-258-2000 45x151P.110NCD41XData Feb2012Rey 0 (QrJCO • s TECHNICAL DATA SHEET ULTRA-DQX Premium Connection 100% Threaded and Coupled •High tech premium thread form which resists fatigue damage -Superior leak resistance under cyclical torsion loading •Pressure ratings exceed API minimum internal yield and collapse a r$; I t , FullContactTM Threads •Tension and compression efficiency •High bending capacity and evenly distributed stress 1 •Deep,easy stabbing and quick. F s*� easy make-up •Leak-tight thread sealing 2 t Pin Nose to Pin Nose Positive Torque Stop P = w-- .,�-- .i •Excellent torque resistance IALIUMI •Torque energized metal seal •Reduced coupling fatigue I. '_ 1 Elrc •Verifiable make-up with positive torque tIKIIIIIIIIMII shoulder t •Superior over-torque drift-ability •Minimized flow turbulance I ', .11111111115 I 4 — R •Out Threa i:,. • unMaximum critical section area • Low interference run-out threads enhance fatigue life • , I Note. The information in this lechrcai Data Sheets for general information only It should not be used or relied upon for any specific application without being independently verified by competent professional examination for accuracy. suitability and applicability Anyone utilizing the information contained herein T1 hone:281-949-1023 does so at thea own risk P Tr;',N. v toll free:888-258-2000 n 4.5 x 15.1 P-110HC DQX Data Feb 2012 Rev 0 i .) • • yr te. f oevoolivoi p, i `‘ 6'> String: 4.5-in Production Liner Well Name: RU-03A WI Company: Glacier Oil & Gas Field: REDOUBT SHOAL Contact: Amanda Dial Well Location: Cook Inlet,Alaska (Offshore) Well Number(API): Osprey Platform County: State: Proposal Number: 4 Date: 12/15/2016 Made By: Stephen Lauper Service from District: Kenai,AKA District Phone: Objective: Fully Cement Liner iwth Returns circulated off of liner top Acceptance Criteria: Pump per design (Volume, Density, Rate) Disclaimer Notice Schlumberger surements,this uaumestndhfthe mnesbenefit at itsr jndgmeaLb�erience,and good oilfield practices Schlumberger This information is provided in accordance with generally accepted industry practice,retying on facts a information provided by others,limitations,computer models measurements,assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only NO WARRANTY IS GIVEN CONCERNING ACCURACY DR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. • • Well Data Summary The cementing program incorporates the following data : All depths take the rig floor as reference RigType Offshore Mud Line Depth 345.0 ft Fluids Return to Water Depth 185.0 ft Mud Return Depth 79.0 ft BHST 198degF Section MD 16809.0 ft Section TVD 12900.0 ft Tubulars and Casing Hardware MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in psi psi Prey Casing 9103.0 9 5/8 _ 40.0 47.0 8.681 L-80 _ 4750 6870 API 14379.0 7 5/8 40.0 29.7 6 7/8 L-80 4790 6890 API Drill Pipe 9103.0 5 40.0 19.5 4.276 E75 10000 9500 API 14030.0 4 40.0 14.0 317/50 S-135 20140 19490 API Liner 16809.0 41/2 40.0 15.1 3.826 P-110 14340 14420 API Liner Hanger 14046.4 4 1/2 40.0 15.1 3.826 14340 14420 Landing Collar 16729.0 Serial number : MC on Inclination tdeg; m mi E,e- Horizontal Departure(ft) 0 10 20 30 40 50 - AMC !MC m„ nxoo G1 0. —Ind atbn(deg) —Horwitz'Departure( ) g 5�DrNPpe, , : ) not ( 95BinCasiri v «j I Zb 0 e0 in ,i-4inDeiPpe] a{ 5o m Casa* r 12846fl lio `a-er c'. ,,e c' c '4 V2 n finer- c c „. Fkk F c. Cam 1 \. 16377 P. 168091...__ q E E. 16974 c R; 2 of 18 Schlumberger • 40 Open Hole Total Volume 119.5 bbl Minimum Diameter 6.750 in Maximum Diameter 6.750 in Mean Diameter 6.750 in Mean Annular Excess 20.0% Mean Equivalent Diameter 7.115 in Mc Oft Ib'gal 345ft — c 10 11 12 13 C c: i Pore Pressure ED(b'gar Frac Pressure ED(tbigeh s C. C 1____r � 9103 ft 7229 ft '� O O v T m v c i , 12846't ,,; .._..,.__t_ 13634 t10715ft t i 14379*11108 ft M'' C 1 . :tigni 105= I 16729t_12827ft L—L ;t.... i 16974*16974 ft 1 C C: C. N. Formation Frac Pore Top Bottom Bottom Frac Bottom Pore Bottom Res. MD MD TVD Top ED ED Top ED ED Lithology Fluid Name ft ft ft lb/gal lb/gal lb/gal lb/gal 345.0 16974.0 13065.0 4.59 13.00 4.59 9.00 3 of 18 Schlumberger • 1111 • Temperature Relative Name Top MD Bottom MD Bottom TVD Temperature Gradient Gradient Sea Current ft ft ft degF degF/100ft degF/100ft ft/min Surface 0.0 0.0 0.0 80 0.00 0.00 SeaLevel 0.0 160.0 160.0 80 -0.02 -0.02 10.13 SeaBed 160.0 345.0 345.0 73 -2.15 -4.00 10.13 Rock 345.0 16000.0 12220.8 191 0.91 _ 1.00 0.00 Rock 16000.0 16809.0 12900.0 198 0.92 1.00 0.00 Geothermal Profile rdegF: 80 100 120 140 160 180 200 o wl — otherrr tem;.(de9F;, c\i N oa m 0 cs c v C> c, o m cz c> `N o r ID S OD 0 4 of 18 Schlumberger • • Fluids Summary Fluids Type Name Density Conditions K n Ty lb/gal lbf.sAn/ft2 lbf/100ft2 Drilling Fluid Mud 10.10 Custom 175 degF[T2] 8.00E-3 0.60 5.92 Spacer CemPRIME SCRUB 11.50 Manual 7.43E-2 0.28 9.43 OBM Slurry Production Cement 15.30 Manual 1.37E-3 0.92 9.77 Drilling Fluid Produced Water 8.50 Surface 68 degF 7.89E-4 0.58 0.79 *Compressible Rheology Parameters and Densities are displayed at P=1 atm and T=20 degC(65degF) SSI '—Rheobgy Mud(Ib i1 DOit2) Rheology CemPRIME SCRUB GBM (INA DOft2) o Rheobgy Production Cement (mft1DOR2) —Rheobgy Produced Water(Ibfi103112' 0 Ccs c*i etei 0 200 400 600 800 1000 12C:C Shear Rate(Vs) 5 of 18 Schlumberger S 4111 ,• Mud Circulation Fluid Mud Ambient Temperature 110 degF Number of Circulation 1.55 Correction Slope 0.00 Total Volume at Ambient T 1440.0 bbl Pumping Stages Fluid Pump Rate Duration Volume bbl/min hr:mn bbl Mud 8.0 03:00 1440.0 Well Security Status Description Min Differential At Depth At Time Pressure ft hr:mn psi Success Fracturing 1316 14379.0 03:00 Success Production/Influx 605 14379.0 03:00 Success Burst 8102 79.0 03:00 Success Collapse 9457 9103.0 03:00 A psi E:,-: 0 200C 4000 6000 8000 1000 * '3 o § c) Pore Pressure(pso Frac Pressure lost) x co 8 c, —Max Annular Pressure(psi) -2 — r=, c -4. Min Annular Pressure(psi) E i= 2 \ — \ ti 0_ -0 ,-- — 2 8 8 I : . g R 8 \. Er 8 --------- _. 8' Time(hrmn) 6 of 18 Schlumberger • II ...,,,,,,,,- . . .,,,,,, .,, , ,, ,,.7,....„:.,-,:-,,,,, ' . .. ,..„ ,, . .., ..* ,i. .. ...... , ,_,--- ---,..--,-.-..=.40.-.„ ..,_ Fluid Placement Surface Densities are computed at P=1 atm and T=Surface Temperature(80 degF) Fluid Placement in Annulus Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl Ib/gal Mud 79.0 12846.4 12767.4 555.2 10.10 CemPRIME SCRUB 12846.4 13834.2 987.7 30.0 11.50 OBM Production Cement 13834,2 16809.0 2974.8 86.8 15.30 Fluid Placement in Pipe Fluid Name Top MD Bottom MD Length Volume Surface Density ft ft ft bbl lb/gal Produced Water 0.0 16377.4 16377.4 248.5 8.50 CemPRIME SCRUB 16377.4 16729.0 351.6 5.0 11.50 OBM Production Cement 16729.0 16809.0 80.0 1.1 15.30 MD Oft Produced Warr 9133 ft Cemf-.`.'E SC JB. 12846ft D3M 1363411 -Prdlcon Cement _,_. 14379 it CemPRIME SCRUB Produdron Cement j /NM Mud 16377 ft t6969 ft _ 16974 ft 7 of 18 Schlumberger • • IIIPF Pumping Schedule Pumping Schedule Pump Injection Cumulated Fluid Name Duration Volume Rate Temperature Comment Time hr:mn bbl bbl/min degF hr:mn CemPRIME SCRUB 00:05 30.0 6.0 68 00:05 OBM Pause 00:05 - 00:10 Production Cement 00:15 87.9 6.0 68 00:25 Plug 00:10 00:35 CemPRIME SCRUB 00:01 5.0 6.0 68 00:35 OBM Produced Water : 00:35 248.5 > Produced Water 00:30 238.5 8.0 68 01:05 > Produced Water 00:05 10.0 2.0 68 01:10 Maximum Required Hydraulic Horsepower(HHP) 483.1 hhp(at 01:05 hr:mn) 8 of 18 Schlumberger • • ,* ,rr —Ptan,rate(bbennin) Return Rate ibbUmin) is 00 00 00:20 0040 :;i cc Time(hymn; —Pump pressure(psi) —Cement head pressure(psi) / 00:00 00:20 00:40 01:00 Time(hrmn) m csito —Bottom note pressure ED(tigal) Pore Pressure At Bottom Hole Frac Pressure At Bottom Hole c‘, _Static pressure at bottom ED(Ib'gaq ED(Wgal) ED tom) cci OU) 00:00 0020 00:40 01:00 Time(hrmn) 9 of 18 Schlumberger • • Well Security Well Security Status Description Min Differential At Depth At Time Pressure ft hr:mn psi Success Fracturing 890 16809.0 01:05 Success Production/Influx 605 14379.0 01:01 Success Burst 7124 79.0 01:05 Success Collapse 8243 7759.2 00:46 N/A Dead-End Collapse 0 0.0 00:00 N/A Dynamic u-tubing in Dead-End 0 0.0 00:00 N/A Balanced u-tubing in Dead-End 0 0.0 00:00 F^i C 2000 4000 6000 _-C_ 1C C 0 0o 0 Pore Pressure(psi) —Max Annular Ptesute,,psis —Pam nnnuiat Pressure;ps+. <, Frac Pressure(psi) 0 00 sr _ 0 1 00 0 vt a o ., 0 a v0 00 N 4 8 c 00 ! O 00 O 0 O 0 10 of 18 Scblumberger • i Temperature Outputs Temperature Summary Table Static Temperature.at TOC 176 degF Static Temperature at BH 198 degF Simulated HCT at TOC 154 degF Simulated HCT at BH 167 degF Max First SK Temperature 167 degF Max Last SK Temperature 167 degF At time 00:57 hr:mn At time 01:10 hr:mn c sc, T at Bottom Hole{degF) _Mud i CemPRIME SCRUB OBMc Interface Temp{degf CemPRIME SCRUB OBM/Production Cement Interface Temp(degF) o Producton Cement)CemPRIME —SCRUB OBM Interface Temp {degf) LL ,� —CemPRIME SCRUB OBM I Produced g / Water Interface Temp(degF) c — / 0 m 0 co 00 00 00 2C 00:40 01:00 Time(hymn) degF 60 80 100 120 140 160 180 200 0 F%) —Geothermal temp. degF i T m annulus at ume,oe;F " ` T m pipe at torte(degf) 00 o \ 33 O O • `\ O \ \ co N o o N O c O ` � g ~` 88 11 of 18 Schlumberger • • ', 9 :',0° ,0- Centralization Centralizers Commercial Alias Manufacturer Name Type Config Csg OD Min OD Max OD Count in in in SPIRAGLIDER HD-4 Hannover Not Set rigid Not Set 4 1/2 6.252 6.252 0 1/2-4-SPI RAL650 SpiraGlider HD-5 0-4- Hannover SpiraGlider HD rigid Spiral 5 6.252 6.252 0 Spiral650 1502041-41/2-4- Houma 1502041 rigid Positive 41/2 6.500 6.500 60 Positive Pattern Placement Bottom MD Joints Centralizer Alias Pattern Min STO Depth ft ft 14418.0 9.29 - 0 0.0 14052.9 16809.0 59.77 1502041-4 1/2-4-Positive 1/1 0.0 14423.1 n- MC r,ft C 20 1-.. 6080 t f.n 3458 _ -"m i ------ P'.-- 'a.e Q Mud _Brandon I:4 ce+mafizers 8 Standoff at oentrai¢ers I L i 0 8 1E 1 9103* .i N SO Q QQ ,� I 73834 R I l , C:emPRIME SCRUB 111_ I i Production Cenen; r... ..._. r 14379 R.. ( I ICemPRIMEOBM SCFUB }§ 1*Production Cernen; 163771 Mod 16729 t 16974 t Computation time:Cement Turns 00:56 12 of 18 Schlumberger ! ! .„ WELLCLEAN* III Average Fluid Concentrations Average fluid concentration in annulus Average fluid concentration in pipe Average Concentration(ib) Average Concentration(%) 0 20 40 60 80 100 20 43 60 80 100 120 —Mud in ann.;;%y —Mud in pipe(%) _ CemPRIME SCRUB OEM _ CemPRIME SCRUB OBM in ann. . n Production Cement in ann. Production Cement in pipe (%} (%) —Produced Water m ann. i -Product Water in pipe; CDS L G � N 8 8 a 88 o ' 8 13 of 18 Schlumberger • • • . nP Final Fluid Concentrations Oft 315ProducedWaim t --- Atid111 i asoa_ ss issoo • t SGiiG 9103* 65GG_ 12646t Cc9-P7`AE SC=!E. 4 ' 8t°1 Fr..'J.;..: r Cenen: 13934* 14379* Fluids concentrations - Mud CeirP='.`--qE SC EJJE. - 03M CemPRIME SCRUB OBM Frcd�c'i�r Cenpn2 Production Cement 16377t Mid - — Produced water 16729 t 16974 t 4 of 18 Schlumberger i Post-Processing Results (Annulus) 14500 15000, 15000._ 1,500 { •.�, 10000 i 0s�00_ 16500 Contact Time(second) Mud On Wall Risk - a 0 NE None III675 3 1.1 Low 1350 7 Medium 2026.0 High al2701.4 15 of 18 Schlumberger • • 4 Operator Summary Volume Summary Prepared Fluid Mix Fluid Dead Silo dead Fluid Name Pumped Volume Dead Volume Prepared Fluid Volume volume bbl bbl bbl bbl ton Production Cement 87.9 5.0 92.9 0.0 0 CemPRIME SCRUB 35.0 15.0 50.0 0.0 0 OBM Material Summary Additive Pumped Required Loadout Loadout Pack. Pack. Comment Quantity Quantity Quantity Items Name Size D031 6142.6 lb 8775.2 lb 8775.2 lb 79.77 sack 110.0 lb Fresh Water 3328.1 gal 3940.9 gal 3940.9 gal 0.00 0.0 gal D182 149.2 lb 213.2 lb 213.2 lb 4.26 sack 50.0 lb D047 7.0 gal 10.0 gal 10.0 gal 2.00 pail 5.0 gal F103 70.0 gal 100.0 gal 100.0 gal 1.82 drum 55.0 gal U066 70.0 gal 100.0 gal 100.0 gal 0.00 0.0 gal Production Cement 34493.1 lb 36454.2 lb 36454.2 lb 0.00 bulk 0.0 lb Blend D046 69.0 lb 72.9 lb 72.9 lb 1.46 sack 50.0 lb D202 172.5 lb 182.3 lb 182.3 lb 7.29 sack 25.0 lb D400 275.91b 291.6 Ib 291.61b 11.67 sack 25.Olb D154 2759.4 lb 2916.3 lb 2916.3 lb 29.16 sack 100.0 lb D174 517.4 lb 546.8 lb 546.8 lb 10.94 sack 50.0 lb D198 17.2 lb 18.2 lb 18.2 lb 0.36 sack 50.0 lb 16 of 18 Schlumberger • • Fluid Preparation Production Cement Pumped Volume:87.9 bbl Density: 15.30 lb/gal SVF:40.4% Yield : 1.35 ft3/sk Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Dry Phase 38304.6 lb 40482.3 lb Production Cement Blend: 94.0 lb per sack 34493.1 lb 36454.2 lb 36454.2 lb -G 94 lb/sk WBWOB 34493.1 lb 36454.2 lb 36454.2 lb D046 0.2%BWOB 69.0 lb 72.9 lb 72.9 lb D202 0.5%BWOB 172.5 lb 182.3 lb 182.3 lb D400 0.8%BWOB 275.9 lb 291.6 lb 291.6 lb D154 8.0%BWOB 2759.4 lb 2916.3 lb 2916.3 lb D174 1.5%BWOB 517.4 lb 546.8 lb 546.8 lb D198 0.1 %BWOB 17.2 lb 18.2 lb 18.2 lb Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity Total Mix Fluid 5.965 gal/sk VBWOB 2188.6 gal 2313.1 gal Fresh Water 5.965 gal/sk VBWOB 2188.6 gal 2313.1 gal 2313.1 gal CemPRIME SCRUB OBM Pumped Volume:35.0 bbl Density: 11.50 lb/gal Weighting Material Concentration Pumped Quantity Required Quantity Loadout Quantity CemPRIME SCRUB OBM 4.18 lb/gal WBVOSpacer 6142.6 lb 8775.2 lb 8775.2 lb Weighting Material: -D031 4.18 lb/gal WBVOSpacer 6142.6 lb 8775.2 lb 8775.2 lb Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity Total Liquid Phase 0.9 bbl/bbl BVOSpacer 1300.0 gal 1857.2 gal Fresh Water 0.8 bbl/bbl BVOSpacer 1139.5 gal 1627.8 gal 1627.8 gal D182 5.50 lb/bbl WBVOBF 149.2 lb 213.2 lb 213.2 lb D047 0.2 gal/bbl BVOSpacer 7.0 gal 10.0 gal 10.0 gal F103 2.0 gal/bbl BVOSpacer 70.0 gal 100.0 gal 100.0 gal U066 2.0 gal/bbl BVOSpacer 70.0 gal 100.0 gal 100.0 gal 17 of 18 Schlumberger • • 4-4 Y" Document Control Document Name and Version : Once approved by Schlumberger and the Operator,any deviation from this program requires document agreement(SLB QHSE Standard S010 Management of Change and Exemption Standard) Approvals Name Signature Date Author Stephen Lauper Schlumberger review Rianne Campbell Schlumberger Approval Customer Approval Amanda Dial "By signing this document (or confirmation email), I confirm I have reviewed and approved it as the basis for the well cementing program." Distribution List : Cementing Program Generated From Cementics File ru-03a_designv2.jdcx Cementics Version 2016.2.70 Revision History Date Version Description Author 12/15 V4 Updated Liner Depths and Directional slauper References Version Planned Date received Originator Filename or actual Well Trajectory P6 18 of 18 Schlumberger Mi SWAG CI0 . AS`"'"""bow, `°""""" Cook Inlet Energy Redoubt Unit: RU-3A INTEGRATED FLUIDS ENGINEERING DRILLING FLUIDS PROPOSAL RU-3A SIDETRACK WATER INJECTOR COOK INLET ENERGY ALASKA .�•_ _ ._ _ ... ,, ii—/ I ' rid 0 41 .`i , 1 A Owner Approver Approver Approver Signature: Date: Name: Tony Berrigan Ray Figueroa Stephen Ratcliff Amanda Dial Job Title: Fluids Project Engineer Operations Manager Sr. ODE ODE Ver.1.1 Draft M� SWACO • • A Sc Mumb.sie,Cmpd,„ Cook Inlet Energy Redoubt Unit: RU-3A Distribution Company/ Name Role Glacier Oil&Gas Leadership Stephen Ratcliff Sr. ODE Amanda Dial ODE M-I SWACO Onsite Drilling Fluid Specialists Field Drilling Fluid Specialists Maintaining proper Document Control and Management of Change(MOC)are critical with regard to the development of appropriate well design. No changes will be made without being supported by the appropriate documentation and described below in table. For changes needed after Pre-spud date a MOC process must be implemented. Once the MOC process has been completed,the revision change must be noted in the box below with MOC log #. Version Date Description 1.0 draft 9/25/2016 Original draft 1.1 draft 12/9/2016 modified Liability and Obligations Statement and Checklist This document has been prepared in good faith but is provided without warranty under the general hold harmless provisions of the contract. M-I SWACO document approvers in signing this document and annotating this checklist warrant that they are both competent to sign the document and that it has been prepared taking into account the information below Ver.1.1 Draft INA II SWACO • Cook Inlet Energy • Redoubt Unit: RU-3A The RU-3A will be a sidetrack (water injector) well with a window cut in 7-5/8" casing on the Osprey platform/Rig 35. At this time the expected 6-3/4"production interval formation pressures should be drilled with a mud weight of" 10.2ppg. The well will be sidetracked from a window cut in the existing 7-5/8"casing at a depth of X14,326 MD and the production interval drilled to a depth of 16,809' MD/12,900TVD. — Clean pits and build OBM (onsite seed mud and LVT available) — Displace well bore (produced water) with OBM (review spacer design) — Clean out BHA run — RIH set Whip stock — Mill window — PU 6.75"drilling BHA — Drill sidetrack to 16,974' — 4-1/2 liner run/set/cemented/CBL Hole Casing Mud Size Size Casing MD TVD Mud Weight (in) (in) Pro.ram (ft.) (ft.) System (lb./gal) 9-5/8 na 47# 7-5/8 (TOL 9,103") 29.7# 1KOP6 OBM 10.2 6.875(ID) window 6.75 4.5 16,809 12,900 OBM 10.2 Ver.1.1 Draft Mr SWAGO • . Cook Inlet Energy Redoubt Unit: RU-3A Estimated Drilling Fluid Costs Engineering Depth Interval Costs Interval Cumulative (ft.) Product Costs ($) Days Cost Cost ($) 2 Eng. _ ($) ($) Window and Open Hole $150000 $22,000 10 197000 177000 Completion/Frac TBD Total Estimated Cost $ Recycled fluid Company owned Oil Based mud shall be utilized as required. Estimates shown for new fluid build for sidetrack drilling. Initial load out list(new fluid) MI Wate 63.0 PPB 103,317 lbs 2,066 sacks 20.7 pallets $11.09 $22,915.74 VG Supreme 2.0 PPB 3,280 lbs 66 sacks 2.0 pallets $159.68 $10,474.72 LIME 5.0 PPB 8,200 lbs 164 sacks 2.7 pallets $25.55 $4,190.08 Actimul 8.0 PPB 13,120 lbs 525 sacks 1.0 pallets $0.00 $0.00 CaCI powder 50Ib _ 60.0 PPB 98,397 lbs 1,968 sacks 1.0 pallets $29.99 $59,018.67 LVT gal 0.6 PPB 987 lbs 107.7 gals 0.5 pallets $5.65 $11.06 0.0 PPB 0 lbs 0 sacks 1.0 pallets $0.00 HRP 0.3 PPB 410 lbs 8.2 gals 0.0 pallets $1,253.51 $10,278.49 VersaWet 2.0 PPB 3,280 lbs 357.7 gals 1.6 pallets $903.09 $5,873.01 Safe Carb 20 25.0 PPB 40,999 lbs 820 sacks 16.7 pallets $21.57 $17,686.91 Safe Carb 40 25.0 PPB 40,999 lbs _ 820 sacks 17 $22.78 $18,679.08 Lube 776 0 lbs 0.0 gals 0.0 pallets $1,630.22 $0.00 SuperSweep 1 box 50 lbs 1 sacks pallets/totes $147.20 $147.20 LCM contingency(makeep at warehouse or OSK) SafeCarb 40 9500 4pallets SAFE CARB 250 16500 7 pallets SAFECARB 500 11500 5 pallets Completion material/Frac to follow Material is currently stored at the Kenai warehouse(KCL,Caustic,polymer,Deep clean) Ver.1.1 Draft Mr Ewa cO..—. • Cook Inlet Energy Redoubt Unit: RU-3A Production Interval Drilling Fluid System Actimul OBM Key Products LVT 200,Actimul, IMG 400, VG Supreme, Lime,CaCl2 brine, MI WATE (Barite) • Excessive ROP(>150 ft./hr. average) • Guage hole conditions with OBM (very little washout) Potential Problems • Seepage losses • Sag • Torque and drag • Adequately clean hole using pipe rotation, good fluid properties&controlled Interval Objectives ROP • Minimize solids/liquid invasion by maintaining optimum PSD of bridging agents • Maintain minimal ECD by minimizing drill solids accumulation PRODUCTION INTERVAL MUD PROPERTIES Electrical Depth MD Mud Wt. Yield Point HTHP Fluid Loss Stability (ft.) (lb./gal) (Ib./100ft2) (mI/30min) OWR (mV) 14326— 16,809 10.2 25 - 35 < 5 70:30— >400 75:25 Production Interval Fluid Formulation LVT 200 0.602 bbl VG Supreme 2.0 ppb Lime 5.0 ppb Actimul 8.0 ppb Brine (11.6 ppg CaCl2) 0.165 bbl M-I WATE 60 ppb HRP,Versawet As Needed Based on Pilot Testing Ver.1.1 Draft Mi SWACO A ScMombo"'°'`°"w""" Cook Inlet Energy Redoubt Unit: RU-3A • Inspect decking rubbers, c/o as necessary. • Install 175—210 mesh screens or finer if shakers will handle flow rate. Ensure screens are properly tensioned, per manufacture's best practice suggestions. Spray down new screens with fresh water before operating the shakers. • As fluid shears, screen up as necessary to higher mesh screen sizes. 210 mesh is Shakers Optimum to reduce sand sized particles. • Minimize flowline"jetting"during drilling,as additional mud flow will allow shakers to Be overrun with fluid. If possible,only jet the flowline during connections or in short bursts during drilling operations. • Check screens for holes between each connection. • Screen pulse may be an option to maximize cuttings haul off efficiency • Production intervals generally call for a "high-speed" centrifuge, which is rotating at approximately 3,200 rpm's. This allows the centrifuge to make the 3 - 6 micron cut, and eliminate a percentage of the "ultra-fine" cuttings from the fluid. Through put must be decreased while running the centrifuge at 3,200 rpm's, since there is a greater risk of "packing off"the centrifuge back drive and auger. Centrifuge • Refer to mud engineer for solids information to determine speed and feed rate of centrifuge. • Continual processing at low feed rates will yield better results than shutting centrifuge down and starting it up. Slow feed rate down to maintain an acceptable weight if needed. • Run as needed but be aware that M-I Wate/ SAFECARB will be discharged and needs to be replaced if the centrifuge is run. Fluid and Drilling Concerns — Hole cleaning must be monitored closely and continually throughout the entire well. The tangent section can create hole cleaning problems with cuttings accumulation,avalanching and the potential for pack-offs. The following are all tools that should be used to help monitor hole cleaning and make the necessary adjustments before hole cleaning becomes a problem. • Virtual Hydraulics • PWD data ECD's • Drilling parameters- Pickup and slack off weights, RPM, ROP,flow rates • Monitoring cuttings returns from sweeps — Lost circulation - Control ECD's, particularly in the lower intermediate and production intervals, by maintaining good fluid properties combined with good drilling and hole cleaning practices with help minimize potential for lost circulation. • Have adequate LCM material on location prior to drilling. • Should losses occur,refer the"Lost Circulation Flow Charts"at the end of this program. — Wellbore Breathing/Ballooning — Carefully manage/monitor ECD's, pit volumes and flow in vs. flow out, particularly when pumps are turned on and off.Trends from monitoring these parameters may be early indicators of wellbore breathing/ballooning. Ver.1.1 Draft Mi SINAGS7 --• A Schlunhuryw Company Cook Inlet Energy Redoubt Unit: RU-3A — Waste volume and disposal cost minimization of drill cuttings and associated waste fluids. Production Interval Operations: Milling 1. Use Super sweep to clean hole of metal cuttings as needed during milling operations. 2. Ensure magnets are cleaned prior to drilling open hole and record weight. Displacement 1. Ensure all valves and pit equalizers do not leak and are in good working order to avoid any potential for fluid contamination. 2. Clean pits and flush all lines with LVT-200 prior to adding the OBM to the pits. 3. Shut off and bullhead all water lines into pit room prior to adding OBM INTO pits.Once OBM FLUID is in the pits DO NOT USE WATER TO WASH DOWN UNLESS DIRECTED TO DO SO BY MUD ENGINEER. 4. Clean out to float collar with Brine/mud. 5. Once the Whip stock has been set(or packer set prior)-displace to the OBM by pumping the following: • 25-50 bbl.water viscosified with 2 ppb FLOWZAN. • bbl. LVT-200 • 25 bbl.viscosified OBM • Follow with OBM fluid Pump at highest rate practical. Aggressively rotate and reciprocate pipe while displacing. Make sure bit is on bottom when leading edge of spacers and OBM exit bit. Calculate strokes and monitor returns at the flow line for spacer returns. Electrical stability of the fluid can be used for the final confirmation of acceptable fluid purity. Discard spacers until clean OBM returns are observed. Drilling 1. Maintain flow rates established by VH modeling to ensure adequate hole cleaning. ECD management will be critical in the later portions of this well. Control the ROP and flow rates to avoid inducing a breakdown of the sands. Reduce pump rates immediately if packing off occurs. The best indication of a sufficiently cleaned hole is the amount of cuttings observed at the shakers. In previous wells pipe rotation,adequate rheological properties and flow rate,short trips and avoiding excessive ROP proved to be the best method of ensuring adequate hole cleaning. 2 Past experience has indicated that for every one barrel of hole made there is 1.2 bbl. lost with the cuttings through the solids control equipment. Be sure to have the LVT-200 tank full on the rig with LVT-200 mineral oil. 3. While drilling adjust rheology, ROP, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. Ver.1.1 Draft Mi SWAGQ,:-.r.• ASc M1laoibarpar Congany Cook Inlet Energy Redoubt Unit: RU-3A 4. Utilize +1.5 lb. /gal weighted sweeps using SAFE-CARB 40 and tandem sweeps (low viscosity/weighted) if needed for sweeping the hole clean. 5. Drill ahead watching for well bore instability problems. Any fluid weight adjustments should be performed in 0.1-0.2 lb./gal increments using either M-I WATE or SAFE-CARB 40 as weighting agent and bridging agent. 6. Run the centrifuge to remove drill solids and maintain the rheology. This will require the addition of SAFE-CARB 40 to maintain acceptable bridging characteristics. 7. Fluid Loss Control:To verify the bridging capability of the Versa/Actimul, use a modified HTHP.The HTHP should be equipped with a 20 micron aloxite disk(or as close to the permeability of the formation). 8. Monitor rheological properties and retort results for determining dilution requirements. Based on the dilution rates experienced on other OBM wells expect minimum dilution rates of 0.18 bbl/ft. depending on hole size. Barite Sao Concerns Barite sag (a reduction in the MW out due to the dynamic and static settling of barite) is a potential drilling hazard while using fluid weighted with barite. Although this well is designed for mud weights in the 9.0 — 10.0 ppg range, unexpected conditions may make additional weight ups or lubricant additions necessary. Both of these changes may increase the chance of encountering barite sag issues. Barite sag is also aggravated by circulating at low rates for extended periods of time or while tripping with drill pipe or casing. As a consequence, if it becomes necessary to circulate at reduced rates,it is recommended that the pit watcher weigh and record MW out using a pressurized and un-pressurized balance every 15 minutes. Trips and casing running should also be closely monitored for indications of barite sag and records should be kept and sent to the Project Engineer at the end of the interval. The"VST Sag Shoe"test should be run and reported on all mud checks where Barite sag may be an issue. If Barite Sag is detected,a 5 gal sample may be collected for further analysis. Instructions will be given at the time on where and how to ship the sample. Ver.1.1 Draft Mi SWACC • • A Sc.w.ba,4u,Cumperry Cook Inlet Energy Redoubt Unit: RU-3A 6-3/4"HOLE SECTION, PROCEDURES AND RISKS — Sloughing Coals Throughout the interval — control with higher MW and proper drilling practices (see items below), identify coal intervals against log. — Coal Gas—should be minimized with the existing mud weight but beware of gas reducing weight in OBM. — Drilling Fluid Contamination—Do NOT use water for wash down around the pits. — Directional control—high instantaneous doglegs. 1) PDC bit performance through coals greatly limits the effectiveness of ROP as a gauge for determining if a coal has been penetrated. Consequently, torque may be the most accurate gauge of when coals are encountered. Be aware that drilling breaks may or may not indicate a coal has been penetrated. 2) Hole cleaning must be dictated by the active fluid system properties, flowrate and rotary rpms. Maintain 6 rpm Fann VG meter at a minimum of 1.1 to 1.2 times hole diameter for efficient rheology for hole cleaning at high angle. Sweeps should not be relied upon for improving hole cleaning unless associated with pipe rotation. Sweeps in the high angle tangent section will flow along the top of the hole and will likely be ineffective at removing cuttings, especially if pipe is not being rotated. 3) Circulation for hole cleaning should a) be minimum 2—4 bottoms up, b)ALWAYS be accompanied by rotary RPM and c)set a stand back every 30-45 minutes to avoid localized hole erosion d) with minimal or slow reciprocation in order to avoid high surge pressures on down stroke. 4) Back reaming should only be used when tight hole is identified based upon data from previous section. Do not use back reaming for hole cleaning and do not "double back ream" on connections. When a tight spot is encountered during a trip always assume the tight spot is associated with cuttings bed buildup. RIH until the BHA is clear of the tight spot, circulate and rotate for approximately 3—4 times BU and attempt to POOH again. If the tight spot has disappeared or moved up hole,then the tight spot was most likely cuttings. If the tight spot is in the same place,then it is most likely a formation condition and back reaming should be undertaken. If back reaming is necessary, use normal drilling flowrates. DO NOT USE BACKREAMING AS A METHOD TO CLEAN THE HOLE AS IT WILL EVENTUALLY ACCUMULATE CUTTINGS TO WHERE FURTHER PIPE MOVEMENT AND CIRCULATION IS GREATLY REDUCED. 5) Wiper trips should be used judiciously in order to maximize drilling time and minimize hole degradation associated with swab/surge effects. Trips for bit,BHA changes should suffice for ensuring hole integrity rather than additional wiper trips. Wiper trio(s) should be conducted only as means for alleviating tight spots, not hole cleaning. On trips, monitor PU/SO weights against actual connection drag friction values to assess hole conditions. 6) Once hole angle exceeds 50 degrees cuttings bed buildup will begin to develop. Bottoms up circulation at that point is irrelevant for hole cleaning thus any extended circulation time for additional hole cleaning should be 2—4 times bottoms up with high rpm pipe rotation to effect additional cuttings removal. 7) For proper wellbore monitoring,it is recommended to rely upon torque and drag data to determine clean hole/dirty hole characteristics prior to drilling ahead. When circulating and reciprocating for extended periods, pull 1 stand per hour to minimize wash out effects of circulation across a single area. On past wells significant hole enlargement has occurred in areas where repetitive circulation and reciprocation was used. These zones of enlargement create areas of reduced annular velocity,cuttings bed build- up and a potential pack off threat later in the well. 8) PU and slack off data should be captured to establish friction factors for tripping out of hole. Any trips out of the hole should rely on these baseline friction factors to establish when tight hole is encountered. On all trips, any tight hole should first be assumed to be cuttings beds, with circulation and rotation, below the tight spot(2 —4 BU)as the appropriate first response. Ver.1.1 Draft M/SWi4CQ -„=_ • - AS`"W.Im'poCmv'"" Cook Inlet Energy Redoubt Unit: RU-3A Hole Cleaning Hole cleaning efficiency is affected by hole size,washouts, drill pipe diameter, flow rate, rotary speed, mud rheology, wellbore trajectory, cuttings size, pipe reciprocation, % sliding, penetration rate, wellbore stability, mud solids and cuttings dispersion. VH modeling will be run with input above to supply client with recommended drilling parameters(ROP, RPM) Production Sidetrack Interval Consideration Ensure that the fluid properties are maintained to provide the best possible hole cleaning. Maintain mud weights as per drilling program guide lines and ensure that rheology is optimized to reduce ECD's to a manageable level while drilling. Monitor for any fluid losses and flow back closely. Control the ROP and flow rates as needed to avoid inducing a breakdown of any formations. Reduce pump rates immediately if packing off occurs. Pump high viscosity weighted sweeps and ream carefully to clean the hole before proceeding with further drilling Adjust rheology, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. Use good drilling and tripping practices. Break circulation slowly—Reduce pump speed 15 to 20%while reaming down. Pore pressure uncertainty also exists. Use all means possible to evaluate well conditions to determine if fluid properties are in line with the needs of the well. Monitor and record drilling parameters on each connection and before and after any lubricant additions. Upon reaching TD watch the bottoms-up cuttings closely. If the well does not readily cleanup or if there are any excess of torque, drag, pick-up or slack-off weights pump a second high viscosity/weighted sweep and observe bottoms up again. Establish good hole conditions for any logging and testing that may be performed. Fluid deliveries, fluid transfers, and cuttings disposal issues will be tracked on a daily basis. Ver.1.1 Draft MI BWAGQ/_•,,,,4 • "$`"'""'°'°"``""'°""" Cook Inlet Energy Redoubt Unit: RU-3A Oil Based Mud LCM Decision Tree IMeasure rate of loss 1 / , Seepage losses Seepage&Partial losses Severe losses >10BPH 20—80BPH >80 BPH _.. ._ ___ Background LCM I If fault related drill 100 ft.past the If fault related drill 100 ft.past the • -3 ppb MIX II Med fault before treating mud losses. ! fault before treating mud losses. • -3 ppb Safe Carb 40 • -3 ppb Safe Carb 250 • Pump thru BHA • Add through grate if hopper is Pill#1 (Med/Cse pill) Pill#2 Coarse Pill Checklist to ensure mud losses unavailable "Drill Ahead Pill" "Super Pill" are being treated while mixing 90 bbl/40ppb SafeCarb pill: (Well Commander only) __._ ✓YP-30-40 Ib./100ft2 Typically laid in 1:1 while pulling 1. Confirm with WSL&town ✓Mix 90+bbl(2 Big bags) above the fault. engineers before mixing. ✓Pump>90 bbl per Treatment • 100 bbl.Cad 60 ppb 2. Ensure enough whole mud is on Pill#1 (Med/Cse pill) up hand to keepwith losses. • Safe Garb 1400 10 ppb Add Ccs rig NutPluq Med 15 ppb • Target YP=-35 Ib./100ftMix II Cse/Med 10 ppb 3. Mix 90+bbl.of Pill#1 while • Ensure pH is 10.5-11.0 • Safe Carb 750 15 ppb circulating/treating losses. Safe Carb 1400 10 ppb • Busan 1060 @ 0.4 ppb • Safe Carb 500 10 ppb ! 4. Back ground LCM should be Safe Garb 750 15 ppb • Monitor fluid on vac for • MIX II Med 5 ppb Safe Carb 500 10 ppb added through the suction pit degradation. Pump thru BHA grating if hopper is unavailable. • `Mixing 80 ppb LCM pills at the 5. DO NOT pump Pill#2 through Casing/Liner Surge Pill •Rotary Steerable tools have a limitation of 40 rig takes 3-5 hours. the BHA! 40 bbl SafeCarb ppb LCM.Dilute all Drill Ahead pills to 35ppb. Wellbore Strengthening Pill 6. DO NOT fibrous material through BHA! • Target YP=-35 Ib./100ft" • Safe Carb 250 10 ppb • Safe Carb 500 10 ppb • Safe Carb 750 15 ppb 0 Total 35 ppb • Spot on bottom prior to POH to run Casing/Liner Casing/Liner Running (Lube) Pill • Active fluid+4%Lubes and increased YP targeting 35-40 Ib./100ft'. • 2 ppb Drill Beads. Ver. 1.1 Draft •A SchlumhoNot Cunw°"Y Cook Inlet Energy Redoubt Unit: RU-3A Handling of Drilling Fluid Products — Drilling crews should be instructed in the proper procedures for handling fluid products. — Personal Protective Equipment(PPE)charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. — PPE must be in good working order and be utilized as recommended by the PPE charts. — Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans), as much as possible in order to minimize inventory of partial units. — Ensure all MSDS sheets are up to date and readily available for workers to access for information. — Environmental — Ensure that all product stored outside is protected from the weather. —Do not store partial units(sacks)outside if possible. — When transferring fluids and/or cuttings from the rig to tanks, insure all hoses are properly secured. Perform a transfer checklist as needed in order to avoid spills. HSE Issues Like many chemicals used in oil and gas drilling, oil-base mud can be hazardous to your health if handled improperly. When working with oil-base mud be aware of the following hazards: • Oil-base mud is difficult to remove from the skin. • Oil-base mud, and some of the chemicals used in it, can be quite irritating to the skin and eyes. • Mist and vapor from oil-base mud, especially in the area around the shakers, can be irritating to the respiratory system. • Oil-base mud is difficult to remove from clothes. If clothing is not properly laundered, mud residue in the material can cause skin irritation. How to Protect Yourself The purpose of the following guidelines is to identify potential hazards associated"Oil"based mud systems and also to give basic guidelines for safe handling of the"Oil" based fluids. • Always have the Safety Data Sheets (SDS) available on location for all chemicals that you handle. Read and follow all instructions on the SDS. • Use the Personal Protective Equipment(PPE)described in the SDS. • Avoid unnecessary contact with the mud. • Wipe mud off your skin as soon as possible and wash with soap. • If mud soaks through your clothes, change and wash as soon as possible. • Use good personal hygiene,wash thoroughly after each tour. Ver.1.1 Draft M i EV VAC 4;2,- -0 41, A Schlumhmwn CO.V.V Cook Inlet Energy Redoubt Unit: RU-3A Skin Care The most common health problem with handling oil-base mud is dermatitis or skin irritation. The following 3-step program is designed to help you prevent dermatitis: — Protection-before contact with the mud apply a barrier cream to areas that are not easily covered by some other form of PPE. Use a barrier cream specifically designed to protect against oil-based or solvent hazards. Barrier creams should be used in addition to the PPE mentioned above, not as a substitute for it. — Cleaning -wash frequently, and use a soap designed to remove oil and grease from skin, such as the waterless soap preparations used by mechanics. Do not wash your skin with diesel or rig wash. — Reconditioning-contact with the mud and frequent washing of the skin can result in loss of the skin's natural oils and moisture. To prevent dry, chaffed, and irritated skin apply a reconditioning skin lotion after work and as needed. Over-the-counter hydrocortisone cream may be used to relieve minor skin irritation. Follow instructions and precautions provided by the manufacturer. If left untreated minor skin irritation can progress and result in intense itching and blisters,which can become infected.Cases of severe dermatitis,especially if infection is suspected, should be referred to a medical professional immediately. Laundering Recommendations Be sure that your work clothes are clean before wearing them. For clothing that is heavily soiled with oil- base mud this will require special laundering procedures. Laundering procedures must be adapted to available equipment and conditions; however, the following suggestions have been proven to be effective: — Do not overload washers. — Designate one washer for washing only oily/muddy clothes. Clothes,which are not soiled with oil-base mud, should be washed in a separate washer. — The washer used for oily/muddy clothes should be cleaned periodically by running a wash cycle with hot water and detergent only(no clothes). — Run oily/muddy clothes through at least 2 wash cycles using hot water and regular laundry detergent. Additional cycles may be necessary for extremely muddy clothes. — If repeated washing is not possible or practical, pre-soak oily/muddy clothes 1-2 hours in a laundry detergent solution before laundering. This can be done in a container such as a clean 55 gal drum or large plastic trash can. — Workers who handle oily/muddy clothing should observe the precautions outlined above. Ver.1.1 Draft Mi SWACOIII11111 Cook Inlet Energy Redoubt Unit: RU-3A Product Function Health Flammability Reactivity PPE Actimul RD Emulsifier 2 1 E CALCIUM CHLORIDE(DRY) Control salt content of internal phase 1 0 1 E CALCIUM CHLORIDE(BRINE) Control salt content of internal phase 1 0 1 E CAUSTIC SODA Alkalinity control 3 0 X CITRIC ACID pH Adjuster 1 0 0 E DEFOAM X Defoamer 1 1 0 J DESCO CF Dispersant 1 1 0 E DUOVIS Viscosifier 1 1 0 F Versawet Wetting Agent 1 1 0 HRP Rheology modifier 1 0 EMI-3070 Thinner 1 1 0 FLOVIS Viscosifier 1 1 0 G-SEAL Graphite loss circulation 1 1 0 GELEX Bentonite Extender 1 1 0 GREEN CIDE 25G Biocide 3 0 0 HRP Viscosifier 1 1 0 IMG-400 Organophilic clay Viscosifier *1 0 1 LIME Calcium Source,Alkalinity 2 0 0 LUBETEX Lubricant 1 1 0 . LVT-200 Mineral Oil 1 1 0 MI BAR Weighting Agent *1 1 0 MI GEL Viscosifier *1 1 0 MI SEAL F,M,C Loss circulation material *1 1 0 MIX II F,M,C Loss circulation material *1 1 0 NUT PLUG Loss circulation material *1 1 0 POLY PAC Viscosifier,Fluid Loss Control *1 1 0 SAFE CARB 10,20,40,250 Bridging&weighting agent *1 0 0 SAFE SURF 0 Oil base detergent 2 2 0 SALT(NACL)&Brine Solutions, Densifier 1 0 0 SAPP Dispersant 0 0 SODA ASH Calcium precipitation 1 0 SODIUM BICARB Alkalinity control 0 C HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS)HAZARD RATINGS 4-Severe hazard 3-Serious hazard 2-Moderate hazard 1-Slight hazard 0-Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A-Safety Glasses B-Safety Glasses,Gloves C-Safety Glasses,Gloves,Synthetic Apron D-Face Shield,Gloves,Synthetic Apron E-Safety Glasses,Gloves,Dust Respirator F-Safety Glasses,Gloves,Synthetic Apron,Dust Respirator G-Safety Glasses,Gloves,Vapor Respirator H-Splash Goggles,Gloves,Synthetic Apron,Vapor Respirator I-Safety Glasses,Gloves,Dust and Vapor Respirator J-Splash Goggles,Gloves,Synthetic Apron,Dust and Vapor Respirator K-Air Line Hood or Mask,Gloves,Full Suit,Boots X-Consult your supervisor for special handling directions. ._ 0 co 0f..,„ N! 0 4... Ver.1.1 Draft < • 411) RU-03A WI-Proposed Frac Wellbore Schematic Date: 3-Jan-17 Version: 1.0 GLACIER Tubing Hanger-3-1/2"12.95#PH6-Top&Btm ii 30" 150#A-36 260'MD ID-28" Welded 260'TVD 13 3/8" 68#L-80 3,507'MD 18 112"Hole J ID-12.25" BTC 3,024'TVD Perforations 9-5/8"Casing Patch-7,750'-7,850'MD MD TVD Feet r-'""-- r+ --- 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 7 5/8"X 9 5/8"Liner Hanger TOL @ 9,103'MD . .' ' 9 5/8" 47#L-80 9,332'MD 12 1/4"Hole ID-8.50" BTC 7,416'TVD 4 1/2"15.1#P-110 Frac String TOL @ 14,030'MD Window 8 1/2"Hole 75/8" 29.7#L-80 14,362'MD _ ____ ID-6.75" Hydril 521 11,096'TVD 1= 1 it= 4 Plug and Perf Hydraulic Frac Completion c C C 4 1/2" 15.18 P-110 16,809'MD 6 3/4"Hole ,r J ID-3.832" GeoConn 12,900'TVD M�SWACO i "S`"'"'"" °"'`"""°"" Cook Inlet Energy Redoubt Unit: RU-3A RU-03 Proposed Abandonment Schematic 10/11/2016 Version-1.0 30" A-36 200'MD 15012 Welded 200'TVD • -A A- 13 IA" L8 3.507MD 68 8 8TC 3.024'IVO - —.CasMQ Pat,'^; 4,er,at 7 774` 7 q25't,rr Perforatrons-7780'-7818'MD' 6.203'-6.232'TVD TOL @1 9,103'MD c 9 5.8" L 80 9 332 MD Baker Hanger Assembly $1 47 n BTC 7 416'TVD i —" Cement Retainer 14,448'MD Option 1 Cement squeeze of 18 buts 15161 Top Tieback @ 14,717'MD Option 2.Cement squeeze of 30 bbts(1,056') Perforations-14,803'-14,860'MD 1 m NZ= =PI CRTC 11.410'-11,450'TVD 7 518" L-80 15.615'MD Baker Hanger Assembly 29 7 8 Hydril 521 11,981'TVD Cement Retainer @ 15,691'MO ' Lost fish 01.15,768'-16.048'MD = • E 5 112" L80 16,940'MD 17 8 Hydril 521 13,016'TVD Well Ver. 1.1 Draft Mi SWAGO • • AS`"'""'t'°'°`"`'m"""" Cook Inlet Energy Redoubt Unit: RU-3A RU-03A WI-Proposed Wellbore Schematic Date: 8-Aug-16 Version: 1.0 GLACIER Tubing Hanger-3-112"12,956 PH6-Top 8 Bottom '— L 30" 1506 5-36 260'MD ID-28" Welded 260'71.03 4 — 3.112"12 550 P•110 PH6 Tubing•ID•2.75" 13 318" 686 1-80 3,507'MD 18 112"Holej Al .iID•12.25" BTC 3,024'TVD Perforations I -8.5%8'Casing Patch-7,750'-1,850'MD MD TVD Feet 7.780•7 660 6.203-6,210 20 —.._.. ., •�--- 7,806.7 018 6 233 6273 13 7 SB"X 9 518"Lowe Hanger 101*9.103'MD 9 518" 4791410 9,332'MD 12 114"Hole ( ID-8.50" OTC 7.416'TVD • • 1+,` 3.112'PH8 X 2-78'EUE X'O at 14,200'MD TOL Crs 14,120'MD, Window 7 5B" 29.76 L•80 14,418'MD 8 112"Hole I ID-6.75" Hydril 521 11,137'TVD , { I 2 18'4 66 L-80 EUE Tubing,ID-1 901" .• i 2-318"X 5"Permanent Packer a 2.318-Sailing Skaeve[n?+1-16.50a MD J. � ax —2318"X 5'Permanent Packer ai% 2-38"Siding Sleeve a a= IIlif2-318-X 5"Permanent Packer a IC._. 1 A2.3,8"XN N.pple r— 2" 16,974'MD I 6314"Hole I II (i ID 43.832" t SGeoCon.19 n 12.910'TVD Ver.1.1 Draft ,.. • RU-03A WI-Proposed Wellbore Schematic iio Date: 20-Dec-16 Version: 2.0 GLACIER Tubing Hanger-3-1/2"12.95#PH6-Top&Btm 30" 150#A-36 260'MD ID-28" Welded 260'TVD 4 3-1/2"12.95#P-110 PH6 Tubing-ID-2.75" -r 13 3/8" 68#L-80 3,507'MD 18 1/2"Hole ID-12.25" BTC 3,024'TVD Perforations 9-5/8"Casing Patch-7,750'-7,850'MD MD TVD Feet 7,780-7,800 6,203-6,219 20 7,805-7,818 6,223-6,233 13 II 7 5/8"X 9 5/8"Liner Hanger TOL @ 9,103'MD . 9 5/8" 47#L-80 9,332'MD 12 1/4"Hole ' ID-8.50" BTC 7,416'TVD 5. a ji.C.X.'N.. jrX ; 4— 3-1/2"PH6 X 2-3/8"EUE X/O at 14,150'MD fkiA TOL @ 14,030'MD Window 7 5/8" 29.7#L-80 14,362'MD Pit 8 1/2"Hole inID-6.75" Hydril 521 11,096'TVD W rAtDd"J i L►K3a2 3/8"4.6#L-80 EUE Tubing-ID-1.901" 2-3/8"X 4-1/2"Permanent Packer 2-3/8"Sliding Sleeve @+/-16,500'MD p..--- 2-3/8"2-3/8"X 4-1/2"Permanent Packer 2-3/8"Sliding Sleeve 2-3/8"X 4-1/2"Permanent Packer IC i. sI I 2-3/8"XN Nipple 41/2" 15.1#P-110.16,809'MD 6 3/4"Hole !IIj ID-3.832" GeoConn 12,900'TVD RU- Current Completion 12/6/2012 • N _ SSSV @ 303'MD 2-7/8"Halliburton SSSV at 287' 30" A-36 200 MD 150# Welded 200'TVD . [1it__''4I ., 2-7/8"chemical injection mandrel @ 2,500'MD -a 13 3/8" L-80 3,507'MD 68# BTC 3,024'TVD 41 2-7/8"WXO Sliding Sleeve @ 7,578'MD i0 lb 9-5/8"x 2-7/8"Weatherford Hydrow I hydraulic-set packer©7,614'MD 4 2-7/8"Sliding Sleeve @ 7,754'MD 2 7/8"6.5#L-80 EUE M Tubing .=— Perforations-7780'-7818'MD/ 6,203'-6,232'TVD ? ,I Redressed 9-5/8"x 2-7/8"Weatherford Hydrow 1 hydraulic set packer @ 7,854'MD TOL© 9,103'MD Baker Hanger Assembly =1 1. . 9 5/8" L-80 9,332'MD F. 1 47# BTC 7,416'TVD in 2-7/8"XN-nipple @ 14,751'MD Top Tieback 14,717'MD �. WL Re-Entry Guide©14,791'MD Perforations-14,803'-14,860'MD/ 11,410'-11,450'TVD Baker Hanger Assembly 1 7'4 7 5/8" L-80 15,615'MD is 6s 1 29.7# Hydril 521 11,981'TVD Cement Retainer @ 15,691'MD v�v _ Lost fish©15,768'-16,048'MD � o �� t 5 1/2" L-80 16,940'MD , I 17# Hydril 521 13016'TVD RU-03 Proposed Abandonment Schematic 12/20/2016 Version-3.0 30" A-36 200'MD 150# Welded 200'TVD 13 3/8" 68#L-80 3,507'MD ID 12.415" BTC 3,024'TVD l " Casing Patch-ID 7.75"after setting @ 7,770'-7,830'MD r r Perforations-7780'-7818'MD/ 6,203'-6,232'TVD TOL©9,103'MD 9 5/8" 41#L-80 9,332'MD Baker Hanger Assembly ID 8.525" BTC 7,416'TVD I Whipstock top of window @ 14,362'MD Cement Retainer @ 14,385'MD Top Tieback @ 14,717'MD - Cement squeeze perfs,20 bbls 15.3 ppg v' Perforations-14,803'-14,860'MD/ L7 11,410'-11,450'TVD M♦ 1 7 5/8" 29.7#L-80 15,615'MD Baker Hanger Assembly J ID 6.75" Hydril 521 11,981'TVD Cement Retainer @ 15,691'MD Lost fish @ 15,768'-16,048'MDt.:74 5 1/2" 17#L-80 16,940'MD ID 4.767" Hydril 521 13,016'TVD Traveling Cylinder P of NoGo Region EOU's based on.Oriented EOU Dimension-Minor Risk N TRAVELING CYLINDER PLOT Anti-Collision rule used:D&M AntiCollision Standard S002 v5.1/5.2 Client Glacier Oil&Gas Field Redoubt Unit Structure Osprey Platform Well RU-3 North Borehole RU-3A • 350 0 10 Date 13-Dec-2016 340 0s 20 330 s - . -----/80 r 30 aft 60 r 320 40 40 f toie 1 20 310 40 s00 50 80 ` lir 300 /4(4,110111* 160 60 140 • 120 290 1 70 ft 100 80 280 47 4 60 , 80 II 40 S It , 11111114114811 * e 20 270 ._...___ ` II so m� ti o ;, o 1114 ,.,,x.. i.,,,, , .. , 4141/ i 40,4a . , 260 Attille$112ftsb 100 "IIIP IF 250 " ` ViantalAtTiti °° 110 oo. o 4,0 VA,Liiimui,oe A cP 240 4,,, Vial 11111M111111111M. 0 Cu 0 120 O#V, Cb 230 \ �-''S 130 220 bra��- 0010� 140 210 41rtrllIllIllr 1111 150 200 160 190 180 170 Well Ticks Type: MD on RU-3A(P6) Calculation Method: Normal Plane Ring Interval 20.00 ft Azimuth Interval: 10.00 deg Start Depth: 14323.91 ft End Depth: 16808.98 ft Offset Well Count: 25 S • < SOblamer GLACIER RU-3A(P6)Anti-Collision Summary Report Analysis Date-24hr Time: January 30,2017-14:46 Analysis Method: 3D Least Distance Client: Glacier Oil&Gas Reference Trajectory: RU-3A(P8)(Def Plan) Field: Redoubt Unit Depth Interval: Every 10.00 Measured Depth(5) Structure: Osprey Platform Rule Set: DAM AntiCollision Standard S002 05.115.2 Slot: L3-S15(W) Min Pts: All local minima Indicated. Well: RU-3 Version I Patch: 2.10.302.0 Borehole: RU-3A Database I Project: localhoslldrilling-Cook Inlet 2.10 Sean MD Range: 14323.91ft-16808.985 ISCWSAO 3-D 95.000%Confidence 2.7955 sigma,for subject well.For Trajectory Error Model: offset wells,error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 57819.48 ft Selection filters. Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Del Plans when no Def-Plan Is set Ina borehole Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)1 MAS(5)I EOU(5) Day.(5) Fact. Rule MD(5) I TVD(5) Alert I Minor I Major RU-3(Def Survey) PCI Major 329.2 MIZEMEEIR3 000 OSF1.50 14323.91 11089.30 OSF<5o0 OSF<1 50 050<1 00 EnterMyor 0.00 25703 -171.68 -2570 C OSF1.50 14330.00 11073.63 MinPt-OSF 000 257.'%=Ma III -0.01 OSF1.50 14382.00 11098.39 MinPts 0.07 224.07 -149.64 -224...®" OSF1.50 14370.00 1110203 MinPt-O-SF 2023 323.•. -196.0 -303.73 0.09 OSF1.50 14850.00 11295.24 MINPT-0-EOU 26.29 331.27 -194.81 MEM ail OSF1.50 14890.00 1132285 MinPt-O-ADP 48.14 355.22 -191... -309.08 0.19 OSF1.50 14800.00 11896.70 MinPt-O-ADP 250.78 378.27 -040 -125.49 1.00 OSF1.50 15480.00 11859.72 05F>1.00 Eot Mejor 380.16 380.71 128.03 -0.55 1.50 OSF1.50 15830.00 12098.65 OSF>1.50 F'1 Minor 72945 380.44 475.49 349.01 2.88 OSF1.50 16808.98 12900.00 TD RU-5A(Def Survey) Warning Alert jjjjjj E 280.80 1304.82 1211.35 7.99 OSF1.50 14323.91 11089.30 MinPt-CICt 1493.37 283.•=MR 1210.01 7.93 OSF1.50 14370.00 11102.03 M1NPT-0-EOU 1203.88 38233 961.80 84135 4.99 OSF1.50 16210.00 12383.06 OSF45.00 Enter Alert 1078.24 386.47 813.59 681.78 4.08) 09F1.50 1874000 1283734 MInP1-0-SF 107376 393.82 810. 6799.11 4.10 OSF1.50 16800.00 12881.80 M:nP1-0-ADP Ititi ^•• 303.324 810.81 68004 4.10 OSF1.50 16808.88 12900.00 MinPts Redoubt SH ST 20064 1(Def Survey) "'� Weming Alert I 5476541 3407.171 3204.591 2069.37 2.41 OSF1.50 14323.91 11089.30 OSF45.00 Enter Alert 5529.10 3443.37 3233.01 208572 241 00F1.50 14490.00 11184.79 MInPt-0SF 6743.07 3982.88 4087.45 2760 2 OSF1.50 1880888 12900.00 MInPI-0SF RU-4P02(Def Survey) Warning Merl =MI 1888.34 582316 5194.04 563 OSF1.50 14323.91 11069.30 MinPt-CtCt 7167.57 2153.99 5731.25 5013.58 4.99 OSF1.50 1447000 11170.99 OSF<5.00 Enter Alert 7574.24 4692 831 4445 361 2881 411 2.421 OSF1.50 15420.00 11819.57 MinPts 8129.67 4546.85 5098.11 3582.82 2.68 OSF1.50 18808.98 12900.00 TD RU-5B(Def Survey) Pass ®' 348.134 1668.711 1552.991 8.21 OSF1.50 1432391 11069.30 MinPts 2012.83 380.86 1758.59 16319 7 OSF1.50 14800.00 11396.70 MinPt-0SF 2532.74 318.13 232033 221461 11.97 OSF1.50 18808.98 12900.00 TO RU-5(Def Survey) Pees ® 195.184 2382.781 231804 19.40 OSF1.50 14323.91 11089.30 MinPts 2835.10 204.08 2498.72 243102 19.48 OSF1.50 14800.00 11896.70 MinPt-0-SF 2815.72 196.16 268481 2619.55 21.63 OSF1.50 15750.00 12040.90 MinPt-0.SF 2882.67 17188 280780 2810.89 26.18 OSF1.50 16808.98 12900.00 TO RU-2(Def Survey) ��1 Pass 2990.20 401.5'®r '.MEEM® OSF1.50 14323.91 11089.30 MinPts 3091.56 428.31 2805.89 2863.241jjMEIER OSF1.50 1480000 11398.70 MinPt-0-SF 3308.56 421.60 3027.18 2886.1.1111111111.1(.x' OSF1.50 16890.00 12531.80 MinPt-0-0F 3389.67 407.45 3097.71 2962.22 1243 OSF1.50 16808.98 12900.00 TO RU-2A(Def Survey) Pass MEEMITI 328.921 3041141 2931 1491 OSF1.50 14323.91 110 .30 MinPts 3382.51 380.25 314201 3022. 89 14.12 OSF1.50 1480000 11398.70 MinP0-06F 3738.81 336.22 3512.34 3400.59 16.72 OSF1.50 16808.98 1290000 TD RU-7(Def Survey) Pass EMMIg 348.5 CrC.�C OSF1.50 14323.91 11069 30 MinPts 4490.68 352.18 4255.57 4138.51 MEE OSF1.50 1448000 1117/.89 Mini)-06F 4803.02 380.18 434024 4222.8'MEE 00F1.50 14800.00 1139870 MInPI-OSF 4643.79 388.5-MEM CIMMO OSF1.50 14040.00 11494.93 MlnPts 4720.21 3943-MEM11111111gm !yT, OSF1.50 15360.0 11779.42 MinPts 4821.27 3933 MEE:Is MZEg1^ OSF1.50 16250.00 12418.22 MinPte 4824.68 4002 1111Z631111112/2115] 18.12 OSF1.50 16280.00 1244084 MinPts 4831.23 40087 4563.65 4430 •1 .r OSF1.50 18370.60 1251504 MInPI-0SF 4834.B8 402.5-C•=SEE MillE OSF1.50 18420.06 12557.10 MinPts 4865.87 400.52 4598.53 4465.35 18.26 OSF1.50 16808.98 12900.00 TD RU-7B(Def Survey) Pass MMIIM 317.475 4263.981 415849 21.21 OSF1.50 14323.91 11089.30 MinPts 4588.79 32901 4368.12 4259.78 OSF1.50 14550.80 1122620 MinPt-0SF 4703.72 34748 4471.74 4358.25 20.38 OSF1.50 14800.00 11398.70 MInPt-OSF 4047.77 342.49 4710.11 4605.28 2173 OSF1.50 15450.00 11839.64 MInPt-OSF 5192.29 343.33 4963.08 4848.98 22.75 OSF1.50 18250.09 12418.22 MMPI-OSF 5327.05 34257 5098.34 408447 23.39 OSF1.50 16808.08 12980.00 TD Redoubt Shoe:ST 1(Def Survey) Pas. 4612.60 646.984 4180.951 396562 10.71 00F1.50 14323.91 110 .30 MinPts 4805.40 654.78 4368.55 4150.61189 11.02 OSF1.50 14750.00 11364.24 MMPI-0SF Drilling Office 2.10.302.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) Page 1 of 3 00 Offset Trajectory Separation Allow Sep. Controlling Reference Tra)ectory Risk Level Alert Statue Ct-Ct Mil MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) 1 TVD(it) Alert I Minor I Major 5045.92 652.75 4610.42 4393.17_ 11.61 OSF1.50 16480.03 11859.72 MinPt-0SF 527492 637.74 4849.43 4637.18 12.42 OSF1.50 16808.98 12900.00 TD RU-7PB1(Def Swtey) Pass NEM 271.64 4709.601 4619361 27.10 OSF1.50 1432391 11069.30 MinPts 5238.48 27880 505242 4959.881 28.30 OSF1.50 14800.00 1139870 MinP1-0-SF 655705 22204 8408.70 6335.01 4449 OSF1.50 16808.98 1290000 TD Redoubt Shoal Unit 2(Def Survey) Pass Marl 574.401 4578.561 43874 12.98 OSF1.50 14323.91 11068.30 MinPts 5201.71 598.73 4802.23 4602.8 1305 OSF1.50 14800.00 11398.70 MinPt-O-SF 5286.10 612.74 4877.21 4673. 12.1a3 12.96 0571.50 15010.00 1154285 MinPts 5301.25 6320.91 4879.5 4889. 12.60 OSF1.50 15060.00 11576.98 MinPts 5483.61 835.21 505981 4848.41 1297 OSF1.50 18808.98 12900.00 TD RU-6(Def Survey) Pass 5106.03 372.2.NEE1BIMMEMIDI M.1 OSF1.50 1432391 11069.0 MinPts 5180.90 378.10 4929.83 4804.:•®i OSF1.50 14480.00 11177.89 MinP1-0SF 5229.64 301.1.MEEM -:�: 7 20.10 OSF1.50 1459000 11253.82 MinPts 5302.30 417.57 5023.5r :�: c MEE OSF1.50 14800.00 11398.70 MinPts 537272 421.19 5091.59 4951.5 MEE OSF1.50 15080.00 11578.98 MInP8-0SF 5430.32 42702 514531 5003.•MEE OSF1.50 15360.00 1177942 MinPt-O-SF 5449.88 42896 5163.57 5020.91 MinjE OSF1.50 15480.00 1185972 MinPt-O-SF 5482.70 432.75 6193."MZEIM Mil OSF1.50 15670.00 1198685 MinPts 5503.43 434.93 5213.14 5068.,r Man OSF1.50 15790.00 12068.56 MinPt-OSF 5543.21 43800 5250.88 5105.21 OSF1.50 16020.00 12235.85 MinPt-0SF 5558.62 440.89 5264.:1.1111M M112 0571.50 1611000 1230495 MinPts 5597.38 444.38 5300.81 5153.0• 09F1.50 16350.00 12498.39 MinPI-O-SF 5829.96 448.42 5330.::Mann 18.87 0571.50 1656000 1267745 MinPI-O-ADP 5634.10 44936 533420 5184.7.1 0571.50 16590.00 12703.71 MinP1-0SF 5654.16 452.60 5352.10 5201.:':1 057150 16760.00 1285543 MInP1-0SF 5658.35 452.54 5356.33 5205.81 1879 OSF1.50 16808.88 1290000 TD RU-6P81(Def Survey) Pose 5108.03 372.221 4857.561 4733.81 20.63 0571.50 14323.91 1106030 MinPts 5180.90 376.10 4929.83 4804 2071 0571.50 14480.00 11177.89 MinP1-0-SF 5311.72 40602 5040.72 490570 19.6 OSF1.50 14800.00 11398.70 MinPt-0-SF 532940 413.711 5053.261 4915.68 1937 OSF1.50 14850,00 11433.12 MinPts 5361.20 438.78 5068.35 492241 18.371 OSF1.50 1495000 11501.79 MinPt-0SF 5963.41 40141 5695.48 556200 22.34 OSF1.50 1680898 12900.00 TD RU-1(Def Survey) Pass MEM 294.045 5390.981 5293.30 28.59 OSF1.50 1432391 11069.30 MinPts 5613.54 295.77 5418.03 5317.77 28.56 OSFI.50 14380.00 1110897 MinPt-0SF 565023 29794 5451.27 5352.291 28.54 OSFI.50 14460.00 11164.09 MInPt-0-SF 5784.98 329.65 556488 5455.32 28.40 OSF1.50 14800.00 11308.70 MinPt-0-SF 5830.08 331.68 5808.63 5496.40g 28.44 OSF1.50 1494000 11494.93 MinPl-0-SF 5959.54 332.36 573764 5827.18 2897 OSF1.50 15460.00 11848.34 MinP1-0-SF • 623129 32446 6014.66 6006.83 28.89 OSF1.50 16808.98 12900.00 TD RU-1A(Def Survey) Pass ll= 27544 5449.061 5357.24 30.67 OSF1.50 14323.01 1106930 MinPts 5890.69 306.49 5686.03 5504.23 8.92 OSFI.50 1480000 11398.70 MInPt-0SF 5924.02 30957 5717.31 561445 28.79 OSF1.50 14870.00 11446.87 MInPt-0-SF 625725 308.59 8051.20 5948.66. 30.51 OSF1.50 15800.00 12075.54 MinPI-0-SF 6268.23 31240 607963 5975.83 OSF1.50 15900.00 12146.85 MinPt-0SF 6310.09 313.29 6100.91 59968C 30.30 0571.50 15980.00 1220578 MinP1-0-SF 6500.89 310.25 6293.73 6190.64 31.53 OSF1.50 16808.98 12900.00 TO RU-4(Def Survey) Pass MEM 224.84 6888.34 681371 4715 OSF1.60 1432391 1106930 MinPts 7274.12 259.59 7100.74 7014.54 42.19 OSF1.50 1480000 11398.70 MinPt-0-SF 7751.98 258.78 7579.13 7493 451 OSF1.50 18220.00 12392.00 M1nPt-0-SF 7960.11 258.49 778746 7701.62 4636 OSF1.50 1880898 12900.00 TD RU-4A(Def Survey) Pass 22484 6888.341 6813.71 47.15 OSF1.50 14323.91 11089.30 MlnPts 7274.12 25959 7100.74 7014.54 42.19 OSF1.50 1488.00 11398.70 MinPt-0SF Min 306 971 7124 821 7022.83 35.93 OSF1.50 16808.98 1290000 MinPts RU-4PB1(Der Survey) Pass warn 223.78 6940.30 6866..-Mr= OSF1.50 14323.91 110 .30 MinPts 7350.31 261.24 717582 7089.0 C OSF1.50 1480000 11398.70 MinPI-0-SF 7555.20 26605 7377.50 7289.1 C OSF1.60 15300.00 1173027 MinP1-0-SF 7877.75 27262 7895.66 7605.1,MEE OSF1.50 16220.00 12302.00 MInPt-0SF 7918.31 300.5'.MZ13731111111= 39.64 OSF1.60 16330.00 12481.76 MinPts 792954 302.38 7727.62 7627.1 M OSF1.50 1637000 1251504 MInPt-0SF 8009.87 30546 7805.70 7704.20 M OSF1.50 1685000 1275671 MInPt-OSF 8058.82 305.40 7852.89 775142 39.69 OSF1.50 16808.98 12900.00 TD R-09PB1(Def Survey) Pass Erin 266071 7303.741 721538 4233 0571.50 14323.81 1106930 MinPts 7590.20 26543 7412.92 73247 43.0 0571.50 14510.00 11198.59 MinP3-0SF 7783.45 284.81 7593.24 749863 41.13 OSF1.50 14800.00 11398.70 MinP3-0SF 943034 268.91 9252.07 0183.43 53.19 OSF1.50 1680898 12900.00 TD RU-9(DefSurvey) Pass 7623.96 240.6 ZC=1EfiEltl OSF1.50 1432391 11069.30 MinPts 774288 253.7•-7 4595 OSF1.50 14520.00 1120549 MinPts 791748 28041 7730.21 7637.0 C 007150 14800.00 11398.70 MinPt-0-SF 8020.32 288.89 7828.73 7733.42 11.113I 0571.50 14050.00 11501.79 MinPl-0SF 819228 28894 7999.32 7903.'Minn OSF1.50 15190.00 11685.23 MinP1-0SF 8508.38 29422 8311.01 8214.1:C OSF1.60 15600.00 1104001 MinP1-0-SF 9340.01 29797 014194 9042.,'MINUE 0571.50 16740.00 12837.34 MInPt40SF 9386.42 298.60 9188.98 9087.73 47.29 OSF1.50 1880898 12900.00 TD RU-9PB3(Def Survey) Pass 7623.96 240.6 Cl Cl 11=11611 OSF1.50 1432391 11069.30 MinPts 774288 253.7•MUM MEXE 4595 OSF1.50 14520.00 11205.40 MinPts 791748 280.41 7730.21 76370 MBE OSF1.50 14800.00 11398.70 MinPt-0SF 8020.32 288.89 7828.73 7733.42 M 0071.50 14950.00 11501.79 MinPt-0SF 8192.28 28894 7999.32 7903. 'MEM 0571.50 15180.00 11665.23 MinPt-0SF 8508.38 294.22 8311.91 8214.1,EINEM 0571.50 15800.00 11940.01 MinPl-0-SF Drilling Office 2.10.302.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) Page 2 of 3 • • Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)1 MAS(ft)I EOU(ft) Dev.(ft) Fact. Rule MD(ft) I TVD(fl) Alert I Minor I Major 9340.91 29797 9141.94 904294 47.17 OSF1.50 16740.00 1283734 MinPt-0-SF 9386.42 29869 9186.96 9087.73 4729 OSF1.50 16808.98 12900.00 TD RU-9P82(Del Survey) Pass 7623.96 240.6 11111EME MEM MEM OSF1.50 1432391 11069.30 MinPts 7742.88 253.7.M MS= 45.95 OSF1.50 14520.00 11205.49 MinPts 791748 280.41 773021 7637.0 MEM 06F1.50 14800.00 11398.70 MinPt-O-SF 8020.32 286.89 7828.73 7733.42 06E1.50 14950.00 11501.79 MinPt-OSF 8192.28 288.94 7999.32 7903..MEM OSF1.50 15190.00 11865.23 MinPt-OSF 8508.38 29422 831191 8214.1.r 05F1.50 15800.00 11940.01 MinPt-O-SF 9340.91 297.97 9141.93 9042.9,MIME 06E1.50 1674090 12837.34 MinPt-O-SF 9386.42 29869 9186.96 9087.73 4729 05F1.50 16808.98 12900.00 TD RU-D1(Def Survey) Pens 9157.90 409.341 &884.681 8748.561 33.641 OSF1.50 14323.91 11069.30 MinPts 11221 97 397.27 10956.79 1082469 4247 OSF1.50 16808.98 12900.00 TD Drilling Office 2.10.302.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) Page 3 of 3 • • < SCIONMOP GLACIER RU-3A(P6)Anti-Collision Summary Report Analysis Date-24hr Time: January 30,2017-14:47 Analysis Method: Normal Plane Client: Glacier Oil 8 Gas Reference Trajectory: RU-3A(PR)(Def Plan) Field: Redoubt Unit Depth Interval: Every 10.00 Measured Depth(ft) Structure: Osprey Platform Rule Set: DAM AntiCollision Standard S002 v5.1/5.2 Slot: L3-S15(O6) Min Pts: All local minima indicated. Well: RU-3 Version I Patch: 2.10.302.0 Borehole: RU-3A Database 1 Project: localhoslldrilling-Cook Inlet 2.10 Sean MD Range: 14323.91ft-16808.98ft ISCWSAO 3-0 95.000%Confidence 2.7955 sigma,for subject well.For Trajectory Error Modal: offset wells,error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 57819.48 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Del-Plan Is set in a borehole Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)!MAS(ft)I EOU(ft) Dec.(ft) Fact. Rule MD(ft) I TVD(N) Alert I Minor I Major RU-3(Del Survey) Fall Major 0.00 3292 MIMI MIMS 0.00 OSF1.50 14323.91 11089.30 OSF<500 OSF<1.50 OSF<1.00 Enter Meier 0.00 25703 -171.68 -2570 R, OSF1.50 14330.00 1108.63 MInP1-0-SF 1 0.001 2574 =MU MEM -0.01 OSF1.50 14360.00 11094.97 MinPts 0.07 224.14 149.68 -224.0 MIMI OSF1.50 14370.00 11102.03 MInPt-0-SF 2021 3238 196 -303.61 0.09 OSF1.50 14848.49 11294.20 MINPT-0-EOU 28.27 331.20 -194. -304.03 0.11 OSF1.50 14687.73 11321.29 MinPt-0-ADP 38.59 34865 192 -3080 0.18 05F1.50 1475591 11368.32 MInPt-O-ADP 239.48 38222 -2.33 -122.74 0.99 OSF1.50 15403.83 11808.62 OSF>1.00 Exit Major 385.83 38841 121.02 0.79 1.50 OSF1.50 15719.87 12020.22 OSF>1.50 Exit Minor 79218 383.44 536.22 408.74 3.10 OSF1.50 18797.12 12860.17 TD RU-5A(Det Survey) Warring Aged MEM 281.86 130430 1210.87 7.97 OSF1.50 14323.91 1106930 MinPt-CICI 1493.97 284.6 =RCM 120934 790 OSF1.50 1438720 1110007 MINPT-0-EOU 116252 350.16 928.75 81236 4.99 OSF1.50 18558.84 1267643 OSF45.00 Enter Alert MEM 367.031 838.481 716.461 4.441 OSF1.50 16805.84 1289.88 MinPts Redoubt SH ST 20064 1(Def Survey) Wernilg Alert 3371 2.33 OSF1.50 1 11089.30 Enter 1 59117. 3812.121 3375.981 2105.781 2.331 OSF1.50 14380.17 11005.0 05E45.00MinPt-� SF 8402.87 388036 3815.46 2522.51 2.48 OSF1.50 14804.00 11263.48 TD RU-55(Def Survey) Peas EirM 361.701 1737291 161705 822 OSF1.50 14328.08 11072.27 MinPts 2027.59 365.88 1783.38 1661.73 8.33 OSF1.50 14442.16 11151.79 Meet-OSF 2097.54 393.41 183494 1704.14 801 OSF1.50 14799.80 11308.61 MmPt-OSF 2381.85 392.80 211965 198904 9.11 OSF1.50 1557407 11922.67 TD RU-5(Def Survey) Pass ESEMI 193.741 2466.221 2401.9 201 OSF1.50 1432757 11071.90 MinPts 2710.49 20262 2575.07 2507.86 20.16 OSF1.60 14803.61 11401.10 MinPt-O-SF 2766.00 20468 2629.21 256131 20 OSF1.50 15174.47 11654.73 MinPt-0SF RU-2 pet-Survey) Pass C 4028 285901 2725.85 11.67 OSF1.50 14328.95 1107288 MinPts 3181.74 434.3 2891.821 2747.36 1101 OSF1.50 14980.12 11508.72 MinPts 3246.14 438.82 2953.26 2807.32 11.12 OSF1.50 15548.80 11905.76 MinPt-OSF RU-2A(Def Survey) Pass C 336.341 3300.391 318861 1576 OSF1.50 1432391 1106930 MinPts 3531.47 370.81 328393 3160.66 1432' OSF1.50 1514265 11633.18 MinP6-06F 3523.80 369.601 3277.081 3154.20 14.34 OSF1.50 1527800 11724.58 MinPls ® 369.20 3277.32 3154.58 1435 OSF1.50 15319.83 1175241 MinPt-CtCt 3670.60 374.41 3420.67 3296.19 jF OSF1.50 1500497 1194334 MinPt-O-SF RU-7(Def Survey) Pas WIFIM 3640fi1 4649.82 452880 20.21 OSF1.50 14323.01 11060.30 MinPts �E 3652 467914 4557.69 20.27 OSF1.50 1438.19 1110772 MinPts 4751.23 399.12 4484.82 4352.11 1790 OSF1.50 15282.60 11727.66 MinPt-OSF 474404e0 398.961 4483.001 4350.43 17.90 OSF1.50 15298.83 11738.48 MinPts 1;y;;--1 398.91 4483.10 4350.46 1790 OSF1.50 1532400 11755.33 MinPt-CICI 4858.00 410.51 4582.00 4445..'MBE OSF1.50 18226.37 1239713 MinPt-0SF 4912.87 438.89 4819.r MEM MI-IMIMI OSF1.60 1647441 1286.43 MinPts Redoubt Shoal Unit 2(Def Survey) 1 Pass WSW 628.64 4956071 4745.851 12841 OSFI 50 15319.00 11751.99 MlnPle 5383.00 628.71 4963.53 4754.29 1286 OSF1.50 15363.30 11779.82 TO RU-6(Def Survey) Pass MEMO 40283 5536.91 540296 216]1 OSF1.50 1432665 1107125 M:nPts W40329 5569.65 543555 217.1f OSF1.50 14383.88 1111162 M:401s 5510.63 451.53 5218.28 5068.10 1837 OSF1.50 15319.91 11752.80 MlnPts 552992 452.56 5227.89 5077.36 18.371 OSF1.50 15365.73 11783.26 MinPt-OSF 5711.38 45732 5406.15 5254.04 18.77 OSF1.50 1680898 12900.00 TD RU-4A(Def Survey) Pass TI 1 253.6 MIMI Nrr 45.43 OSF1.50 14323.91 11060.30 MinPts NEM 254.2%=SE 7398.6 4531 OSF1.50 14380.00 11108.96 MinPts NESE 27163 743966 734944 4223 OSF1.50 14688.42 1130657 MinPt-CtC1 7627.14 297.0 7428.761 7330.06 38.63 OSF1.50 14790.66 11398.47 Min171s 762754 297.11 7429.14 7330.43 38.63 OSF1.50 14805.19 11402.28 MinPt-O-SF C 302.111 7190.011 7089.63 36.82 05F1.50 10808.20 12899.29 M:nP1s RU-4(Der Survey) Pas 0026.0- 257 3.MEC�.'. MEM OSF1.50 1432391 1106930 MinPts III=1:2 25791 means6528.78 MZBE OSF1.50 14380.30 11109.17 MinPts Drilling Office 2.10.302.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) Page 1 of 2 • • Offset Trajectory Separation Allow Sep. Controlling Reference Trajectory Risk Level Alert Status Ct-Ct(ft)I MAS(ft) EOU(ft) 0ev.ft Fact. Rule MD(ft) I TVD(ft) Alert I Minor I Major 7869.37 29138 7674.79 757799 4064 OSF1.50 15312.34 11747.53 MinPls 291.36 767480 7578.01 40.65 OSF1.50 15319.09 1175205 MInPt-CtCI 8625.71 307.22 8420.57 8318.50 42.25 OSF1.50 18808.98 12900.00 TD RU-9P82(Oaf Survey) Pass 9091.41 310.051 8884 381 8781.361 44.12 OSF1.50 14362.08 11096.43 MinPts 9830.66 344.52 9600.65 948614 42.92 OSF1.50 14612.43 11289.30 1,11nP1-0-SF RU-9(Def Survey) Pass 909141 310 041 8884 381 8781 44.12 OSF1.50 14382.06 11096.43 MfinPts 9947.76 32489 9730.83 9622 381 r 4606 OSF1.50 1467243 11310.73 MinPt-0-SF RU-9P83(Def Survey) Pass 9091.41 310051 8884.381 8781.361 44.121 OSF150 1436206 1109643 MinPis 9629.59 320.13 9415.84 930946 452`'11 OSF1.50 16549.78 1122604 MinPt-O-SF RU-1(Oaf Survey) Pass RU-1A(Def Survey) Pass RU-4PB2(Def Survey) Pass RU-D1(Oaf Survey) Pass R-09PB1(Def Survey) Pass RU-6PB1(Oaf Survey) Pass RU-78(Def Survey) Pass RU-4P81(Oaf Survey) Pass RU]PB1(Def Survey) Pass Redoubt Shoal ST 1(Def Survey) Pass Drilling Office 2.10.302.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) Page 2 of 2 • 0 GLACIER RU-3A(P6)Proposal Geodetic Report (Del Plan) Report Date: December 13,2016-02:09 PM Survey/DLS Computation: Minimum Curvature/Lubinei Client: Glacier Oil 8 Gee Vertical Section Azimuth: 127.103°(end North) Field: Redoubt Unit Vertical Section Origin: 0.000 ft.0.000 fl Struct Well KB urs/Slot: Os prey Platform/1_3-51515(06) ihiiit�►Study TVD 00 TVD Reference Elevation: 90.0ft above MSL Borehole: RU-3A Seabed Elevation: 651%0 ft below MSL .-- ANN: 507332050401 Magnetic Declination: 16.102° Survey Name: RU-3A(P6) Total Gravtty Fled Strength: 1001.3388mgn(9.80666 Based) Survey Date: December 13,2016 Gravity Model: DUX Tort I AHD/DDI/ERD Ratio: 191.849°/10360.393 ft/6413/0,803 Total Magnetic Field Strength: 55389.]6901 Coordinate Reference System: NAD27 Alaska Stale Plane,Zone 04,US Feet Magnetic Dip Angle: 73.510° Location Let I Long: N 60°41'43.86599',W 151°40'04.60029' Declination Date: December 31,2016 Location Grld N/E Y/X: N 2449933.254 flUS,E 200627.483 605 Magnetic Decllnetlon Model: SCUM 2016 CRS Grid Convergence Angle: -1.4570° North Reference: Grid Noah Odd Scale Factor: 1.00000199 Grid Convergence Used: -14670° Version/Patch: 2.102540 Total Corr Mag North->Grld North: 17.5594° Local Coord Referenced To: Well Head Comments MD Incl ANuelon Zone DLS Directional Exclusion Zona Ezcleo m Odd TVDSS TVD VSEC NS EW TF Angle GMag Th Northing Easting (0) (°) n (R) (R) (R) (0) (11) 11 C/10011) Difficulty Index Alert 1°1 (nT) (flUS) (RUS) RTE 0.00 000 000 -90.00 0.00 000 000 0.00 OM WA 0.00 16.39 15629.98 2449933.25 200627.48 93.00 0.00 000 300 93,00 000 0.00 0.00 276M 0.00 000 16.39 16630.19 2449933.25 200627.48 177.00 0.25 75.00 8100 177.00 -0.18 0.02 -0.18 237.88M 0.30 0.00 16.45 15682.43 2449933.27 200627.30 90' 20000 030 9788 110.00 20080 -0.22 '00/ .0.28 20204 0.80 0.00 1062 1584819 244993924 20062720 267.00 0.75 02.00 177.00 267.00 -017 -051 -0.60 186M 0.80 000 17.14 18322.86 2449932.74 200628.88 361.00 2.60 86.00 260,96 360.96 0.96 -292 -1.00 180M 2.25 098 18.94 17983.52 244993034 200626.48 446.00 450 80.00 35577 445.77 4.32 -8.79 -1.23 173M 2.04 1,64 2072 19601.96 244992447 200626.25 53500 600 73.00 44440 534.40 9.66 -18.90 -0.66 50.07L 183 205 2199 20738.12 244991636 200628.82 82400 700 64.00 532,83 822.83 17.24 -28.73 140 41.071 160 233 2255 2124233 2449906.53 200828.88 71500 8.00 58.00 62305 713.05 27.11 -3793 5.30 41.18L 139 2.65 23.11 21743,42 2449895 32 200832.78 827,38 10.04 4842 734.04 824.04 42.95 -53.53 13.36 4.531 2.25 2.82 24.15 22663.20 2449879.73 20064084 917,68 11.92 47.70 822.68 912.68 69.01 68.12 22.47 11020 209 3.00 25.70 2402077 2449865.14 2064995 1006,98 13.20 48.79 00984 999.84 77.12 -84.83 32.68 2.46L 1.46 314 26.93 2509162 2440848.62 200660.16 1097,28 15.01 48,49 99742 108742 9759 -103.42 4413 5.371 201 3.29 28.51 2644091 2449829.83 200671,62 1190.98 16.38 4804 108782 1177.62 12121 -124.96 57.46 4.21 1.45 3.41 29.67 27420.31 244980829 200684.94 1288.38 19.08 4743 1180.39 127039 148.96 -160.02 73.29 2.871 2.80 3.55 32.06 29404.03 2449783.23 200700.78 1381.78 21.49 47.10 1268.00 1358,00 179.35 -077.26 90.81 18911 2.58 3.88 34.22 31158.18 2449756.00 200718.29 1475.18 2305 45.74 1354.43 1444.43 212.76 -206.73 110.40 3.731 1.76 3.78 35.46 32144.00 2449728.52 200737.88 1567.08 2528 45.40 1438.27 1628.27 248.44 -237.76 131.67 10.419 2.43 388 37.48 33711.96 2449005.49 200759.15 1667.38 28.70 45.98 1619.43 1609.43 285.94 -27045 153.97 66,470 1.80 3,97 38.90 3478894 2449662.81 20078145 1752.08 27.15 48.16 1603.87 1003.87 326.24 -306.44 17727 10079 1.15 4,04 3866 35369.78 244962882 200804.75 184198 3014 4928 1888.02 1778.02 368.96 -34573 201.12 6.91_ 317 4.14 4266 3764620 244958752 200828.60 194428 31.84 48.89 1770.68 1860.58 414.04 -388.27 22660 3.141 1.78 4,21 4422 3863921 244954499 20)854.08 2040.08 36.26 4848 184993 1939.93 664.81 -434.08 254.48 6,391 4.62 432 48.37 4141639 2449490.18 200881.96 2135.98 40.40 47.54 1925.14 2015.14 520.37 -484.50 288.00 110.721 4.36 4.41 52.19 43772,38 2449448.76 20091348 2230.98 40.13 4641 199784 2087.64 578.11 -535.08 309.46 20.12L 0.82 447 51.73 43497.77 2449397.28 200946,94 2325,98 40.61 46.14 207001 2160.01 63623 -587.15 353.62 32.780 0.54 4.52 62,14 43743.89 2449345.10 200981,11 2421.08 42.00 47,47 214145 223145 69532 630.68 387.98 22.331 1.73 4.57 53.72 44663.88 2449293.57 201016.48 2514,28 43.34 46.67 2209,98 2299.98 75469 X2.70 422.32 45.121 1.65 4.82 54.86 4531099 2449240.66 20104080 2809,28 43.86 46,92 2278.78 2368.78 816.56 -747.20 458.68 042.791 0.77 4.67 65.22 45512.05 2449186.06 201086.16 2703.58 43.57 46,60 2346.93 243693 87831 -801.07 495.34 36.141 039 4.71 64.88 45324.74 2449132.18 201122,63 2798.28 44.28 4486 241514 2505.14 940.74 -855.03 532,81 115.731 0.93 4.75 55.43 45825.52 2449078.22 201180.29 2889.98 44.12 4438 248088 2570.88 1001,70 -907.16 569.83 178.615 040 4.78 55.18 45490.82 2449026.10 201197.31 2985.98 42.09 44.57 2550.97 2640.97 0064.31 -960.54 607.94 17140 2.12 4.82 53.27 44409.35 2448972.71 201235.43 307938 40.71 44.89 2821.03 2711.03 1123.18 0010.97 64381 3.99R 149 4.86 5200 43668.15 244892229 201271.09 3176.18 4337 45.16 2002.91 2782.91 1184.84 -105408 680.76 137.71 276 491 5461 45173.86 2448869.17 201308.24 327228 43.13 44.84 2782.91 2852.91 1247.60 -111802 718,53 10841 0,34 493 54.32 45010.53 244881523 20134601 336808 43.03 4459 2832.85 2922.85 130990 -1171.46 76634 3.096 019 496 54.22 44957.15 244876180 201383 82 345278 43.72 44.64 2894.39 298439 136540 -121890 79004 10410 0.78 4.98 54.85 4530805 2448714,35 201417.52 19.8,9' 956700 44.01 44.72 2999.49 9029.40 1401.22 -124958 811.78 10.950 054 500 55.14 45470.11 2448899.70 201430.25 356002 44.29 4479 2971.53 3061,53 143641 -1279.72 83308 127.421_ 0.54 5.01 55.42 4562746 2448663.64 201460.56 3655.72 44.12 44.47 3040.13 313013 160003 -1336.13 871.70 147.558 029 5.03 55.20 45504.32 2448599,13 201499.18 3751.72 43.74 44.82 3109.27 319927 1563.54 -1388.45 91024 160.611 0.47 5.06 54.90 45339.32 244854481 201537.72 3847.82 43.36 44.82 3178.78 3268.76 1626.51 -1442.38 948.40 96.081 0.43 5.08 54.49 45109.03 2448400.87 201575.88 3944.02 4329 43.77 3248.92 333892 1689.72 -1496.02 087.09 80.019 0.81 5.10 64.27 44985.54 2448437.24 201616.57 4040.02 43.56 45.84 3319.64 3408.64 1752.58 -154994 1025.12 63.359 1.51 5.13 54.92 45361.26 2448383.31 201652.60 4138.12 4409 47.33 3387.98 347798 0815.31 -1605.49 1081.76 23.541_ 1.21 6.15 55.71 45784.36 2448327.77 201889.24 423102 44.17 47.28 3456,09 3546.09 1877.32 -1661.09 1097.45 66.52L 009 517 55.77 45821.90 2448272.16 201724.93 4324,72 44.38 46.86 3523.19 3813.19 1938.83 -1715.02 1133.10 157641_ 050 519 55,94 45860.00 2448217.33 201760.58 4419,02 4414 46.63 3590.74 3880.74 2000.86 -177086 1100.33 80.371 026 520 5581 45731.83 244816240 201796.81 4614,12 44.22 4587 365894 3748.94 205349 -1825.93 120620 5.761 0.49 522 55.66 4670727 244810733 20183388 4606.32 4478 45.79 3724.70 3814.70 212469 -1879.40 124249 148.989 0.61 5.24 58.09 45992.75 244805386 201800,97 4702.42 44.11 46,37 379331 3883.31 218833 -1935.23 1280.04 105.83R 082 5.28 65.56 45701.25 2447998.02 201907,63 4797.72 44.01 4688 3861.79 3961.79 2250.79 -1900.58 1318.60 179.720 039 5.27 5555 45700.57 2447942.68 201943.98 4892.42 42.64 46.89 393068 4020,88 2311,93 -2045.00 0352.00 155.550 145 5.30 5423 44987.51 2447888.26 201979.48 4988.12 41.95 47.38 4001.47 409147 237244 -208808 1386.96 98.051 0,79 5.31 53.65 44638.09 2447834,17 202014.44 508342 41.86 4636 4072.40 416240 2432,34 -2152.38 1421.75 71.280 0.71 5.33 53.38 44484.61 2447780.87 202049.24 5178.82 41.91 46.58 4143.42 423342 2492.43 -2205.48 1458.94 159.70 0.16 5.34 63.47 44535.78 2447727.78 20208442 5274.22 41.74 46.00 4214.52 4304.62 2552,38 4258.61 1491.92 136231 0.19 5.36 5323 44453.60 2447874.65 202119.41 5370.12 4143 46.24 4286.25 4376,25 261244 -231166 1527.09 56.11 0.45 5.37 52.95 44233.42 2447621.59 202154.67 5466.12 4186 45.29 4357.98 4647.98 257287 -236440 1562.98 139.939 080 5.38 53.18 4437223 2447688.85 202190.46 • 5581.82 4160 45.82 4429.40 451940 273333 -2415.87 1590.10 84.658 0,36 539 6300 44263.21 2447618.38 202226.58 5656.12 41.66 45.81 4409.89 4589.89 2792,70 -2468.63 163439 110.761 0.15 541 5300 4431782 244746482 202261.87 575192 41.67 45.45 4671.51 4661,61 2853.03 -2521,15 167030 130.719 027 542 52.93 44229.09 244741211 202297.79 5845,92 41.12 4625 4642.08 4732.08 2011.83 -2672.53 1705.18 98990 074 5.43 52.65 44062,71 2447360.72 202332.65 5939.52 41.03 47.15 471264 4802.84 2960.75 -262393 173893 120.571 0.64 6.44 52.73 44107.92 244730922 20236641 8037.02 40.80 46.55 478632 4876.32 3929.86 -2677.40 1773.60 130339 067 5.46 52.40 4391480 244726586 202401.33 6130.22 40.64 4684 485696 4948.96 3087.16 -2728.21 1807.23 140.85L 027 5.47 52.30 4385534 244720504 202434.71 6225.22 40.37 48.50 4929.19 6019.19 314528 -2779.78 1841.13 118.11 0.37 5.48 51.97 43666,40 2447053.49 20246862 8320.72 40.26 46.18 600201 509201 3203.62 -2831.19 1875.38 156.4R 0.25 6.49 51.81 43668.29 2447102.05 20250286 6415.12 39.39 48.78 5074,51 5180.51 3260.65 -2881.59 1808.77 127.651_ 1.01 6.50 51.08 4313040 2447051.66 202538,25 6509.72 39.09 46.16 5147,78 5237.78 3317.11 -2931.48 1941.82 120.820 0.52 551 600.60 4288751 2447001.78 2026669.30 6604.52 3903 46.32 5221,39 5311.39 3373.54 -2981.14 1975.02 75.21_ 0.12 5.52 50.66 42670.35 2446952.11 202602,60 6700.22 3904 46.26 5295.73 5385.73 343047 -3031.28 2008.47 51.329 004 553 60.66 42870.13 2446001.98 20263695 6796.52 3984 47.80 537010 5460.10 3487.97 -3082.60 2041.76 6.149 131 5.54 51.70 43502.48 244686085 202869.24 6889,52 4125 4803 5440.77 553077 3544.48 -3133.82 2073.88 16091_ 1.52 5.66 53.10 44328.07 244679943 202701.34 6983,72 42.04 6769 5511.16 5801.16 3603.01 -3188.82 2107.16 141.999 0.87 5.57 53,80 4473225 244674643 202734.85 7077.72 41.81 4796 5581.10 5671.10 3861.76 -3239.99 214081 138821 0.31 5.58 5362 44633.43 244669327 202768.09 717122 41.40 4737 5651.01 5741.01 371988 -329244 217381 101.29E 0,61 5.59 53.12 44345.13 2446640,81 202801.30 7287.12 41.28 4643 5723.01 681301 377948 -3345.51 220840 176.251_ 0.68 5.60 52.84 4417948 2446587,75 202835.89 7381.62 40.96 46.40 5794.19 6884,19 3838.14 -3397.29 224279 135.850 032 581 52.54 44007.69 244653597 202870.27 7455.22 4073 4676 5864.99 696499 389587 -3448.39 2278.51 11591 0.37 5.62 52.37 43904.94 2448486.86 202904.00 7549.22 40.45 45.86 693637 602637 395382 3499,28 2310.44 170449 0.69 5.03 51.94 43548.56 2446433.97 20293792 7643.62 40.03 45.97 5006.43 609543 401135 3549.79 2344,81 132.541 0.45 5.63 51.55 43419.94 2446383.67 20297209 7736.82 39.93 45.80 6079.85 6169.85 4065.04 3599.36 2375.20 68.931_ 0.18 5.84 51.43 43344.02 244633389 203005.69 7828.12 40.06 45.32 5149.60 6239.80 4123,70 3647.76 241138 125.829 036 5.85 51.45 43360.95 2446286.60 203038.86 7922.52 39.77 45.93 8222.21 6312.21 4181.12 -3697.74 2445.58 106.389 0.51 5.666 51.30 43266.58 2446236.51 203073.06 8017.22 3883 48.60 629507 5385.07 4238.25 -3748.07 2470.13 31.81R 0.53 5.87 51.30 43288.68 2446185.18 203106.61 8114.22 4047 47.49 6369.32 6659.32 4296.90 -3800.47 2513.04 177.400 1,02 588 52.25 43837.83 2446132.78 203140.52 821542 39,74 47.54 6446.73 6536.73 4358.60 -385546 254605 109.09L 0.72 5.89 51.56 43424.61 2446077.79 203175.53 830702 3958 46.71 6517.26 8607.28 4412.91 3904.56 2579.78 3008L 0.61 5.70 5124 43231.87 2446028.70 203207.28 840292 40.14 46.19 6590.88 5650.88 4470.89 -3955.76 2613.74 150.731 0.70 571 6170 4351131 2446977.49 203241.22 649732 39.54 45.76 6663.31 6753.31 4628.16 -4005.94 2647.52 108.269 0.61 5.71 51.14 43174,22 2446827.32 203276.10 869202 3955 46.24 6736,28 8826.28 4685.29 -406597 268137 162.161 0.34 6.72 51.14 43176.17 244587728 203308.86 868322 39.08 48.. 6806.84 8896.84 4639.91 -410394 2713.58 148.111 0.54 5.73 5085 4287522 2445829.31 20334107 8776.82 38.58 45,60 6879.60 8989.60 469540 -415235 2746.54 151.679 0.63 574 5008 4262438 2445780.00 20337403 8871.02 37.72 4626 8953.84 7043.84 4750.61 -420082 277925 140.771 1.04 5.76 4939 4209537 2445732.83 203406.74 8985.72 37.24 4581 702899 711699 4805.15 -424836 2811.53 172.711 0.86 6.76 4882 41731.72 2445684.90 203439.01 9000.02 36.38 4542 7104.60 719460 4858.74 -429492 2843.51 158.689 0.94 5.76 4794 4117046 244563833 203470.99 9166.72 35.88 45.74 718281 727281 491281 -4341.94 287573 15521 0.53 5.77 47.54 40909.92 2445591.31 20350322 9233.32 34.88 4493 724506 733506 495493 -4378,42 2900.95 176320 1.44 5.78 46.45 40187.27 2446564.83 203528.44 9275.92 3444 44.98 7280.10 737010 497799 4398.25 2904.87 159.35L 104 5.78 46.04 3991346 244653600 20364235 9-5,8' 0392.00 3390 44.88 792548 741048 5008.03 4424.03 293309 150.IL 085 570 45.56 30591.05 2446600.22 203580.51 9382.60 3359 44.40 7368.66 746845 5034.82 4446.91 2949.32 2149 0.85 5.79 45.13 30208.37 2445486,34 203576.81 9475.70 36.79 44.80 7444.60 7534,60 5098.07 4490.63 2980.51 11.285 344 5.81 48.21 41342.62 2445442.62 203607.99 9571.80 40,18 45.64 751083 7609.83 514291 -4539.68 3014.88 2.60 3.67 5.83 51.62 43469.07 2445393.67 203642.16 966540 42.51 45.81 7590.10 7680.10 520149 4590.77 3049,49 2.975 2,51 5.85 53.91 44809.48 2445342.49 203678.97 9757.80 44,54 45.96 7657.10 7747.10 5261.73 4643.45 3085.17 18.925 220 586 65.89 45913.05 244626981 203712.68 9853.70 4599 46.85 7724.59 7814.59 5328.06 4700.13 312296 115471_ 180 587 67.42 4872543 2446233.13 203760.44 9951.10 45.78 45.97 7792.41 768241 5392.08 -4758.30 3161.74 116.719 0.55 588 57.07 48543.74 2445174.96 203789.22 9993,77 4542 46.93 7822.27 7812.27 542084 4783.70 3178.59 72.35R 1.79 5.89 5692 46465.71 2445149.55 203806.07 1004427 46.63 4741 7857.88 794768 546486 -4813.96 3198.11 HS 071 5.59 57.11 46568.71 244511930 203825.59 19139.77 45.59 47.41 7024.64 8014.54 551881 -487141 323483 06.610 0.06 5.90 57.17 4659984 244506186 203862.32 10236.87 45.66 47.78 7991.88 808188 558296 -4929.41 327185 121.151_ 028 5.90 6721 46820.58 244500384 203899.13 1033167 45.27 47.10 805906 814906 584687 -498686 330833 37.921 0.59 5.91 56.81 4640748 2464946.40 20393501 10427.27 45.61 46.73 8126.14 8216.14 571095 -5043,93 3345.52 169015 0.45 5.92 67.07 4654505 2444889.33 203973.00 10521.37 45.39 46.79 819209 828209 5774.18 -5100.06 3382.31 82349 0.24 5.93 56.86 46639.36 2444833.19 204009.79 Drilling Office 2.10.254.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) 12/20/2016 3:06 PM Page 1 of 2 S 0 Comments MD Incl Azlm Grid TVD(8 TVD VSEC HS EW TF DLS DirectionalExclusion Zone Exclusion Zone Angle (B) GeoMag Th Northing Easting (ft) (") 1`) (B) go (B) (8) C1 (n1008) Difficulty index Alert (,) (nT) (BUS) GIGS) 0620.]] 45.43 14720 826187 8351.87 5840.72 -5159.43 3420.88 28.174 030 593 58.90 46500.42 2444773.83 204048.35 0]16.0] 45.55 14729 8328.88 841868 5904.53 -5216.58 3457.63 4139L 0.14 5.94 57.11 4657069 244471667 204085.12 0810.77 45.88 146.88 8394.81 8484.81 6968.24 -5273.49 3494.47 175.858 0.47 5.95 57.36 4869833 2444659.76 204121.98 090707 45.39 146.93 8462.14 8552.14 603301 -5331.17 3532.06 106.381 0.51 5.95 56.89 48455.10 244460209 204159.55 1001.87 45.24 146.20 8528.81 8618.81 6098.56 -538741 3569.20 159.321 0.57 596 56.61 46308.49 244464584 204106.68 1091.27 44.70 145.91 8592.05 8882.05 8156.32 -5439.83 360448 HS 0.85 5.97 56.03 45998.29 2444493.43 204231.98 1188.87 44.82 145.91 8681.21 8751.21 822124 -5496.83 384292 139.841 0.12 6.97 59.15 46061.24 2444436.63 204270.40 1283.17 4432 145.79 8728.30 881830 6284.26 -5551.70 368028 135.791 0.14 5.98 5603 45997.50 2444381.55 204307.76 1374.77 44.44 14540 8793.55 8883.55 6345.24 -5604.75 371661 160.84L 0.43 6.98 5589 45811.49 1444328.50 204344.09 1469.47 44.04 145.20 8861.39 8951.39 6408.00 -5659.07 375422 173.68L 0.45 5.99 5527 45580.01 2444274.19 204381.70 1563.37 43.79 145.16 8929.04 901904 8469.91 -5712.54 3791.41 118.11L 0.27 599 55.02 45443.22 2444220.72 20441089 1657.77 43.47 144.28 8997.36 908736 6531.99 -576511 3829.03 166.14R 033 6.00 54.54 45178.80 2444187.55 204466.51 175187 43.11 144.41 9065.86 915588 659382 -5818.14 3886.64 69.189 039 6.01 54.22 44998.12 2444115.12 204494.12 1848.67 4363 146.33 9136.23 9226.23 6656.73 -5872.83 390441 106911 146 602 55.08 45480.70 2444060 42 204531.89 1841.57 43.43 145.47 9203.58 9293.58 6]1)30 -5925.81 3940.28 175.811_ 0.67 6.02 54.73 45284.79 2444007.44 20458736 2041.47 43.15 145.44 9278.30 9368.30 6782.32 -5982.23 3979.12 107.04L 0.28 6.03 5445 45131.09 2443961.02 20480660 213].5] 42.84 143.99 9346.59 9436.59 684477 -6035.73 4016.07 44.33L 1.08 6.04 53.88 44807.26 2443697.53 20464445 2233.27 4305 14389 9416.84 9508.64 6907.21 -6088.37 405544 163.39L 0.31 6.04 5403 44889.77 244384489 204682.92 2325.17 4167 14307 948455 9574.55 8066.85 -6138.07 4082.37 129.35L 1.57 8.05 52.68 44056.18 2443795.19 204719.86 2420.17 40.88 141.58 9555.95 9845.95 ]02].11 618]6] 4130.67 46714 133 8.06 51.64 43435.22 2443745.58 204758.15 251737 41.40 14241 0629.15 8719.15 7088.91 6238.06 4170.04 78.099 038 807 6220 43829.27 2443695.20 204797.52 2609.27 41.94 14587 9897.81 9787.81 7147.31 -6287.57 4206.81 143.181 2.57 808 53.37 4451830 2443645.69 204833.29 270407 41.29 145.13 976858 985888 7207.05 -6338.45 4241.47 114.99L 0.86 608 52.81 44073.16 244359380 204868.95 2798.50 41.03 144.27 9839.78 992938 7266.29 6390.17 4277.38 113.11 0.68 609 52.20 4383143 244364308 20490488 2894.10 40.78 143.36 9912.03 10002.03 732624 -8440.70 4314.34 19.43L 0.88 6.10 51.79 43586.60 2443492.58 20494182 2989.70 4091 143.29 9984.35 10074.35 7386.27 -6490.85 435168 55918 0.14 8.10 51.90 43653.60 244344241 204979.16 3038.20 41.95 145.54 1002031 10110.71 7416.91 6518.94 4370.35 111.02L 3.74 8.11 53.32 44488.82 2443416.31 204997.83 3084.80 41.64 14430 10055.46 1014548 744847 -6542.36 438820 9653( 1.89 6.11 52.79 44180.88 2443390.89 205015.68 3175.90 41.64 142.89 10123.59 10213.69 7504.45 659103 4424.08 160.831. 1.03 6.12 5243 43966.87 2443342.23 205051.57 3270.80 4044 141.94 10195.23 1028523 7564.48 684036 4482.04 59.340 1.33 6.13 51.19 43228.18 1443292.90 205089.53 3360.10 41.36 14423 10268.53 10359.53 7626.35 689182 4500.69 146.77L 139 8.14 52.51 4401894 244324144 205128.17 3480.10 39.77 142.59 10338.66 1042866 7683.13 -6739.33 4635.95 133.16L 2.10 615 50.68 4291543 244310392 205163.43 3505.11 39.13 141.50 10373.42 10463.42 771037 -6781.88 4553.53 155.544 2.10 6.15 49.86 4240841 24431]13] 205181.02 3566.40 3885 141.85 10421.12 10511.12 774801 -6792.07 4677.40 61.578 0.88 6.15 49.47 4216464 2443141.18 205204.88 3869.21 3935 143.84 10493.25 10583.26 7804.21 -6838.82 461266 24.83R 1.55 8.16 50.51 42816.28 244309463 205240.15 3755.71 41.76 14549 10566.57 10656.67 7864.02 -6889.81 4648.93 41.958 2.73 6.17 53.13 4438147 2443043.44 205278.41 384801 42.47 14643 10635.03 1072503 7922.59 -8941.10 4683.57 15.566 1.03 618 5398 4487432 2442992.15 20531105 394221 43.69 14687 1070391 10793.91 7983.15 X94.18 471890 48.466 1.20 8.19 55.12 46509.71 2442938.47 205346.38 4040.61 44.36 148.15 10776.74 1086434 8047.16 -705140 4755.58 124.57L 1.22 6.18 56.12 46059.78 2442880.88 205383.06 4135.41 4398 147.36 10842.74 10931.74 8108.97 -7108.26 479083 168.78L 0.71 6.20 55.61 45781.99 244282499 205418.31 4229.21 42.88 146.97 10910.86 1100088 8169.54 -7162.44 4825.79 39.288 121 6.21 54.48 45155.64 2442]]081 205453.28 Tie-11 Sunray 4323.01 4457 148.92 10979.30 11088.30 8230.70 -7217.92 4860.51 83.18 2.28 622 56.46 48244.64 2442715.33 20548800 Top Whiubck(KOP) 4362.00 44.73 149.36 11006.39 11096.39 8255.61 -7240.90 4874.24 301 0.92 8.22 56.69 4836891 244269235 20550133 Base Whipstock 437800 4647 147.98 11017.59 11107.69 8266.14 -7250.88 4880.19 HS 12.50 6.23 58.13 47117.52 2442682.59 205507.67 Cry2/100 439800 46.47 14798 1103136 11121.36 8279.69 -726296 4887.88 93.86L 0.00 6.23 68.13 4]11].62 2442670.30 205515.36 4400.00 46.47 14793 11032.70 11112.74 828106 -7264.19 488865 93.82E 2.00 6.23 66.11 67111.13 2442889.07 205516.13 ' 4500.00 46.37 146.17 1110189 11191.89 8349.34 -732461 4828.56 91.92L 2.00 8.24 57.50 46794.43 2442608.64 205656.05 4600.00 48.33 142.41 111]0.]2 11280.72 841883 -7382.98 4971.30 90.01L 200 825 58.93 46493.]] 2442550.27 206596.78 4700.00 46.37 139.64 11239.75 11329.75 848885 -7439.23 5018.80 88.111 2.00 826 56.40 46210.93 2442494.03 205844.28 4808.00 46.46 136.89 1130830 11398.70 855990 -7493.27 5065.02 86.21_ 2.00 627 55.81 4594763 244243999 205892.50 4000.00 46.63 134.14 11377.49 1146749 8831.70 -7545.06 5115.88 84.321 2.00 6.27 55.46 45706.52 24423%21 205743.36 5000.00 4686 131.41 1144602 11536.02 870417 -]594.60 5169.33 82.451 2.00 6.28 55.06 45486.13 2442338.76 20579881 510000 47.16 128.71 1151421 11604.21 8777.20 -7641.56 5225.31 60.6L 2.00 6.29 54.71 45290.85 2442291.69 205852.79 520000 47.51 12603 1158199 11871.99 8850.72 -7886.18 5283.74 76.79L 2.00 6.30 54.41 45120.98 2442247.08 205911.21 5300.00 47.93 123.39 1184927 11739.27 8924.63 -772830 6344.55 77.01L 2.00 6.31 54.15 44977.62 2442204.96 205972.04 End Cry 5314.81 4800 123.00 11859.18 11749.18 8935.60 -7734.32 5353.76 HS 2.00 6.31 64.12 44968.71 2442198.94 205981.24 5400.00 48.00 12300 11716.19 11808.19 8998.75 -7788.80 5408.85 HS 0.00 6.31 54.12 44959.10 2442164.45 206034.34 5500.110 48.00 123.00 11783.10 11873.10 907288 -7809.28 5489.18 HS 000 6.32 54.12 44959.57 244212398 206086.66 5800.00 4800 123.00 11850.01 11940.01 9147.00 -7849.75 5531.50 HS 000 8.32 54.12 4496003 2442083.50 206158.99 Cry 223/100 5689.65 4800 123.00 11910.00 12000.00 921345 -7886.03 6587.38 188.421 0.00 6.33 54.12 4496045 244204722 20821488 5700.00 47.77 122.94 11916.84 12006.94 8221.11 -7890.21 6593.82 168.38L 2.23 6.33 53.89 44830.65 244204304 206221.30 580000 45.60 122.31 11985.54 12076.54 9293.64 -7929.44 565509 167.95L 2.23 6.34 61.89 43540.87 2442003.81 208282.58 590000 4342 12163 12056.85 12146.85 9363.48 -7966.57 571455 167.48L 2.23 6.35 49.49 42187.81 2441968.69 206342.03 6000.00 41.25 12090 12130.77 12220.77 9430.45 -8001.53 5772.11 166.02L 223 6.35 4729 40773.43 244193173 206399.59 6100.00 39.09 120.10 12207.18 12297.18 9494.53 -8034.27 5827.68 166.31L 223 8.36 4509 39300.23 2441888.98 206455.16 6200.00 36.93 119.23 12285.97 123]5.9] 9555.68 -8064.75 5881.17 165.62L 223 6.37 4289 37770.74 2441868.50 208508.85 6300.00 34.77 118.26 12367.02 1246702 0613.52 -8092.03 5932.51 16484L 223 8.38 40.70 36187.65 244184033 206569.99 6400.00 32.83 117.18 12460.21 1254021 9688.26 -8118.74 5981.62 16394L 223 639 38.51 34553.83 2441814.51 206609.10 6500.00 30.50 115.96 12535.41 12625.41 9719.72 -8142.17 6028.42 162.9L 223 630 36.32 32872.31 2441791.08 20666590 6600.00 28.38 114.50 12622.50 12712.50 9767.82 -8163.17 6072.85 161.71L 2.23 6.40 34.14 31146.35 244177008 208700.33 6700.00 26.27 11301 12711.34 12801.34 9812.49 -8181.71 6114.83 160.3L 2.23 6.41 31.96 29378.08 2441751.54 206742.31 680000 24.19 111.18 12801.80 12891.80 9853.66 -819736 615430 158.65L 2.23 6.41 29.79 27575.52 2441735.49 206]81.]9 End Cry/TD 6808.98 24.00 11100 12810.00 12900.00 9857.18 -8199.08 615733 2.23 6.41 2960 27411.76 2441734.17 206785.21 Survey Type: Del Plan Drilling Office 2.10.254.0 Redoubt Unit\Osprey Platform\RU-3\RU-3A\RU-3A(P6) 12/20/2016 3:06 PM Page 2 of 2 0 0 • 1 g . - ii I- i 1 1 i i i i 1 0 g Q / Q $ 8 $ g fdaison Oa inns 7M 2TS fi R ININIMIF b0 Nl/Ios +� i I I P : r -r 1 31 i 9 i E ; i it I i 1 a F i .._. , w i I ' 3 ; t 4 R I a i i I: a gii ggi i ggI i I:. 1; !C R S g xx gr, gi ki - zK z& a (4)ML a Olcuu. • Geothermal Temperature Profile MD IVO Temperature Gradient at) tit; (denFl (denE11001t1 0.0 0.0 80 0 0 90.0 90.0 60 -0 0 160.0 159.9 77 -1.8 15226 0 12345 4 190 0.9 it degF 75 100 125 150 175 200 o- AMISS 141\ Tabir ..�S�l9sbli� P A- Temp. Profile 61 119 mm • Geological Well Prognosis RU-3 A Water Injector Surface Location:X=200627.483 Y=2449933.254 Lat/long: N 60° 41'43.66599", W 151°40' 14.50029" Top Hemlock Formation:X=206289.4 Y=2441997.8 Bottom Hole Location:X=206785.21 Y=2441734.17 Kenai Peninsula Borough,Alaska Ground Elevation: Mean Sea Level KB Elevation Est. 90'feet above MSL Critical Formation Tops Formation Est. M.D. Est. SSTVD Potential KOP (Tie-In) 14, 323' 10,978' Sidetrack Upper Hemlock 15,750' 11,951' Oil (Primary Injection Objective) West Forelands 16,700' 12,711' Total Depth 16,808' 12,810* * TD will be determine upon thickness and depth of the Hemlock formation. The Plan is to TD in the lower Hemlock. • Permitted TD.Actual total depth may be shortened due to mechanical hole conditions, depth of intersection of Top Hemlock and thicknesses of Hemlock Formation in the sidetrack as well as Top of West Forelands Formation. Note:The above tops are estimated from seismic and offset well control. Measured depths are estimated from directional plan RU-3 A(P6) dated December 13,2016 by Schlumberger. These depths are not refined and may be slightly modified before spud. For planning purposes,they should be close. Formation Evaluation Open Hole Logs LWD logs or comparable logs are to be run to Total Depth. Evaluation minimum will consist of a Gamma Ray and Resistivity from Kickoff to TD.( A 1"=100' , 2"=100' and 5"=100' MD and TVD s • log to be provided twice daily with one report to be received no later than 5:00 am and the second no later than 2:30 PM daily by email to people designated on a separate list. Data in a .las format to be provided to Company man, Cook Inlet Energy geologist in the Anchorage office, and State of Alaska AOGCC ASAP after logging concluded. An Open Hole suite of logs will be run over the bottom 2000' of hole to be decided prior to reaching TD. Purpose of open hole logs is to evaluate formations drilled. For open hole logs a triple combo suite consisting of a Gamma Ray, Resistivity, Caliper, Density, and Neutron log shall be run. Cased hole Logs Engineers are to be provided a Borehole volume survey at each casing point in order to assist in determining cement volumes necessary. If well is cased for production, a Cement Bond Log/ Cement evaluation Type survey is to be run from PBTD to shallowest potential evaluated in wellbore. A 5"=100' MD and TVD log to be provided (No. of copies to be determined) after each run including both paper copies and digital data. Data in a .las format to be provided to Company man, Cook Inlet Energy Anchorage office, geologist, drilling personnel and State of Alaska AOGCC ASAP after logging concluded. Geologic Hazards Primary geologic hazards expected to be encountered in this well are similar to those encountered in other wells previously drilled in the Redoubt structure. There are numerous coal beds present throughout the Tyonek and Hemlock formations. These can range from a few feet thick to upwards of fifty feet in thickness and should only be a concern once the well has kicked out and sidetracked out of the original RU-3 wellbore. Sloughing coals have proven problematic in drilling operations to date. Although no abnormal pressures are expected, care should be exercised when drilling. We are kicking off at a depth sufficient that no shallow gas hazard will be encountered during drilling. We will be drilling an interval which has produced gas to depletion from the original RU-3. Pressure separation is expected due to faulting and this zone should not cause a problem. The Hemlock top is provided so that reasonable care can be exercised when drilling the targeted interval. Critical Personnel and Contact Lists A list of critical personnel addresses and contact information will be provided prior to spud of well. • - DELVED GLACIER JAN 11 2017 AOGGC January 10th, 2017 Mr. Guy Schwarz Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Cook Inlet Energy, LLC: RU-03A Dear Mr. Schwartz, Please see the attached information in regards to the additional documentation required to convert RU- 03A to a water injector after sidetracking. If you have any questions, please contact me at(907)433-3808. Sincerely, Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy(a Glacier Oil &Gas Corp.owned company) 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 Stephen.Ratcliff@CookInlet.net 0: 907.433.3808 C: 907.433.9738 • • GLACIER Area of Review— Redoubt Unit 03A This Area of Review is required in preparation of the RU-03A Injection well. This AOR discusses wells within 1/4 mile of the well's entry point into the Hemlock Formation to the bottom of the planned RU- 03A wellbore completion. Plat of wells within 1/4 mile radius of injection well (Regulation 20 AAC 25.402 (1)): 1J 18 7N/ 13W 2. 19 20 --58 1u�\ ..Rt1-0 Proposed 0.250 mite radius centered on RU-034 1 3 Top Herntock Penetration Point 26 25 30 29 ..1:166116 II c lo-cr 2600 ?CC: Two other wellbores, RU-05A and RU-03, enter the Hemlock formation in this area of review. The table below illustrates the wells within the AOR, annulus integrity/cement conditions based on in-depth review of each well, reservoir status, zonal isolation and mechanical integrity. • • I GLACIER Well Top of Top of To of Top of Top of Cement PTDP Status Hemlock Hemlock p Cement Determined Reservoir Status Zonal Isolation Cement Ops Summary Mechanical Integrity Name (MD) (TVD) Cement(MD) (TVD) by Planned: Planned:4-1/2"liner New 15750' 12000' Planned: 11096' Planned:perfs will be Planned:TOC 14030' Planned:4-1/2"liner- &liner lap Pressure RU-03A TBD Injector MD TVD 14362'MD TVD Planned:CBL open for injection MD(CBL will confirm). 87.9 bbls/Class G test to 3500 psi Planned:P&A for Planned:Retainer at Planned for P&A: 13964'MD Redrill-Retainer at 14385'(20 bbls pumped 7-5/8"-224 sx/Class Zone P&A'd: Shut-in(will (End of CBL) 14385'-20bbls will below retainer). G/no losses Whipstock for 3A @ be P&A for 15859' 12154' (Calc TOC @ 10724' CBL 10-08- be pumped below CBL TOC 12259'MD& 5-1/2"-129 sx/Class 14362'MD/11096' RU-03 2010640 Redrill) MD TVD 12259'MD) TVD 2001 retainer. Retainer at 15691'MD. G/no losses TVD P&A'd for Redrill- Retainer at 12928' 7-5/8"-219 sx/Class CBL 10-14- MD;200'cement on CBL TOC 15820'& Gino losses Zone P&A'd:5-1/2" P&A for 15309' 11971' 12252' 2002&08-25-top of EZSV at Retainer at 12928'MD. 5-1/2"-282 sx/Class liner tested to 3000 RU-05A 2021680 Redrill MD TVD 15820'MD TVD 2013 13550'MD G/no losses psi. As per 20 ACC 25.402 (15): Well RU-03 (Permit 2010640) enters the Hemlock formation at 15859' MD (12154'TVD). The 9-5/8" Intermediate casing was run to 9332' MD and cemented with lead of 72.6 bbls of 12.5ppg Class G cement and tail of 107.8 bbls of 15.8 ppg Class G cement, and bumped the plug with no issues. The 9- 5/8" casing was tested to 3000 psi for 30 minutes prior to drilling out the float equipment. A 7-5/8" casing was run to 15615' MD (top at 9103' MD) and cemented with 46 bbls of 15.8 ppg Class G cement, with no issues noted and bumped the plug. The liner top packer was pressure tested to 2000 psi for 30 minutes.The 7-5/8" liner was tested to 4000 psi for 30 minutes prior to drilling out the float equipment. The 5-1/2" casing was run to 16940' MD (top at 15347' MD) and cemented with 27 bbls of 15.8 ppg Class G cement and bumped the plugs. The liner top packer was pressure tested to 3000 psi for 30 minutes.The 5-1/2" liner was tested to 3000 psi for 30 minutes. A CBL run on 10/8/2001 shows good cement throughout the interval logged, including all of the 5-1/2" liner and a portion of the 7-5/8" liner, with the log stopping at 13970' MD. The calculated top of cement for the 7-5/8" liner is estimated at 12259' MD. Well RU_-05A(Permit 2021680) enters the Hemlock formation at 15309' MD (11971'TVD). While drilling RU-05,the 9-5/8" intermediate casing was set at 13760' MD and cemented with 229.7 bbls of 15.7 ppg Class G cement, with full returns but did not bump the plug. The casing was tested to 3000 psi for 30 minutes prior to drilling the float equipment. RU-05A was then drilled out of the 9-5/8" casing using a whipstock (window: 11473'—11494' MD). A 7-5/8" liner was run to 15323' MD (top at 11290' MD) and cemented with 45 bbls of 15.8ppg Class G cement, with no issues and bumped the plug. The 7-5/8" liner was tested to 3000 psi for 30 minutes prior to drilling out of the float equipment.The CBL ran on 08/23/2013, shows top of cement at 11420' MD.The 5-1/2" liner was run to 17000' MD (top at 15118' MD) and cemented with 56 bbls of 15.8ppg Class G cement and bumped the plug.The liner top packer was pressure tested to 3000 psi for 30 minutes.The 5-1/2" liner was tested to 3000 psi for 30 minutes.A CBL (10/14/2002) confirmed cement behind pipe across the length of the 5-1/2" liner. RU-05A was abandoned for Redrill (RU-05B) in August 2013 with an EZSV at 13550' MD with 200' of cement on top. An additional EZSV was set at 12928' MD (preparation for whipstock). I GLACIER Under A1O 32, RU-03A will be utilized for water injection in the Southern block as approved by the AOGCC. A1O 32 provides additional applicable information in regards to the Hemlock formation and the confinement of the Southern fault block. Under A1O 32,the following conditions will be met as ordered by the AOGCC: Rule 1: RU-03A injection interval correlates to RU-02 in the Southern fault block. Rule 2: RU-03A is being permitted as a service well for water injection in conformance with AOGCC regulations. Rule 3: RU-03A would be utilized for injection of Authorized Fluids as listed in A1O 32. Rule 4: RU-03A Injection pressures will follow the same guidelines as described and limited by A1O 32. Rule 5: RU-03A Tubing and casing annulus pressures will be monitored as described in AIO 32. Rule 6: RU-03A Mechanical Integrity will be monitored and demonstrated as described in A1O 32. Rule 8: Notification of any well integrity failure and confinement to the AOGCC will be provided as described in A1O 32. Rule 9: AOGCC will be notified as per A1O 32 if any improper Class II injection is identified. Rule 10:Any future plan for P&A of RU-03A will be approved as required by AOGCC under AIO 32. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: THE APPLICATION OF FOREST ) Area Injection Order No. 32 OIL CORPORATION for an order ) authorizing the underground ) Redoubt Unit injection of fluids for enhanced oil ) Redoubt Shoal Undefined Oil Pool recovery in the Hemlock Formation, ) Redoubt Shoal Undefined Oil Pool, ) Redoubt Unit, Cook Inlet,Alaska ) January 30,2008 IT APPEARING THAT: 1. By application dated and received by the Alaska Oil and Gas Conservation Commission ("Commission") on July 30, 2007, Forest Oil Corporation ("Forest"), operator of the Redoubt Unit ("RU") requested a Commission order authorizing, under 20 AAC 25.402, the underground injection of fluids for enhanced oil recovery ("EOR") in the Hemlock Formation ("Hemlock") of the Redoubt Shoal Undefined Oil Pool. 2. The Commission published notice of the opportunity for a public hearing in the Anchorage Daily News on August 8, 2007 and in the Peninsula Clarion on August 9, 2007. 3. On August 8, 2007, Commissioner Daniel T. Seamount, Jr. recused himself from this case. 4. By emails dated August 6 and 7, 2007, and September 12, 2007, the Commission requested additional information. Forest responded on August 22, 2007, and September 14, 2007. 5. No comments,protests or requests for a public hearing were received. FINDINGS 1. Operator Forest operates the Redoubt Shoal Undefined Oil Pool in the RU, Cook Inlet, Alaska. f Area Injection Order 324111 Page 2 January 30,2008 2. Project Area and Proposed Enhanced Recovery Injection Interval Enhanced recovery injection is proposed for the Redoubt Shoal Undefined Oil Pool. This pool is compartmentalized by faulting into three fault blocks: the Northern, Central and Southern fault blocks. The Central and Southern fault blocks contain the majority of reserves in the pool. In the Central fault block, the injection zone is correlative with the interval from 14,140' to 14,945' measured depth ("MD") in the RU #1 well. In the Southern fault block, the injection zone is correlative with the interval from 14,365' to 15,222' MD in the RU#2 well. 3. Proposed Injection Area Forest has requested authorization to inject fluids for the purpose of enhanced recovery operations on RU land within TO7N R13W and TO7N R14W, Seward Meridian. Most of the wells affected by the proposed injection activities were drilled from the Osprey Platform, which is located approximately 1.5 miles southeast of West Foreland, offshore Cook Inlet. However, there are also four exploratory wells within the proposed injection area that, between 1967 and 1976, were drilled and then plugged and abandoned. 4. Operators/Surface Owners Notification Forest is the only operator and the State of Alaska is the only surface owner within one-quarter of a mile of the proposed injection area. Forest provided the State a copy of the application for enhanced oil recovery injection. 5. Description of Operation Injection will occur within the Hemlock Formation ("Hemlock"). The Redoubt Shoal Undefined Oil Pool is being developed under statewide regulations. It has not yet been defined in vertical or regional space. There are three active wells in the Central fault block. There is no production from the Southern fault block. Pilot waterflood enhanced recovery operations conducted in the Central fault block were authorized by Enhanced Recovery Injection Order No. 2 in August 2004. During those pilot operations, from March 2005 through September 2007, Forest utilized the RU#6 well to inject 1.3 million barrels of authorized fluids into the Hemlock and recovered 652,000 barrels of oil. The operator plans to progressively expand development within the RU, using new and re-drilled wells from the Osprey platform. However, development options will ultimately be determined by field performance and economic factors. To facilitate reservoir management and field development, surveillance data will be collected on an ongoing basis through static bottom-hole pressure surveys, production logging, injection logging and production well testing. 6. Hydrocarbon Recovery The estimated original oil in place ("OOIP") for the RU is 54 million barrels of oil ("MMBO"): 30 MMBO in the Central fault block and 24 MMBO in the Area Injection Order 32 Page 3 January 30,2008 Southern fault block. Primary recovery from the Hemlock within the RU is expected to be 6% of the OOIP. Results of the pilot project suggest that waterflood operations will increase recovery by an additional 5% to 7% of the OOIP. 7. Geologic Information The Hemlock reservoir within the RU resulted from fluvial deposition in meandering, coalescing stream channels. It consists of interbedded fine-grained to medium-grained sand, gravels, pebble conglomerates, dense silts and scattered thin coal beds. Conventional core analysis indicates that there are at least six lithofacies within the Hemlock. The Redoubt Shoal Undefined Oil Pool accumulated in a northeast-trending anticline that is bound to the west by east-dipping reverse faults. The anticline is transected by several southeast-trending,normal faults. Core data and well logs were used to estimate rock properties. Porosity is intergranular with well-cemented and competent rock. Clay volume ranges from 9% to 20% of rock volume and appears to be dispersed. Reservoir facies consist of pebble conglomerate (porosity 7% to 13%), pebble-gravel sandstone (porosity 10% to 16%), medium-grained to coarse-grained sandstone (porosity 10% to 16%) and fine-grained sandstone (porosity 12% to 14%). Permeability ranges from 0.1 millidarcy to several hundred millidarcies. The oil from the Hemlock at RU has a gravity of approximately 26.5° API, a gas- oil ratio of 250 standard cubic feet per stock tank barrel, and a bubble point pressure of 1,490 pounds per square inch absolute("psia"). Upper confinement will result from an interval of tuffaceous siltstone and coal that lies at the top of the Hemlock. This interval is laterally continuous and ranges in thickness from 40' to 80'. Lower confinement will result from a series of laterally continuous, tuffaceous siltstone and claystone layers that lie at and near the base of the Hemlock. The aggregate thickness of these layers ranges from 40' to 50'. 8. Well Logs The RU well logs are on file with the Commission. 9. Mechanical Integrity and Well Design of Injection Wells The only injection well being used for EOR is RU #6, which has been injecting since March 2005 in accordance with Enhanced Recovery Injection Order 2 ("ERIO 2"). This well was converted from a producer to an injector in accordance with Commission regulations. There is no indication of any mechanical integrity issues with this well. Additional injection wells will be new or re-drilled wells. Area Injection Order 32 Page 4 January 30,2008 • 10. Type of Fluid/Source Fluids requested for injection are the following: a. produced Hemlock RU water; b. treated sanitary waste; c. treated gray water from platform and camp living facilities; d. produced Hemlock water from the West McArthur River Oil Pool; e. storm water from secondary containment areas at the Kustatan Production Facility and the West McArthur River Production Facility; f. deck drainage from the Osprey Platform; and g. produced water from the gas wells in the West Foreland field. 11. Water Compatibility with Formation Injection performance data was collected during the pilot project authorized by ERIO 2. The compatibility information provided in conjunction with the ERIO 2 pilot project is incorporated by reference in this order. 12. Injection Rates and Pressures,Fracture Information Injection rates for the pilot injection project using the RU#6 well range from 700 barrels of water per day to 2,400 barrels of water per day. Injection rates will increase as more production is brought online and more injection wells are added. Injection pressure typically runs between 3,000 psi and 4,600 psi and is limited to 5,000 psi by the pump at the Kustatan Production Facility. The injection rate and pressure history for the RU #6 well indicate that injection is occurring below the fracture pressure of the Hemlock and,more importantly,the confining intervals. 13. Freshwater Exemption Six Hemlock water samples, from 4 wells, were collected and analyzed. The samples were collected from the RU#2,RU#5A, RU#6, and RU#7 wells. Total dissolved solids averaged 11,060 mg/1,with a range of 8,250 mg/1 to 15,800 mg/I. 14. Mechanical Condition of Adjacent Wells The mechanical integrity of each well in the Central fault block was analyzed. These analyses and the review of data gathered associated with ERIO 2 indicate that the mechanical integrity of these wells is acceptable. Injection performance data gathered during the operations authorized under ERIO 2 indicate no well mechanical integrity problems. There are two wells in the Southern fault block, both of which are shut in, and there is no indication of mechanical integrity issues with either well. The Southern fault block wells must be worked-over or side- tracked or new wells must be drilled to begin production and enhanced recovery operations in this fault block. In addition to the above active or shut in wells, five wells (three in the Central fault block, one in the Southern fault block, and one in the Northern fault block, which is outside the proposed project area) penetrate the Hemlock. These wells have been plugged back and are no longer open to the Hemlock, and no integrity issues have been identified with respect to them. Area Injection Order 32 0 Page 5 January 30,2008 CONCLUSIONS 1. The application requirements of 20 AAC 25.402 are met. 2. Water injection will significantly improve recovery. 3. There are no known sources of freshwater in the area proposed for the development of the Redoubt Shoal Undefined Oil Pool. Therefore, a freshwater aquifer exemption is not required. 4. The proposed injection operations will be conducted in permeable strata, which can accept injected fluids at pressures below the fracture pressures of the confining strata. 5. Injected fluids will be confined within the receiving interval by impermeable lithology,cement isolation of the wellbore and operating conditions. 6. Compatibility testing and actual injection performance data obtained during the pilot project authorized by ERIO 2 demonstrate that the proposed injection fluids are compatible with the Hemlock. 7. Reservoir and well surveillance, coupled with regularly scheduled mechanical integrity tests, will help ensure the proper performance of the enhanced oil recovery project and disclose possible abnormalities. 8. The proposed injection fluids are compatible with the native fluids and rock properties of the Hemlock. NOW,THEREFORE,IT IS ORDERED that: The underground injection of fluids for pressure maintenance and enhanced oil recovery is authorized in the Hemlock within the Affected Area, subject to the following rules and the requirements of 20 AAC 25 (to the extent not superseded by these rules). Affected Area: Seward Meridian Township/Range Section Portions T07N R13W 7 SW/4 of SW/4 17 SW/4; SW/4 of NW/4; W/2 of SE/4; SE/4 of SE/4 18 W/2; SE/4; W/2 of NE/4; SE/4 of NE/4 19 All 20 W/2;NE/4; W/2 of SE/4;NE/4 of SE/4 21 W/2 of NW/4;NE/4 of NW/4 29 W/2 of NW/4;NE/4 of NW/4;NW/4 of SW/4 Area Injection Order 32 • • Page 6 • January 30,2008 30 All 31 NW/4;NW/4 of NE/4 TO7N R14W 13 E/2 of NE/4; E/2 of SE/4; SW/4 of SE/4 23 SE/4 of SE/4 24 E/2; SW/4; SE/4 of NW/4 25 All 26 E/2; S W/4; SE/4 of NW/4 34 E/2 of NE/4;NE/4 of SE/4 35 N/2; SE/4; N/2 of SW/4 36 N/2; SW/4;N/2 of SE/4; SW/4 of SE/4 Rule I: Authorized Injection Strata for Enhanced Recovery Authorized fluids may be injected for purposes of pressure maintenance and enhanced recovery within the Redoubt Shoal Undefined Oil Pool into strata that are common to, and correlate with, the interval from 14,140' to 14,945' MD in the RU #1 well in the Central fault block and the interval from 14,365' to 15,222' MD in the RU #2 well in the Southern fault block. Rule 2: Fluid Injection Wells The underground injection of fluids must be through a well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005, or through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280 and 20 AAC 25.412 Rule 3: Authorized Fluids for Enhanced Recovery The following fluids are authorized for injection: a. produced Hemlock RU water; b. treated sanitary waste; c. treated gray water from platform and camp living facilities; d. produced Hemlock water from the West McArthur River Oil Pool; e. storm water from secondary containment areas at the Kustatan Production Facility and the West McArthur River Production Facility; f. deck drainage from the Osprey Platform; and g. produced water from the gas wells in the West Foreland field. Rule 4: Authorized Injection Pressure for Enhanced Recovery a. Injection pressures must be maintained so that injected fluids do not fracture or migrate into the confining strata. b. If injected fluids fracture or migrate into the confining strata, the operator must immediately shut in the injection wells. Injection may not be restarted unless approved by the Commission. Area Injection Order 32 4110 Page 7 January 30,2008 Rule 5: Monitoring Tubing-Casing Annulus Pressure The tubing and casing annuli pressures of each injection well must be monitored at least daily, except if prevented by an extreme weather condition, emergency situation, or similar unavoidable circumstance. The results shall be made available to the Commission upon request. Rule 6: Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. A Commission-witnessed mechanical integrity test must be performed after injection is commenced for the first time in a well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent tests must be performed at least once every four years thereafter. The Commission must be notified at least 24 hours in advance of each mechanical integrity test to enable a Commission representative to witness the test. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure equal to the maximum anticipated injection pressure that shows stabilizing pressure and does not change more than 10 percent during a 30- minute period. The results of all mechanical integrity tests must be provided to the Commission. Rule 8: Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by an injection rate, operating pressure observation, test, survey, log, or other evidence, the Operator shall notify the Commission by the next business day and submit a plan of corrective action (on Form 10-403) for Commission approval. The Operator shall immediately shut in the well if continued operation would be unsafe, would threaten contamination of freshwater, or if so directed by the Commission. Monthly reports of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or a lack of injection zone isolation. Every five years from the effective date of this order, the operator shall analyze the mechanical integrity of all potentially affected wells and provide a report to the Commission. Rule 9: Notification of Improper Class II Injection The injection of fluids other than those listed in Rule 3 without prior Commission authorization is improper Class II injection. Upon discovering any such event, the operator must immediately notify the Commission, provide details of the event, propose actions to prevent a recurrence, and take any other action required by the Commission. Compliance with the notification requirements of any other State or Federal agency remains the operator's responsibility. Rule 10: Plugging and Abandoning Fluid Injection Wells An injection well within the Affected Area must not be plugged and abandoned unless such action is approved by the Commission in accordance with 20 AAC 25. Area Injection Order 32 • Page 8 January 30,2008 Rule 11: Other conditions It is a condition of this authorization that the operator complies with all applicable Commission regulations. The Commission may suspend, revoke, or modify this authorization if any Rule is violated or injected fluids fail or might fail to be confined within the designated injection strata. Rule 12: Administrative Actions Upon application or its own motion, the Commission may, without notice and public hearing (unless such are otherwise required), administratively waive the requirements of any Rule or administratively amend this Order as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles,and will not result in an increased risk of fluid movement out of the designated injection strata or into freshwater. DONE at Anchorage,Alaska,and dated January 31, j 18 os on.ANS , " John . .rman,Chairman 111111/ , .ska Oil and Gas Conservation Commission Cathy P. oerster, Commissioner Alaska I it and Gas Conservation Commission AS 31.05.080 provides that,within 20 days after written notice of the entry of an order, a person affected by the order may file with the Commission an application for reconsideration. To be timely filed,the application must be received by 4:30 p.m. on the 23rd day following the date of the order,or the next working day if the 23rd day is a state holiday or weekend. The Commission shall grant or refuse the application in whole or in part within 10 days after it is filed. The Commission can refuse the application by not acting on it within the 10-day period. A person who submitted an application for reconsideration has 30 days from the date the Commission refused the application or mailed(or otherwise distributed) an order on reconsideration, both being the final order of the Commission,to appeal the decision to Superior Court. Where an application for reconsideration is denied by nonaction of the Commission,the 30-day period for appeal to Superior Court runs from the date on which the application is deemed denied(i.e., 10`"day after the application for reconsideration was filed). • • EXHIBIT A— LANDOWNERS, OWNERS AND OPERATORS Landowner Owner Operator As defined in As defined in As defined in AS 31.05.170 7 AS 31.05.170 10 20 AAC 25.990 46 Le al Descri tion State of Alaska Cook Inlet Cook Inlet ADL 381203 Energy, LLC Energy, LLC T.7N.,R.14W.,SEWARD MERIDIAN,ALASKA SECTION 13,PROTRACTED,ALL,640 ACRES; SECTION 14,PROTRACTED,ALL,640 ACRES; SECTION 23,PROTRACTED,ALL,640 ACRES; SECTION 24,PROTRACTED,ALL,640 ACRES; SECTION 25,PROTRACTED,ALL,640 ACRES; SECTION 26,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 3,840 ACRES MORE OR LESS. State of Alaska Cook Inlet Cook Inlet ADL 374002 Energy, LLC Energy, LLC T.7N.,R.13W.,SEWARD MERIDIAN,ALASKA SECTION 19,PROTRACTED,ALL,615 ACRES; SECTION 20,PROTRACTED,ALL,640 ACRES; SECTION 21,PROTRACTED,ALL,640 ACRES; SECTION 28,PROTRACTED,ALL,640 ACRES; SECTION 29,PROTRACTED,ALL,640 ACRES; SECTION 30,PROTRACTED,ALL,617 ACRES; SECTION 31,PROTRACTED,ALL,619 ACRES; SECTION 32,PROTRACTED,ALL,640 ACRES; SECTION 33,PROTRACTED,ALL,640 ACRES. THIS TRACT CONTAINS 5691 ACRES MORE OR LESS. Contact Information: State of Alaska CERTIFIED MAIL 7015 0920 0002 1701 0089 Department of Natural Resources Alaska Division of Oil and Gas 550 W 7th Avenue, Suite 1100 Anchorage, AK 99503 907-269-8800 Cook Inlet Energy, LLC CERTIFIED MAIL 7015 0920 0002 1701 0096 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 907-334-6745 RECEIVED DEC 2 3 2016 AOGCC • • EXHIBIT B - WELLS WITHIN 'A MILE RADIUS OF PROPOSED OPERATION T. 7 N., R. 14 W., S.M. T. 7 N., R. 13 W., S.M. 19 20 7N/13W 5B 5A4 .. :U 3A%Z mile 29 2{ 27 X53 • 411 EXHIBIT C - NOTICE OF OPERATIONS GLACIER December 23,2016 CERTIFIED MAIL Landowners,Owners and Operators See Distribution List West Foreland Area Cook Inlet Basin,Alaska Re: Notice of Operations under 20 AAC 25.283 of Cook Inlet Energy,LLC's Sundry Application for a Fracture Stimulation for the Proposed RU 3A Sidetrack Well Dear Landowner,Owner and/or Operator, Cook Inlet Energy,LLC,a Glacier Oil and Gas company(GLA)is applying for a Sundry Application under 20 AAC 25.283 to perform a fracture stimulation of the proposed RU 3A sidetrack well.This Notice is being sent by certified mail to meet the notification requirements under 20 AAC 25.283(a)(1XA) and 20 AAC 25.283(a)(1 XB). The complete application is available for review upon request.If you wish to review the application,please contact Tim Jones,Senior Landman,at the following: Tim Jones Senior Landman Glacier Oil and Gas Corp. 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 Direct:907-433-3811 tjones�cr�,glacieroil.com GLA,through a search of the public record,has identified you as a Landowner,Owner or Operator(as defined in AOGCC regulations)within'h mile of the proposed RU 3A sidetrack well trajectory and fracture stimulation. Please contact me should you require additional information. Iti Sin w , i Tim Joii s Senior!: • .n Distribution List:Alaska Division of Oil and Gas Cook Inlet Energy,LLC 601 W 56 Ave.,Suite 310,Anchorage,AK 99501 • Proposed RU 3A•track Well Fracture Stimulation December 23,2016 EXHIBIT D Affidavit State of Alaska, Third Judicial District Personally appeared before me, Timothy Jones,who, being duly sworn according to law, deposes and says: 1. I, Timothy Jones, am a Senior Landman for Cook Inlet Energy, LLC and a Registered Professional Landman#84167. 2. The Landowners, Owners and Operators, as defined in relevant state statutes and regulations, identified in Exhibit A are correct to the best of my knowledge. 3. The well location in Exhibit B was taken from Cook Inlet Energy, LLC's Permit to Drill submitted to AOGCC. 4. The Notice in Exhibit C was sent to the Landowners, Owners and Operators identified in Exhibit A by certified mail. Further the affia`t sayeth naught. 12/23/14 Timothy Jon Date RPL#84167 UNITED STATES OF AMERICA § STATE OF ALASKA § Subscribed and sworn to before me on the day of December,2016. �olrvla h Notary Public Notary Public ROWENA KEHR �O� r� State of Alaska My commission expires: G / My Commission Expires Feb, 14. 2017 LOFT . `�\NI'li ,. THE STATE Alaska Oil and Gas .A�►.. of` L A s KA Conservation Commission 11'14i 333 West Seventh Avenue ' +; `* GOVERNOR BILL WALKER Anchorage.Alaska 99501-3572 Main:907.279.1433 Or ""4 /7c Ai.A6A f Fax: 907.276.7542 !Z www.aogcc.alaska.gov l" L Conrad Perry `- Drilling Manager i1 PitP) Cook Inlet Energy,LLC 601 W. 5t Ave., Suite 310 Anchorage,AK 99501 Re: Redoubt Shoal Field,Undefined Oil Pool,Redoubt Unit#3 _ ,/ 1-3c-1-7 Permit to Drill Number: 201-064 —7-7- • 1 Sundry Number: 316-612 Dear Mr. Perry: 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 uii the 23rd day following the date of this leiter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, all / `fes._. Cathy . Foerster Chair s4' DATED this?4 day of August,2016. • • ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4-StLS 1�(,Z i APPLICATION FOR SUNDRY APPROVALS .. , 6 20 MC 25.280 .- . 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ElChange Approved Program❑ Plug for Redrill D. Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class: '5.Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development 0 201-064 ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK,99501 50-733-20504-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055' Will planned perforations require a spacing exception? Yes❑ No ❑✓ / REDOUBT UNIT#3 9.Property Designation(Lease Number): 10.Held/Pool(s): ADL-381203(surface),ADL-374002(TD) • REDOUBT SHOAL UNDEFINED,UNDEFINED G-0 TYONEK ' 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): 16940' . 13016'• 15691'• • 12035' 3812 psi 14450' N/A Casing Length Size MD TVD Burst Collapse Structural 150' 30" 150' 150' WA N/A Conductor -- -- _ — — — Surface 3507' 133/8" 3507' 3024' 5020 2260 Intermediate 9332' 9 518" 9332' 7416' 6870 4750 Production 6512' 75/8" 15615' 11981' 6890 4790 Liner 2223' 5 1/2" 18940' 13016' 7740 6280 t Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7780-7818'/14803-14880'1 6203-6232'/11410-11450' 2 7/8" 1-80 EUE M 14791' Packers and SSSV Type: 95/8"WF Hvdrow 1:75/8"WF Hydrow 1: IPackers and SSSV MD(ft)and TVD(ft): • 7614'MD/6075'TVD;14700'MD/11:4:46' Halliburton 2 7/8"WL SSSV TVD;287'MD/TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic 0 Development Q. Service 0 14.Estimated Date for 15.Well Status after proposed work: 12/15/2016 0 Suspended ❑ Commencing Operations: OIL 0 WINJ 0 WDSPL 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown J Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Conrad Perry Email Cperry@glacierOil.com Printed Name Title Conrad Perry Drilling Manager Signature V Phone Date 907.727.7404 Date /2./�fi rCir• COMMISSION USE ONLY Conditions of approval: , Corn :Iion so that a representative may witness Sundry Number: Plug Integrity L._, BOP Test 13( Mechanical Integrity Test ❑ Location Clearance ❑ Other: +t- L/000 /05 6I)/a `24 Post Initial Injection MIT Req'd? Yes ❑ No ❑�,/ �/ Spacing Exception Required? Yes ❑ No LtQ Subsequent Form Required: /b 1 D 7 APPROVED BY Approved by:tlie,lCOMMISSIONER AB THE COMMISSION Date: /� —1I--.4 � 7� IP. /.�f/1f7/ Submit Form and Form 10-403 1112015Oi valid for 12 months from the date d approlral, Attachments In Duplicate 1MMM..rrr /g-z1.44.- • • GLACIER November 30th, 2016 Ms. Cathy Foerster, Chair Alaska 011 and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Cook Inlet Energy: Redoubt Unit 03/50-733-20504-00-00 Dear Ms. Foerster, Glacier Oil &Gas hereby submits a completed Application for Sundry Approval, 10-403,for the abandonment of RU-03, PTD: 201-064, located on lease#381203 and#374002,off the Osprey Platform. Attached is the current wellbore schematic, wellhead schematic and post abandonment schematic. Additionally,rig layout,and a BOP confirmation diagram. Rig#35 will be used to complete this work, commencing December 25, 2016. A separate PTO application will be submitted for the sidetrack of this well. If you have any questions, please contact me at 907.727.7404. 3rIy, Conrad Sr. Vice President/Drilling Manager Cook Inlet Energy, LLC(a Glacier Oil&Gas Corp. owned company) 601 W. 5th Avenue STE 310 Anchorage,AK 99501 Q vr. Pet C`'�"�%1 from Coop red 41. I4 we 15- , , (weer C ilr D,ie k r ire adve rt,;h -91' fedi/I�" A "Igfr •`4j(2446\ frodUG p fa"' ,-0 en hail 6e, fds pradlr1°74 i'�� 1 • • GLACIER 1. WELL NAME—RU-03 Requirements of 20 MC 25.005(f) Well Summary Current Status: The well is shut-in with a dual packer completion. Tubing pressure=50 psi Tubing x 9 5/8" annulus=25 psi Scope of Work: o Rig up Rig 35. NU test BOPE. O Pull completion and tubing. O Set 7 5/8" Bridge plug at 14,428' MD and squeeze cement across perforations. • Place 9-5/8"casing patch across upper perforations. • Pressure test casing to 1500 psi for 30 minutes. ® Set whipstock at 14,426'MD and prepare to mill casing. General Well Information: Reservoir Pressure/TVD: 0.433 psi/ft 4,957 psi @ 14,860' MD(11,450'TVD) MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.433 psi/ft X 11,450'TVD)—(0.1 psi/ft X 11,450') =4,957 psi—1,145 psi =3,812 psi Wellhead Type/Pressure Rating: 13 5/8"5M Wellhead-3 1/2"5M tree BOPS: 13 5/8" 10M—Pipe Rams/Blind Rams/Annular/Kill Line TIFL MIT-IA/MIT-OA: TIFL—N/A MIT-IA—N/A MIT-OA—N/A Well Type: Gas Well—Shut-in Estimated Start Date: December 25, 2016 2 • • GLACIER CIE Drilling Manager CIE Sr Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907)433-3808 (907)433-3822 cperry@glacieroil.com sratciiff@glacieroll.com dkumar@glacieroll.com Program Abandonment General Note:There is a 2 7/8"tubing,tandem packer completion currently in the well. Pre-Rig Operations 1. R/U Slickline and Lubricator. 2. Open Sliding Sleeve at 7578' MD. 3. Circulate 8.5 ppg produced water down tubing taking returns to disposal well until well is dead. 4. Close Sliding Sleeve at 7578' MD. 5. RID Slickline. Rig WorkoverS 12;- '3 1. Move rig onto RU-03. 2. Check for pressure and note pressure in tubing and in annulus. o Confirm well is dead. 3. Place back pressure valve in wellhead. 4. Notify AOGCC of start of operations and upcoming BOP Test with 48 hour notice. 5. N/D Production Tree. 6. N/U BOPE. 7. Nipple up and test 13 5/8" BOPE with 2 7/8"X 5"VBR rams with blinds in middle. o Test BOPE on 2 7/8",4"and S"to 250 psi low/4,000 psi high and chart. 8. Remove Back Pressure Valve. 9. P/U Landing Joint and make up to 2-7/8"Tubing Hanger. 10. Check inner annulus for pressure. 11. Leave annulus valve open when pulling hanger. 12.Back out lock down screws in Tubing Hanger. 3 • • GLACIER 13. Pick up and free packers(31000#straight pull to release) o Max Pull not to Exceed 110,000 lbs W/O Weight of Blocks 14. Circulate 8.5 ppg produced water until clean. 15. Check for Flow and confirm well is dead. P - 16. Pull&L/D 2-7/8" Landing Joint and Tubing Hanger. 4405 17. POH and L/D completion. 18. MU mechanical setting tool with 7 5/8"cement retainer. 19. RIH with retainer and PU 4"and 5"drill pipe. 20. Set cement retainer at 14,428' MD. t= Mrc 21. Pick up and tag retainer with 5K to ensure retainer is set. 22.Sting in with weight down as per tool hand instructions,mark down position on rig floor. 23. Rig up and test cementing lines. 24. Establish injection rate with produced water. o Expect+/-5000 psi surface pressure. 'L' 25. Pickup to un-stung p'o tion. 26. Circulate 20 bbls 15.8 ppg cement to within 5 bbis of stinger. 27. Sting in and squeeze 20 bbis of 15.8 ppg cement(slack off to down mark to ensure sufficient weight is down for squeeze. o Leave 2 bbis in stinger. 28. Un-sting and circulate cement out. 29. POH to 13,000'. 30. MU and RIH with 9 5/8"casing scraper BHA to 7,900' MD. 31. POH and L/D Scraper BHA. 32. MU and RIH with 9 5/8"Owens Casing patch per vendor instructions. o Confirm OD and ID's of tools prior to running Casing patch. ri,A 33. RIH with 60'patch from 7770'-7830' MD per vendor instructions. 34. RU Eline and RIH to correlate depths. 35. RD Eline. 36.Set 60'patch per vendor instructions. la/0,V/ 37. POH and LD setting tool. too ty4 38. Pest»r e t casing patch to psi for 30 mins and chart./ cm-r- Ory M-5v 39. Confirm pressure test success and report to CIE Drilling Engineer prior to moving forward. 40. Clean pits and build OBM mud system. 41. MU and RIH with 6%" mill and 7 5/8"casing scraper BHA. 42. RIH with Scraper BHA to 14,425' MD. 43. RU and displace produced water from well with 10.2 ppg OBM. 44. POH and L/D Scraper BHA. 45. MU 6 3" Mill/Whipstock/MWD BHA per Service Company Running Procedure. 46. Orient MWD to starter mill-lie in to high side. 4 . • GLACIER 47.Slowly RIH through BOP&wear bushing to+1- 14,400'MD. o RIH at 1.5 to 2 mins per stand. o Reduce running speed when passing through casing patch from 7,770'—7,830' MD. o Fill every 30 stands. o Do not rotate or work the string unnecessarily. o Highest Doglegs:4.62 @ 2040'MD,4.36 @ 2136'MD 48. Orient and set bottom trip anchor at 14,428' MD. p;0 49. Pull up approximately 2'to set bottom of whipstock window at 14,418' MD. f 4 o Do not lift tool more than 5'. 50. Release mill from the Whipstock per vendor procedure. 51. Circulate mud and establish circulation. 52. Prepare to mill window. Redoubt Unit 03A Sidetrack will be submitted under separate Application for Permit to Drill. V • 5 RU-O Current Completion 12/6/2012 • • I 1 5 SSSV 0 303'MDr 2-718'Halliburton SSSV at al't L 30" A-36 200 MD 150# Welded 200'ND r 51 2-7/8'chemical Injection mandrel 2,500'MD ttil 41 13 3/8" L-80 3,507'MD 68# BTC 3,024'ND 2-718"WXO Sliding Sleeve @ 7,578'MD t I r r 1 x 9-5/8'x 2-7/8"Weatherford Hydrow I I ', hydraulic set packer®7,614'MD f7f 2-718"Sliding Sleeve @ 7,754'MD 2 7/8'8.5#L-80 EUE M Tubing _ tall= Perforations-7780'-7818'MD/ 6,203'-6,232'ND A. :, 1 i 0* Redressed 9-5/8'x 2-7/8'Weatherford Hydrow 1 hydraulic set packer rr 7,854'MD ' TOL @ 9,103'MD - 1 Baker Hanger Assembly ' 9 y �� 9518" L-80 9,332'MD ' A 'liii' -- 47# BTC 7,416'ND I I 4 2-7/8"XN-nipple @ 14,751'MD if1 4 ? r Top Tieback 14,717'MD i WL Re-Entry Guide @ 14,791'MD Perforations-14,803'-14,860'MD/ - 11,410'-11,450'TVD — A • 4 . !1.i i. I Baker Hanger Assembly i�'11 1 75!8' L 80 15,615'MD� M 29.7#I Hydril 5211 11,981'TVD V-vv. Cement Retainer @15,691'MD r a—•• Lost fish @ 16,768'-16,048'MD ` `kms'=' �` i J 11, , 51/2" L-80 18,940'MD I r 17# Hydril 521 13016'TVD • • RU-03 Proposed Abandonment Schematic 11/22/2016 Version-10 - , i Al t fi 30" A-36 200'MD 150# Welded 200'TVD r 133/8" 68#L$0 3,60T MD <fri,4,IP° g"/„..:,-..---.-....--‘----. D 12.415' BTC 3,024'TVD ii • ' Casing Patch-ID 7.75'after setting C0)7,770 7,830'MD , Perforations-7780'-7818'MD/ ~_ 8,203'-6,232'TVD g 4, Z `‘— s-700 1r),, TOL®9,103'MD 9 518" 41#L-80 9,332'MD /� Baker Hanger Assembly " , ID 8.525" BTC 7,418'TVD F dtg i s Whipstock bottom of window @ 14,418'MD , lik: Ilk Cement Retainer @ 14,428'MD '....--"" Top Tieback 614,71T MD b`�� ` k 1,'f. Cement squeeze parts,20 Phis 15.3 ppg Perforations-,4,803'_14,880'MD/ .. ter•;- . n(,(. 3Q - Si 11,410'-11,450'TVD - ti'��`'•it `7 I i *A 1 '\� y ti!` 7 518" 29.7#L-80 15,815'MD Baker Hanger Assembly i f r i ID 6,75' Hydrli 521 11,981'TVD Cement Retainer 15,691'MD Lost fish®15.788'-16,048'MD . :"- i ,✓ '" , ,, f 5 1/2" 17#L-80 18,940'MD CI t D 4.787 Hydril 621 13,016'TVD • • Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Monday,January 30, 2017 2:11 PM To: Schwartz, Guy L(DOA); Stephen Ratcliff Cc: Conrad Perry;Amanda Dial Subject: Re: RU-03A Attachments: RU-03A WI - Frac Schematic.pdf Guy, See my answers below and attached frac schematic. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From: "Schwartz, Guy L(DOA)"<guy.schwartz@alaska.gov> Date: Monday,January 30, 2017 at 2:05 PM To:Stephen Ratcliff<sratcliff@glacieroil.com> Cc:Conrad Perry<..:perry@glacieroil.com>,Amanda Dial<adial@glacieroil.com> Subject: RE: RU-03A Still working on it. The AOR information given was done very well. Thanks. A couple of follow-up questions: 1. Are you going to pre- produce the well for an extended time after fracking and then convert to injection?- No, we are not planning to pre-produce. We will clean up the wellbore of sand but not planning on lifting oil to surface. 2. You are requesting a no flow test on page 12 .... if converting to injection then No flow test not needed. Thank you for catching this. No flow needed when not producing. our mistake. 3. What is your min LOT/FIT value after drilling out of the window ?- We will plan to bring to a full Leak Off for help with frac modeling. I would expect greater than a 13 ppg EMW. 4. Can you provide a well sketch of the frac string completion. (see step 38 in drilling procedure.) See attached. It will be a 4.5" 15.10 P110 Geoconn Liner and Frac String (Identical to RU-07B). Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guv.schwartz ,alaska.gov). 1 • • Schwartz, Guy L (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Thursday,January 05, 2017 8:46 AM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA);Amanda Dial;Conrad Perry Subject: Re: RU- 3A application ( PTD 216-170) Convert to injector AOR Guy, We will review and get back to you with the additional information. Regards, Stephen Ratcliff Glacier Oil and Gas Corporation 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 0-(907)433-3808 C-(907)433-9738 From: "Schwartz, Guy L(DOA)"<guy.schwartz@alaska.gov> Date:Thursday,January 5,2017 at 8:31 AM To:Stephen Ratcliff<sratcliff@glacieroil.com> Cc:"Bettis, Patricia K(DOA)"<patricia.bettis@alaska.gov> Subject: RU-3A application ( PTD 216-170)Convert to injector AOR Stephen, The PTD for RU-3A was totally lacking any documentation needed to convert the well to a water injector after sidetracking. I am attaching several documents to help you assemble the required information under 20 AAC 25.402. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwart4falaska.gov). 1 • Bettis, Patricia K (DOA) From: Stephen Ratcliff <sratcliff@glacieroil.com> Sent: Wednesday, December 28, 2016 4:24 PM To: Bettis, Patricia K(DOA) Cc: Stephen Ratcliff; Conrad Perry;Amanda Dial Subject: Re: RU-3A: Permit to Drill Application (PTD 216-170) Patricia, We are not planning to pre-produce the well. It will be a water flood injector that we plan to frac prior to injecting. There will not be any production from the well. Regards, Stephen Ratcliff On Dec 28, 2016, at 1:53 PM, Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov>wrote: Good afternoon Stephen, Does Cook Inlet Energy plan to pre-produce RU-3A; and if so, for what duration? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907) 793-1238 or patricia.bettis@alaska.gov. 1 S TRANSMITTAL LETTER CHECKLIST WELL NAME: 7(,L, -3A PTD: a 16 - 17-o Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: POOL: i,c l Shcx dA J�.ftl tI // Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 e 0 y , . " ,, ,,. , ,. " ,, m o ,, , , 715 C yj, , O 3 , o,, , , ; c c o. co o o m ai' , o, o , , , 3 3, a. 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