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214-169
• • STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I.suprv:T1 —, ' it1i3 BOPE Test Report for: SOLDOTNA CK UNIT 21C-04 ' Comm Contractor/Rig No.: Moncla 401 1 PTD#: 2141690 - DATE: 5/26/2018 ' Inspector Bob Noble - Insp Source Operator: HILCORP ALASKA LLC Operator Rep: Bartlewski Rig Rep: Freeman Inspector 1 Test Pressures: Type Operation: WRKOV Sundry No: Inspection No: bopRCN180527111931 , - Rams: Annular: Valves: MASP 318-201 Type Test: INIT 250/3000 250/3 000' 250/3000 - 1400Related InspNo: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P - Trip Tank P NA System Pressure 3000 . P Housekeeping: P Pit Level Indicators NA NA ,Pressure After Closure 240.0 P - PTD On Location P Flow Indicator NA NA 200 PSI Attained 31 P - Standing Order Posted P Meth Gas Detector P P , Full Pressure Attained 103 ` P Well Sign _ P . H2S Gas Detector P - P - Blind Switch Covers: All stations P Drl.Rig P - MS Misc NA NA Nitgn. Bottles(avg): 6 na 2000 " P i' Hazard Sec. P ' ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F x Quantity P/F Upper Kelly 0 NA Stripper 0 none NA No. Valves 8 P " Lower Kelly 0 NA ' Annular Preventer 1 - 7 1/16" " P - Manual Chokes 2 P - Ball Type 1 FP ✓ #1 Rams 1 - 2.375" x 3.5" P Hydraulic Chokes 0 NA Inside BOP 1 P #2 Rams 1 - Blinds P CH Misc 0 NA 1 FSV Misc 0 NA #3 Rams __.0 none NA I #4 Rams 0 none NA #5 Rams 0 none NA_ INSIDE REEL VALVES: #6 Rams 0 none NA (Valid for Coil Rigs Only) Choke Ln.Valves 1 2 1/16" - P " Quantity P/F HCR Valves 1 ' 2 1/16" P - Inside Reel Valves 0 NA Kill Line Valves 2 ' 2 1/16" P - Check Valve 0 none NA BOP Misc 0 none NA Number of Failures: 1 V Test Results Test Time 6 Remarks: TIW threads leaked, it was tightened and passed R/T. New crew to Alaska and they were not real jelled yet. SCAMS JUN 0 b2013, vOF T� 1//iy" THE SIC • Alaska Oil and Gas �1, ofA LA S KA Conservation Commission " = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson 18 Operations Manager � Q �Y Z >CJ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 21C-04 Permit to Drill Number: 214-169 Sundry Number: 318-201 Dear Mr. Helgeson: Enclosed is the approved application for the 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, Hollis S. French Chair r? DATED this 23 day of May, 2018. MAS ,+�kt RgDM i ` RECE2VE STATE OF ALASKAy�, a ALASKA OIL AND GAS CONSERVATION COMMISSION W� �� ��� 01-3 5/ 2-3 i 1 APPLICATION FOR SUNDRY APPROVALS A 20 MC 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: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q. 214-169 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20276-02-00 • 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 0Soldotna Creek Unit 21C-04 ` 9.Property Designation(Lease Number): • 10.Field/Pool(s): • FEDA028996/FEDA028997 Swanson River Field/Hemlock Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,090' • 10,806' • 11,874' 10,656' —1,400 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,372' 3,372' 3,130psi 1,580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner 4,290' 4-1/2" 12,088' 10,805' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,365-11,798 10,311 -10,604 2-7/8"&2-3/8" 6.5#&4.7#/L80 7,763 &11,316 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): G-77 Hydraulic Pkr;N/A 11,240'MD/10,227'TVD;N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 21 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: May 26,2018 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(c�hilcorp.Com Contact Phone: 777-8420 Authorized Signature: 0#1,:1 --- Date: iii(v l/� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 )s -2'o I Plug Integrity ❑ BOP Test Mechanical....._Integrity Test ❑ Location Clearance CI Other: �E 3 ow r,.:.. ex, ? 7 Mrl132018 Post Initial Injection MIT Req'd? Yes ❑ No ❑ t./, RW*5 Li Spacing Exception Required? Yes ❑ No El Subsequent Form Required: '0`" I i� t 01XJ3a APPROVED BY ) Approved by: COMMISSIONER THE COMMISSION Date: 5/ ZT7 e_. z'/ d 41Mati Submit Form and 1.; )Form 10-403 Revised 4/2017 Approved applic i r s i, is I2tt n 1s,f um the date of approval. Attachments in Duplicate • • Well Prognosis Well: SCU 21C-04 Jlilcurp Alaska,LI) Date:05/16/2018 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: Gas Lifted Oil Well Leg: N/A Estimated Start Date: May 26, 2018 Rig: Moncla 401,, Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,485 psi @ 10,638' TVD (Based on PBU 2/16/2018) Max. Potential Surface Pressure: — 1,400 psi (Based on gas lift pressure.) Brief Well Summary This well was drilled as a side track of the SCU 44-05 well in November 2014 with the Saxon#169 rig. The new well named SCU 21C-04 was originally perforated in the Hemlock bench 6(H-6) sand in December 2014. The Hemlock bench 1 and 2 sands were perforated in January 2015. In August 2015,the H-1, H-2, and H-6 were re- . perforated, and in February 2016 the H-3 was added. March 11, 2018 the Hemlock Bench 5 was added perforating 11,510—11,550'. This interval proved to be swept and made 100%water. Several attempts have been made to set through tubing plugs over the Hemlock / Bench#5 without success(AOGCC Sundry#318-133 and BLM EC#409478). The purpose of this work/sundry is to pull the tubing,set a CIBP over the Hemlock Bench#5 to shut off the / water,and re-run the tubing string. The well will then be placed back on production. 1 e..c 11JJ 4 �--VU! Rig Procedure: /).t —i.-' 1. MIRU Moncla #401 WO Rig. 2. ND Well head, NU BOP stack and test 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Notify AOGCC and BLM 24 hrs. in advance of BOP test. c. Test VBR rams on 2-7/8"test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pick up on tubing string 15,000#over string weight to release packer. Pull out of well with tubing, racking back the 2-7/8"tubing and laying down the 2-3/8"tubing and spooling up capillary line for re-run. 4. RU E-line. 5. PU 4-1/2" 12.6#CIBP and run in hole to 11,505'. Log on depth and set same. POOH W/e-line. 6. PU bailer. RIH and Dump 5' of cement on top of CIBP (TOC @ 11,500'). RDMO E-line. 7. PU BHA including packer. RIH on tubing (W/dummy valves set in GLM's) plus the capillary line, 10' .6 t pup jt. below packer and WLEG. Set packer at 7,780' (+/-). Pressure test back side to 2,000 psi. on chart for 30 minutes. 8. RU Slickline. Pull plug and change out dummy valves for live valves. 9. Turn well over to production to test. • Well Prognosis Well: SCU 21C-04 Hilcorp Alaska,ID Date:05/16/2018 Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Well Head Diagram—Current/Proposed (Same) 4. BOPE Diagram 5. Rig Flow/Circulating Diagram 6. RWO Change Form 0 SCU 21C_04 Swanson River Held Well SCU 21C-04 Schematic Completion Ran: 12/13/14 HiIcorp Alaska,LLC RKB:171.34'/GL:15334'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 1 Conductor 20" - - - Surf 44' 20 # ai 44' ,, 2 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' Y' 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' i' - 33.7 P-110 BTC 6.765" 6,906' 7,993' 3) )1) 4 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4" R y et 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' Tubing8 4.7 L-80 8RD 1.995" 7,763' 11,316' � CBL TOC 4iY } ill / 4,240' ,p; g 2-3 ','..4 JEWELRY DETAIL 51 fl OD Item ;' 1No. Depth ID 17.83' 2.992" Tubing Hanger,3-1/2"8RD Box x Box 2 19.71' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box COI, 6 3 2,777' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Live Valve) 7798 4 4,978' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Live Valve) 5 6,770' 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Live Valve) eti L ,z 4''= 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD a 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" L 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 i 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 12 11,240 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 12/11/14 9 PERFORATIONTop(TVD) BtmDETAIL(TVD) 10,384' I Date Zone Top(MD) Btm(MD) SPF Ft Phase Comments 10 1/05/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC Titan) V 8/20/15 11365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) ',. 1 1/05/15H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC Titan) 11 8/20/15 11,433' 11,455' 10,356 10,371' 6 22 60 1-9/16"HC(Razor) 2/5/2016 H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) I l I 03/11/18 H-5 11,510' 11,550' 10,408' 10,435' 6 40 60 1-9/16"HC(Razor) 12 12/23/14 H-6 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC Titan) 12/23/14 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC Titan) 13 x 1 14f �S Iz.n nrI k Jt GLV Port Temp @ - H-1 # Size Depth TCF PSC PSO PTRO Description H 2 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 H-3 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1/PPOR-1 4 16 184 0.783 1166 1226 1290 IPOR-1/1P0C-1/PPOR-1 H-5 3 16 194 0,770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt ,1 .. 2 16 199 0,763 1116 1124 1245 IPOR-1/IPOC-11PPOR-1 1 20 200 0.762 ORIFICE-1 RA Mrk Jt,1 111 WELL DATA Tag Fill @ 11,874'SLM , 11-6 1.75"G-ring PTD:214-169 Short RA Marker Joints API: 50-133-20276-02 03/10/2018 @ 11,350'-11,364'MD Lease: FEDA-028996 RA Mrk Jt�`� Tag Fill @ 11,885'KB @ 11,601'-11,615'MD Spud Date:11/22/2014 @ 11,696'-11,710'MD 4-1/2" 1.75"G-ring Tree cxn: 3.5"Bowen r, 12,088' 7/30/2015 @ 11,913'-11,927'MD Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JLL 03-26-18 c vT T 1 �_O� Swanson River Field X71, V 1 Well SCU 2.1C-04 Proposed Schematic Hilcorn Alaska,LLC RKB:171.34'/GL:15334'AMSL CASING DETAIL KB-THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" 1 1 1 Conductor 20" Surf 44' 44' 2 'il Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' - kaf26,4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' _ 33.7 P-110 BTC 6.765" 6,906' 7,993' 31 , Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4" s a+, 3,372' TUBING DETAIL 4 Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC d 4,240' '-,` , t JEWELRY DETAIL ••,k, 6 _ " fc. No. Depth ID OD Item 7 i J ' 1 1 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box . :y 2 19.71' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box TOI 3 2,800' 2.441" 4.750" 2-7/8"SFO-1 GLM#3(Live Valve) 7798 ` 8 _a ,' 4 5,000' 2.441" 4.750" 2-7/8"SFO-1 GLM#2(Live Valve) �' *.1 9 -� 111, 1 5 7,720' 2.441" 4.750" 2-7/8"SFO-1 GLM#1(Live Valve) ,' 6 7,750' 2.441" 4.750" Chemical Injection Mandrel(Optional) a 7 7,780' 2.441" 6.765" Hydraulic Packer(xxk to release) 7-5/8" 4 -;L 8 7,785' 2.313" X-Nipple 7,993' 9 7,795' 2.441" 4" WL Entry Guide 10 ±11,506' - 3.958" CIBP Plug w/10'cement(TOC @ 11,496')XX-XX-XX0. CBL(TOC) 12/11/14 PERFORATION DETAIL 10,384' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 1/05/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) I, 8/20/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) "* 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) H-2 8/20/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) 2/5/2016 H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) 03/11/18 H-5 11,510' 11,550' 10,408' 10,435' 6 40 60 1-9/16"HC(Razor) 12`, 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 12/23/14 H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) RA Mrk Jt H-1 H-2 H-3 15 %1" _ _ H5 RA MrkJt , I. RAMrkJt'' WELL DATA Tag Fill @ 11,874'SLM 1 11-6 1.75"G-ring PTD:214-169 aa• 03/10/2018 Short RA Marker Joints API: 50-133-20276-02 @ 11,350'-11,364'MD Lease: FEDA-028996 RAMrkJt - @ 11,601-11,615'MD Tag Fill @ 11,885' KB @ 11,696'-11,710'MD Spud Date:11/22/2014 4-1/2" !' - 12,088' • ,s 7/30/2015 @ 11,913'-11,927'MD Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by CAH 05-15-18 • H • illwanson River SCU 21C-04 Current >lcko.p Alaska.1.11: 12/08/2014 Swanson River Tubing hanger,Cactus CSX-E-CL, SCU 21C-04 7 X 31/2 EUE 8rd Lift and susp,3" 10%X 7 5/8 X 2 7/8 Type H BPV profile,3/8 control line prep,dovetail body seals BHTA, Bowen,3 1/8 5M FE X 3"Bowen top Valve,swab,WKM-M, '*r 3 1/8 5 M FE,HWO,D D �� e� `<��� ,.k F�`� trim + Ja\ qh. `s \4� �� ��� Valve,Wing,WKM M, 2 1/16 5M FE, HWO, IP,,, : = �,.., ,I* t A DD trim ` �. � I[ ' � (�/ f _ / \ - o o - o u ..I Valve,master,WKM-M, ° 3 1/8 5M FE,HWO,DD W„C i! g ^ r' trim BOO LI, ..I gal Valve,master,WKM-M 1pp- `' 3 1/8 5M FE, HWO,DD ,i-s! , - trim — Adapter,Cactus E CLN `'” 7 1/16 5M stdd X 3 1/8 5M stdd Tbg head,Seaboard,S 8, top,w/'/2 npt control line exit 115M X7 1/16"5M, - "` '" w/2-2 1/16 5M SSO,BG 1 bottom prep,bored out for 7 5/8 casings� ,' - Valve,WKM-M,2 1/16 5M FE, itrci itt,-411) on UO3 1, - 111 2 .I ir Casing head,CIW-WF, 111 11 11 5M X 10'/SOW bottom, w/2-2" LPO viio It • • HILCORP ALASKA 7-1/16" SM BOPE 7-1/16" 5M HYDRIL GK ANNULAR 32"TALL, FLANGE TO FLANGE / \ mien.,ftrw,fft, / 1 7-1/16" 5M LWS DBL GATE BOP 0jDRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM • J , 26-3/4"TALL, FLANGE TO FLANGE 114444T 7-1/16" 5M DRILLING SPOOL ® W/2-1/16" 5M OUTLETS 18"TALL, FLANGE TO FLANGE —77"TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: -3.30 gallon open chamber volume -3.86 gallon close chamber volume GATE STYLE BOP SPECS: - 1.45 gallons to close per gate - 1.18 gallons to open per gate -5.45:1 closing ratio - 1.93:1 opening ratio i • U W i': G w 2O 2 T U co 66 a. E. 0 0 i 0 r 0S3 Y m z H r O 5 LL El 1 10 O D a 0 0 LL a • W • cc o z z u O u z z N LL O z 0 cc.;w O anz pa �cn� N LL ni ]j 2a S 0 I X8CO /� W2 2a ■Q — a) § 2E CDo ■ co 2 � � § ) < a E ® o• ' 2 ins / § 1 CL f ƒ / / ƒ 2 \ eco > _ = ESC // a / 7 CO .L n -0 e ■ ® $ � 2 ta CO a a % / a) T . CO ere 4 / o N Q £ CD I- 0_ t� © 9 _0• / O 0 k U 2C /� k 0 R cs QD CO/ a) . O / J § < _ t a) E § a) o Ca) o ° = o •� L � � / a a) S CZft \ / C as § .� k 2 . m � ■ C C w V 2 / § ■ @ o § � R Q / \ 0 4Ct , x CL % t E 0 _ o R ° a q Q $ x Q vl< 12 C /as § � d � CI en w S / � 0 0 ) .. \ / % / U 2 15 • Q Cuco > /:3 gaC0 /a$ ; 0 U) U) < < < I U) i • xco Barrels of Oil per Month or Barrels of Water per Month o o00 Ln 0 0 0 0 o o 0 0 I o e 0 1 .... 6-rt7 N I �0�r UI 0 N M lLD at M ' v 0 (Q a 1 NI 71,1 Nra' 3 0 ; a a,1 roe o O £ • • V l' i , 1 1\ Y -0 N . 0 l'. c_J i_ _1 oCO ` HI w a O cc n zI 4 4 a ` NCl_vrV m . ■_a ex w Z u 3 • LJJ i 3 • o Os a —I 411:3: m• Q 0 u a1)4 ■ m 9VI N 2 i 3 row Z ¢ • 1:::: v 4,VQ • V• 311i }7 • 0 ...JN 17 a a Q C1 I V) b a rsi ,1 a o ■ Q a S ■ a lbe CL N O ✓ o € J 2 v b o o o0 0 rode, o 0 o o .-1 O 6 6 .-i 0 0 -, o .-1 -7. ogea no-Seg JO gluo j Jad („ADW„) seg}o laaj Dlgn3 puesnogj • • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Tuesday, May 22, 2018 1:35 PM To: Schwartz, Guy L(DOA) Subject: RE: SCU 21C-04 RWO ( PTD 214-169) Guy, The thought is to get away from the 2-3/8"tubulars. The well will flow on its own, especially after the gas flood increases the GOR so the set depth of the packer shouldn't matter. The 2-3/8"tubulars are hurting production. Especially after a little paraffin coats the tubing we are having difficulty getting tools and perf guns down. I hope this helps, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday, May 22,2018 1:16 PM To:Ted Kramer<tkramer@hilcorp.com> Subject:SCU 21C-04 RWO( PTD 214-169) Ted, Reviewing the sundry...what is the reasoning in moving the packer so high uphole from its current depth of 11240 ft. MD (to proposed depth of 7780 ft.) ?? . There would be a substantial loss of drawdown to the formation. 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 Conservatio 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 t you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 • i Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,April 16, 2018 10:17 AM To: 'Ted Kramer' Subject: RE: SCU 21C-04 PTD#214-169, Ted, You have approval to modify the sundry as propose below. There are no issues with moving plug uphole to isolate H-5. Update MOC as required. Guy Schwartz Sr. Petroleum Engineer AOGCC SCANNED 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:Ted Kramer<tkramer@hilcorp.com> Sent: Monday,April 16,2018 10:12 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject:SCU 21C-04 PTD#214-169, Guy, In the above well, after talking to manufacturers of the umbrella plug,the set depth of our umbrella plug in this well has changed. In the Sundry,our set depth was 11,560'. We would like to change that to 11,515'. This will place the umbrella plug in the H-5 perfs. The manufacturer felt that doing it this way would yield better control for the top of the dumped cement. Since we want to keep all of the H-3 perforations. The concern was that the more trips made in the well with cement in dump bailers the increased chance of getting cement stringers strung out into the H-3 perforations. The top of cement will be at 11,495'. Please let me know if you have any issues with this change. We are on the well today so I will be calling you on this. Thanks, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 µ • SCU 21C-04 • TTBP CEMENT ISOLATION PLUG H-3 H-5 PROPOSED l [ -D , 2 / - 4-1/2"-12.6# Perforations I I 11,476' ■ ■ ■ III III H-3 II II ■ I 11,494' 11,495'top > ..K ^r{. Thru-Tubing Bridge Plug(Top-11,502') Proposed Cement Plug ::E: Bridging Material : s 11,510' -■ II III II 11,515'btm > 1U I H-5 ■ IIII ; 11,550' ■ ■ ■ 1 I • ti OF Tit 5w \ I//7„... A THE STATE Alaska Oil and Gas A.41 ofAL (� Conservation Commission KA _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p P Main: 907.279.1433 ALAS"- Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNED Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99501 Re: Swanson River Field, Hemlock Oil Pool, SCU 21C-04 Permit to Drill Number: 214-169 Sundry Number: 318-133 Dear Mr. Helgeson: 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, Hollis S. French fh Chair DATED this Li day of April, 2018. RBDM ApR 0 5 2018 • • b . STATE OF ALASKA MAR 2 7 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION ms`s 3/j APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 ' Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other. Cl 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory El Development El ' 214-169 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage Alaska 99503 50-133-20276-02-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Soldotna Creek Unit 21C-04 • Will planned perforations require a spacing exception? Yes 0 No , 9.Property Designation(Lease Number): 10.Field/Pool(s): • FEDA028996/FEDA028997 Swanson River Field/Hemlock Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,090' • 10,806' • 11,874' 10,656' -1,400 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,372' 3,372' 3,130psi 1,580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner 4,290' 4-1/2" 12,088' 10,805' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,365-11,798 10,311 -10,604 2-7/8"&2-3/8" 6.5#&4.7#/L80 7,763 &11,316 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): G-77 Hydraulic Pkr;N/A 11,240'MD/10,227'ND;N/A 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development(] • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: April 10,2018 OIL 0 e WINJ ❑ WDSPL El Suspended El 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerOhilcorp.com Contact Phone: 777-8420 Authorized Signature: Date: -5/241 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3!$ — 133 Plug Integrity El BOP Test❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes El No ❑ '< .PR Q 5 Mg Spacing Exception Required? Yes ❑ No Subsequent Form Required: RBDM .� APPROVED BY i 1 I` Approved by: COMMISSIONER1QQC1 -- THE COMMISSION Date: // 11( ei )!° ORIGINAL- - - Submit Form and 0s; Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate S • Well Prognosis Well: SCU 21C-04 Hilcorp Alaska,LL) Date:03/26/2018 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: Gas Lifted Oil Well Leg: N/A Estimated Start Date: April 10th, 2016 Rig: E- Line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Ted Kramer (907)777-8420(0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,485 psi @ 10,638' TVD (Based on PBU 2/16/2018) Max. Potential Surface Pressure: — 1,400 psi (Based on gas lift pressure.) Brief Well Summary This well was drilled as a side track of the SCU 44-05 well in November 2014 with the Saxon#169 rig. The new well named SCU 21C-04 was originally perforated in the Hemlock bench 6 (H-6)sand in December 2014. The Hemlock bench 1 and 2 sands were perforated in January 2015. In August 2015,the H-1, H-2, and H-6 were reperforated, and in February 2016 the H-3 was added. March 11, 2018 the Hemlock Bench 5 was added perforating 11,510—11,550'. This interval proved to be swept and made 100%water. —'-- The purpose of this work/sundry is to set a plug below the Hemlock Bench#5 and to cement across it to eliminate the water production from this interval. E-line Procedure: 1. MIRU E-line, PT Lubricator to 2,000 psi Hi 250 Low for 10 min. a. Tree connection is 3.5" Bowen. 2. PU RIH W/Umbrella Plug to 11,560'. Set same and place beads and 5' of cement. WOC 3. PU Dump bailer and place an additional 55'of cement on plug,TOC @ 11,500'.WOC. 4. RD E-line unit. 5. Turn well over to production to test. Attachments: 1. Actual Schematic 2. Proposed Schematic SCU 21C-04 Wellnson nit l SCU 21cr 4 Schemati• c Completion Ran: 12/13/14 Lu:. . RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" " *r1 `s Conductor 20" Surf 44' 44' !7r. 2 111 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 5-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' „,, 3 ILiner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4 ral et 3372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC4 iin 11 Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' 0 JEWELRY DETAIL 1 5 1 No. Depth ID OD Item 6.' 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box 4,t4 i 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7798 " — 4 4,978' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) mak *fi _ 5 6,770' 2.441" 4.750" 2-7/8"5F0-1 GLM#5(Live Valve) a F 7 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 0 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7_5/8" a ,L 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993 .. 7 7a 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) *. 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) r. 8 i 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) M' 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 9 i 10PERFORATION DETAIL 10,384384'' I Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 10 1/05/15 H-1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) ka 8/20/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) 11 '" 8/20/15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) I !�y 2/5/2016 H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) VI 4 I t I 03/11/18 H-5 11,510' 11,550' 10,408' 10,435' 6 40 60 1-9/16"HC(Razor) 12112/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) a tt 12/23/14 H 6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 13 11 4414 T. RAMrkJt GLV Port Temp H-1 # Size Depth TCF PSC PSO PTRO Desoript;on 4 �* H 2 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 ,,, 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 l'tH-3 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1IPPOR-1 4 16 184 0.783 1166 1226 1290 IPOR-111P0C-1/PPOR-1 --H-5 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 Vit' 3' 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt a Ifc]t $� 1 20 200 0.762 ORIFICE-1 RA Mrk Jt0 NII Tag Fill @ 11,874'SLM WELL DATA fo � 03/10/2018, H-6 1.75"G-ring PTD:214-169 Short RA Marker Joints API: 50-133-20276-02 @ 11,350'-11,364'MD Lease: FEDA-028996" x •` @ 11,601'-11,615'MD RA Mrk Jt 1, Tag Fill @ 11,885'KB Spud Date:11/22/2014 k. A '�w ',, @ 11,696'-11,710'MD 4-1/2" . 1.75"G-ring Tree cxn: 3.5"Bowen @ 11,913'-11,927'MD 12,088' `` 7/30/2015 Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JLL 03-26-18 40 SCU 21C-04 Swanson River Unit V Well SCU 21C-04 Completion Ran. 12/13/14 Proposed Schematic Rhear.masks.LLC RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. i 20 x, 1 - Conductor 20" Surf 44' 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' w k Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' +` 33.7 P-110 BTC 6.765" 6,906' 7,993' 3 ffI Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4" r..: 3,372' TUBING DETAIL f Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' CBL TOC',.,..(4 { � 4,240' V: `e 4 '.;t JEWELRY DETAIL No. Depth ID OD Item n®D i1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box , r_, TOI 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7798 — 4 4,978' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) • 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) `. 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD n 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 i 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 i 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15kto release) 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 15 ±11,560' - 3.958" Umbrella^lug w/60'cement(TOC @±11,500') 12/11/14 �t 9 �i 10,384' PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments * 10 p 1/05/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) 8/20/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) 11 $', 8/20 /15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) 2/5/2016 H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) '� I I I 03/11/18 H-5 11,510' 11,550' 10,408' 10,435' 6 40 60 1-9/16"HC(Razor) 12 / 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) ', a, , 12/23/14 H 6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 13 0 1"' RA Mrk Jt 14 1 GLV Port Temp @ ' H-1 # Size Depth TCF PSC PSO PTRO Description 3A. 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 ''. H-2 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 m'-. H-g 5 16 169 0.804 1191 1280 1315 IPOR-1/1POC-1/PPOR-1 " " ,,} _' 4 16 184 0.783 1166 1226 1290 IPOR 1/IPOC-1/PPOR 1 15 ": `_ ' C. H-5 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 RA MrkJt l''— - 2 16 199 0.763 1116 1124 1245 IPOR-1/1POC-11PPOR-1 #, 1 20 200 0.762 ORIFICE-1 RA Mrk Jt Tag Fill @ 11,874'SLM WELL DATA 74 H-6 1.75"G-ring PTD:214-169 Short RA Marker Joints API: 50-133-20276-02 ' 03/10/2018 @ 11,350'-11,364'MD Lease: FEDA-028996 RA Mrk Jt`1 %: Tag Fill @ 11,885' KB @ 11,601'-11,615'MD Spud Date:11/22/2014 y @ 11,696'-11,710'MD 4-1/2" F ..,,,4;n=, , 1.75"G-ring @ 11,913'-11,927'MD Tree cxn: 3.5"Bowen 12,088' • a c. ' 7/30/2015 Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JLL 03-26-18 • STATE OF ALASKA MA:2712 v01 8 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing❑ Operations shutdown ❑ Performed: Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool Cl Repair Well 0 Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 214-169 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service 0 6.API Number: Anchorage,AK 99503 50-133-20276-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996/FEDA028997 Soldotna Creek Unit 21C-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,090 feet Plugs measured N/A feet true vertical 10,806 feet Junk measured N/A feet Effective Depth measured 11,874 feet Packer measured 11,240 feet true vertical 10,656 feet true vertical 10,227 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,372' 3,372' 3,130 psi 1,580 psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020 psi 3,400 psi Liner 4,290' 4-1/2" 12,088' 10,805' 8,430 psi 7,500 psi Perforation depth Measured depth 11,365-11,798 feet 'j ' True Vertical depth 10,311 -10,604 feet 2-7/8" 6.5/L-80 7,763(MD) 7,760(TVD) Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7/L-80 11,316(MD) 10,278(TVD) 11,240(MD) Packers and SSSV(type,measured and true vertical depth) G-77 Hyd Packer 10,227(TVD) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A R ,ioco Treatment descriptions including volumes used and final pressure: RBDM —V,9 N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 94 3744 30 794 270 Subsequent to operation: 12 9 223 1054 194 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory El Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ El WAG ❑ GINJ❑ 3USP❑ 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: 318-090 Authorized Name: Chad Helgeson(907)777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasse@hilcorp.com Authorized Signature: 611/6/ ' . Date: 3/2C.11 E Contact Phone: (907)777-8354 Form 10-404 Revised 4/2017 Submit Original Only • • S�TV T 21C-04 ��_O� Swanson River Unit Well SCU 21C-04 Schematic Completion Ran: 12/13/14 Hilcory Alaska,LLC RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20 .'; 1 Conductor 20" - - - - Surf 44' 44' "". 2 MR Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' '! . ri 26.4 N-80 BTC 6.969" Surf 3,798' Production 7-5/8" 29.7 N-80 BTC 6.875" 3,798' 5,733' :*' 33.7 S-95 BTC 6.765" 5,733' 6,906' Cr` 33.7 P-110 BTC 6.765" 6,906' 7,993' `.10-3/4 -' 3 e, Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 3,372' A TUBING DETAIL 3,372' Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' CBL IOC ' ;', 4 4,240' 010 ,* JEWELRY DETAIL Ra. No. Depth ID OD Item 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box • J + a 2 19.71' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box TOLt, + 3 2,777' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Live Valve) 7'798 4 4,978' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) _ w- 1 5 6,770' 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Live Valve) @h x,"� 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 0 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 i 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) I 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) ' 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 9 12/11/14 PERFORATION DETAIL 10,384' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments ", 1/05/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) 10 8/20/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) 11 I ,.. ' 8/20/15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) s 2/5/2016 H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) I t I 03/11/18 H-5 11,510' 11,550' 10,408' 10,435' 6 40 60 1-9/16"HC(Razor) 12 ' - r 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 12/23/14 H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) ;�, 13 Et 14 `' RA MrkJt . '.• GLV Port Temp @ R, X H_1 # Size Depth TCF PSC PSO PTRO Description H-2 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-11PPOR-1 p46 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 ' H-3 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-11PPOR-1 4 16 184 0.783 1166 1226 1290 IPOR-1/IPOC-11PPOR-1 a H-5 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt' '' 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 1 20 200 0.762 ORIFICE-1 RA Mrk Jr i 4. WELL DATA 4 , Tag Fill @ 11,874'SLM $;1 H-6 1.75"G-ring Short RA Marker Joints PTD:214-169 4a` 03/10/2018 API: 50-133-20276-02 » F @ 11,350'-11,364'MD Lease: FEDA-028996 RA Mrk Jt "V @ 11,601'-11,615'MD , ; Tag Fill @ 11,885'KB @ 11,696'-11,710'MD Spud Date:11/22/2014 4-1/2" 1.75"G-ring @ 11,913'-11,927'MD Tree cxn: 3.5"Bowen 12,088' 7/30/2015 Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JLL 03-26-18 • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 21C-04 E-Line 50-133-20276-02 214-169 3/10/18 3/11/18 03/10/2018-Saturday Arrive SR meet w/ Bruce TGSM JSA permit. Start warm equipment drive to location. Rig up slickline. Stand by for production to fix tri-plex for PT. PT lub to 2,000psi,good. RIH w/2 7/8" scratcher to 2500' KB no obstructions pooh. RIH w/2 7/8" helix cutter to 2500' KB no obstruction POOH. RIH w/ 1.75" G-ring w/TTL to 9,250' KB sit w/tool falling 15-20 ft every time beating down to 9,400' have production shut in well continue to 10,250' KB w/tool. Fell, continue to 11,380' KB tag tubing tail continue to 11,874' KB tag fill. POOH. RIH w/ 1-11/16"x 20' dummy gun to 11,874' KB tag no obstruction. POOH. Rig down slickline move to SCU 12B-09. 03/11/2018-Sunday Sign in. Mobe to location. PTW and JSA.Spot equipment and rig up Halliburton Lubricator. Shut well in. Pressure test to 250 psi low and 2,000 psi high. RIH w/ 1-9/16" x 20' Razor HC, 6 spf, 60 deg phase and tie into Pollard CBL dated 11-Dec- 14. Ran correlation log and send to town. Get ok to perf from 11,530' to 11,550'. GR/CCL to top shot was 7.7' which put stop depth at 11,522.3'. Spotted and fired gun from 11,530' to 11,550' with 1,010 psi on tubing. Saw no pressure change after 15 min. POOH all shots fired. RIH w/ 1-9/16" x 20' Razor HC, 6 spf, 60 deg phase and tie into Pollard CBL dated 11- Dec-14. Get ok to tie in log and send correlation log in later. Ran correlation log. GR/CCL to top shot was 7.7' which put stop depth at 11,502.3'. Spotted and fired gun from 11,510'to 11,530' with 1,010 psi on tubing. Saw no pressure change after 15 min. POOH all shots fired. Rig down lubricator and turn well over to field. %,OF Ty • • • 40*,,���yy,� A THE STATE Alaska Oil and Gas F , � , of/\ T /\ cI /� Conservation Commission 111�I1�7 x,1-1 rz 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "ti Main: 907.279.1433 OF ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 E Anchorage,AK 99503 Re: Swanson River Field,Hemlock Oil Pool, SCU 21C-04 Permit to Drill Number: 214-169 Sundry Number: 318-090 Dear Mr. Helgeson: 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, Hollis S. French 4"' Chair DATED this day of March, 2018. R'�' `'"`" �," ti . N '7 _C18 • • RECEIVED STATE OF ALASKA MAR 01 201 ALASKA OIL AND GAS CONSERVATION COMMISSION or 3 -3 (t/!8' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑✓ • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development Q. 214-169 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20276-02 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)21C-04 ❑ Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996;FEDA028997 • Swanson River/Hemlock 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): 12,090' • 10,806' ' 11,165' 10,719' 1,400 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,372' 3,372' 3,130psi 1,580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner 4,290' 4-1/2" 12,088' 10,805' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8"&2-3/8" 6.5#&4.7#/L80 7,763 &11,316 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): G-77 Hydraulic Pkr;N/A 11,240'MD/10,227'TVD; N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: March 15,2018 OIL ❑./ • WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 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: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasse@hilcorp.com � Contact Phone: 777-8354 Authorized Signature: G% Date: 3/(/1? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: RETs'.st, ....� 2018 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 0r Subsequent Form Required: /0._ f 0 il APPROVED BY I1,e, Approved by: COMMISSIONER THE COMMISSION Date: i 3_5.1. Submit Form and Form 10-403 Revised 4/2017 ! Approved applic ti Rlie 12 +A n the date of approval. _! ttachme�nkts in Duplicate • • S • Well Prognosis Well: SCU 21C-04 Hilcorp Alaska,LL) Date:03/01/2018 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: Gas Lifted Oil Well Leg: N/A Estimated Start Date: March 15th, 2016 Rig: E- Line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Taylor Nasse (907)777-8354(0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,485 psi @ 10,638' TVD (Based on PBU 2/16/2018) Max. Potential Surface Pressure: — 1,400 psi (Based on gas lift pressure.) Brief Well Summary This well was drilled as a side track of the SCU 44-05 well in November 2014 with the Saxon #169 rig. The new well named SCU 21C-04 was originally perforated in the Hemlock bench 6(H-6) sand in December 2014. The Hemlock bench 1 and 2 sands were perforated in January 2015. In August 2015,the H-1, H-2, and H-6 were reperforated, and in February 2016 the H-3 was added. The purpose of this work/sundry is to add perforations in the H-5 intervals of this well. • E-line Procedure: irk" 1. MIRU E-line, PT Lubricator to 2,000 psi Hi 250 Low for 10min. a. Tree connection is 3.5" Bowen. 2. RU 1.75" GR Assembly. RIH and tag bottom. Clean out paraffin with Slickline if present. POOH. 3. RU 1-9/16" (or 1-11/16")wireline guns (hollow carrier or strip guns). 4. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Hemlock H-5 11,510' 11,562' 52 6 a. Proposed perf interval shown on the proposed schematic. b. Final perfs tie-in sheet will be provided to the field for exact perf intervals. c. Correlate using Cement Bond Log(pending Tie-in log). d. Use Gamma/CCL to correlate. e. All perforations in table above are located in the Hemlock Pool based on Conservation • Order No. 1236 Rule 5. 5. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic II Swnson SCU 21C-04 Weal) SCU 2l1C-0 nit Schematic Completion Ran: 12/13/14 Hiicoru Alaska,LLC RKB:17134'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" 1 i Conductor 20" - - - - Surf 44' 44' 2 MB Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' St it' 26.4 N-80 BTC 6.969" Surf 3,798' .k- Production 7_5/8" 29.7 N-80 BTC 6.875" 3,798' 5,733' 4 I 0 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' .±A 3 I Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4I. .,'''41 I ell 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC 4 alt P Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' 0 VitJEWELRY DETAIL l No. Depth ID OD Item WI 5 Mt i 11 17.83' 2.992" Tubing Hanger,3-1/2"8RD Box x Box 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL I!"'• 6 al '„ 3 2,777' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Live Valve) 7,798 ,' - I — 4 4,978' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) s 21 r i 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) F. . 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD Q 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" r. h. 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' '/ 7 i 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) ' ; I 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) " 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) t' 8 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) .! 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) +, 10384' PERFORATION DETAIL 10,384' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments + 10 1/05/15 H 1 11,365' • 11,400' 10,311' 10,334' 6 35 60 1-11/16"NC(Titan) 8/20/15 11,365' ' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) 4' 11 8/20/15 H 2 11,433' • 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) ■ 2/5/2016 H-3 11,476' • 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) 4 I ' I I 104 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 12, 1- t H-6 t It 1 12/23/14 11,794' • 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) „ f a t 13 a' r GLV Port Temp @ 14 # Size Depth TCF PSC PSO PTRO Description RA Mrk Jt w H-1 tl I 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 t 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 5 16 169 0.804 1191 1280 1315 IPOR-1/1P0C-1/PPOR-1 11-2 4 16 184 0.783 1166 1226 1290 IPOR-1/1P0C-1/PPOR-1 it' -% - 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 4 H-3 V. 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt5'' 1 20 200 0.762 ORIFICE-1 't RAMrkJt „ [ WELL DATA i , cee H-6PTD:214-169 1 ,, Short RA Marker Joints API: 50-133-20276-02 sk Tag Fill @ 11,885' KB @ 11,350'-11,364'MD Lease: FEDA-028996 RAMrkJt ' @ 11,601'-11,615'MD Spud Date:11/22/2014 , 1 - . 1.75"G-ring @ 11,696'-11,710'MD 5" 7/30/2015 Tree cxn: 3. Bowen 4-1/2" tt�.,,,r. :tt '. @ 11,913'-11,927'MD 12,088' Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JEK 2/27/2016 • • H SCU 21C-04 Wellll SCU 211 C-0 nit Proposed Schematic Completion Ran: 12/13/14 HiIcoru Alaska,LLC RKB:171.34'/GL:15334'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20„ f ,,' 1 ., Conductor 20" - - - - Surf 44' 44' . 2 ,4 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 5 95 BTC 6.765" 5,733' 6,906' 4. 33.7 P-110 BTC 6.765" 6,906' 7,993' 3 -" Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4" - 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' tt' Tubing2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' ‘i , CBL TOC 4 1' 4,240' 1., JEWELRY DETAIL : frg No. Depth ID OD Item 5 OR it i` 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box d 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7'7981. 4 4,978' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Live Valve) end _t : 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) eft 1' . .', 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 0 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" ,,. 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' l 7 d 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) t10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) I ') 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) ' ; r 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) t 4 8 1 ,1# iv , 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 1: 12/11/149 PERFORATION DETAIL 10,384' I Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 10 i 1/05/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) 8/20/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) rl' 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) ,s' 11 •1; 8/20/15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) * I♦ 2/5/2016 H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) ), I I I Proposed H-5 ±11,510' • ±11,562' ±10,408' ±10,443' 52 12''x',_` ' m 12/23/14 H-6 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) , M 12/23/14 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 13 ® 1 14 RA MrkJt t r, GLV Port Temp @ H-1 # Size Depth TCF PSC PSO PTRO Description 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 V,' 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 X- 1-1-2 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1/PPOR-1 ,: = H-3 4 16 184 0.783 1166 1226 1290 IPOR-1/1P0C-1lPPOR-1 l< - 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 RA MrkJt t• 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 H-5 1 20 200 0.762 ORIFICE-1 RA Mrk Jt t WELL DATA j,, H-6 PTD:214-169 il Short RA Marker Joints API: 50-133-20276-02 `` 11,350'-11,364'MD .0 Tag Fill @ 11,885'KB @ Lease: FEDA-028996 RAMrkJt,; `'I„ 11601'-11615'MD �, 1.75"G-ring @ Spud Date:11/22/2014 7/30/2015 @ 11,696'-11,710'MD 4-1/2" ,'. @ 11,913'-11,927'MD Tree cxn: 3.5"Bowen 12,088' Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by DMA 03-01-18 214169 Itth Nolan Hilcorp Alaska, 2 6 8 7 6 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Harmi,tI4u.kr.Ii' Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED /w/2014, DATE 03/04/2016 K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVED DATA T RA N SM ITTA 4AR 0 8 2016 SCU 21C-04 AOGCG Perforation Record print and data Prints: Perforation Record CD1: digital data SCU_21C-04_PERF_05FEB16 2/12/2016 3:27 PM PDF Document 509 KB SCU 21C-04 PERF 05FEB16 CORRELATI... 2/'12/20163:27 PM LAS File 93 KB SCU 21C-04 PERF 05FEB16 img 2/12/2016 3:31 PM TIFF File 1,229 KB SCU 21C-04 PERF 05FEB16 SHOOTING ,., 2/12,12016 3:27 PM LAS File 60 KB Please include current contact information if different from above. �`�NNE� App 0 42.Q16 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received Aalty ✓ Date: • 214169 II Seth Nolan Hilcorp Alaska, CSC 2 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Hilrnrp tlu.k.i. 1,1 I Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED Si>>2o14 M K.BENDER DATE 01/20/16REGE1V ED To: Alaska Oil & Gas Conservation Commission PA4R 8 201 Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 AOGOC Anchorage, AK 99501 DATA TRANSMITTAL SCU 21C-04 Elog prints and digital data SCAN,*IEV APR A Prints: v 4 2016 RST/GR/CCL Sector Radial Bond Log with Gamma Ray CD1: Elog digital data 5013312027602_SCU-21C-04_RST_Dec_30„, 1/"14/20151:39 PM TIF File 2„087 KB Hilcorp_SCU21C-04_RST_Dec_30_2014 1/8/2015 12:45 PM DLIS File 14,032 KB Hilcorp_SCU21C-04_RST_Dec_30_2014 1/8/2015 12:43 PM LAS File 630 KB LI Hilcorp_SCU21C-04_RST_Dec_30_2014 1/12/2015117 PM PDF Document 282 KB _ SCU 21C-04 4,5IN CBL 11-DEC-14 12/11/2014 4:14 PM LAS File 3,262 KB irA SCU 21C-04 4.5IN CBL 11-DEC-14 12/11/2014 4:14 PM PDF Document 3,,213 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returnin6g one copy of this transmittal or FAX to 907 777.8337 Received By �✓d� <../, V��`L�% bate: V car'( STATE OF ALASKA RECEIVED ALL OIL AND GAS CONSERVATION COMOISION MAR 0 1 2016 REPORT OF SUNDRY WELL OPERATIONS . . 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown A Performed: Suspend ❑ Perforate ❑✓ Other Stimulate [111 Alter Casing ] Change Approved Program L Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Reperf 0 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 214-169 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20276-02 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996,FEDA028997 Soldotna Creek Unit(SCU)21C-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 12,090 feet Plugs measured N/A feet true vertical 10,806 feet Junk measured N/A feet Effective Depth measured 11,990 feet Packer measured 11,240 feet true vertical 10,736 feet true vertical 10,227 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130 psi 1,580 psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020 psi 3,400 psi Liner Perforation depth Measured depth See Attached Schematic SCEANNED APR 0 5 2016 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8"&2-3/8" 6.5#&4.7#/L-80 7,763'&11,316'MD 7,760'&10,278'TVD G-77 Hydraulic Pkr; 11,240'MD 10,227'TVD Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 112 226 0 640 185 Subsequent to operation: 130 296 25 610 160 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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: 316-061 Contact Joe Kaiser-777-8393 Email jkaiser(a�hilcorp.com Printed Name Chad Helgeson Title Operations Manager i + r Signature C / r '` Phone 907-777-8405 Date /k / 1 Cs Form 10-404 Revised 5/2015 114— 3,417/‘' RBDMS 1,� MAR 0 2 2016 Submit Original Only ,�IJY-� • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 21C-04 E-Line 50-133-20276-02 214-169 2/5/16 2/5/16 Daily Operations: 02/05/2016- Friday Meet at office. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. Pressure test lubricator to 250 psi low and 2,000 psi high. Wait on perf gun to arrive.Arm gun. Shut well in. RIH w/ 1-9/16" x 18' Razor HC, 6 spf, 60 deg phase perf gun and tie into Pollard CBL log dated 11-Dec-14. Run correlation log from 11,580' to 11,210' and send to town. Get ok to perf from 11,476' to 11,494' (H-3 sand). Fired gun with 860 psi on tubing and went to 880 psi after 5 min. POOH, all shots fired. Rig down lubricator and turn well over to field. ' SCU 21C-04 WeSwansonllSCU River21C-04 Unit Schematic Completion Ran: 12/13/14 Hilcorp Alaska,LLC, RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. Z +� Conductor 20" - - - - Surf 44' 20" 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' " «k 26.4 N-80 BTC 6.969" Surf 3,798' I. Ir 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 5-95 BTC 6.765" _ 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' Z.) 3) ;;IJ Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 3, 3372TUBING DETAIL ,372' Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC 41 h) 14 Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' ,+t ,,,.44 JEWELRY DETAIL No. Depth ID OD Item 5 I 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box Il 2 19.71' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7,798' r i"" 4 4,978' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) 5 6,770' 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Live Valve) Ua u 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 i 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple T 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 12/11/14 9 10,384' Irk PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 1/05/15 11,365' 11,400' 10,311' 10,334' 6 _ 35 60 1-11/16"HC(Titan) F' 10 ii:' 8/20/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) il aw,l 1/05/15 H-2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) 11 8/20/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) '+r 2/5/2016 • H-3 11,476' 11,494'✓ 10,385' 10,397' 6 18 60 1-9/16"HC(Razor) r I I I V 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 121"y ',_ i 12/23/14 H 6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 13 X 14 — ill:4 GLV Port Temp @ RAMrkJt 1. '4 # Size Depth TCF PSC PSO PTRO Description IV H-1 7 16 122 0.878 1241 1400' 1385 IPOR-1/IPOC-1/PPOR-1 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 _a_._, 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1/PPOR-1 H-2 t 4 16 184 0.783 1166 1226 1290 IPOR-1/IPOC-1/PPOR-1 -�-'— 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 11-3 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 RAMrkJt 1 [•!' 1 20 200 0.762 ORIFICE-1 RA kirk Jt ' V WELL DATA I-6 PTD:214-169 1Short RA Marker Joints API: 50-133-20276-02 bt.° @ 11,350'-11,364'MD RAMrkJt %� [ Tag Fill @ 11,885'KB 11,601'-11,615'MD Lease: FEDA-028996 1.75"G-ring @ Spud Date:11/22/2014 7/30/2015 @ 11,696%11,710'MD t y;, @ 11,913'-11,927'MD Tree cxn: 3.5"Bowen 2,088' ' Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JEK 2/27/2016 • oF 2.04 - tCo J A4 ,\\I%%- .SA THE STATE Alaska Oil and Gas 4`' of T Jj\ SJKj\ Conservation Commission � z _= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Op, Main: 907.279.1433 ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson i ,ANNEO FEB 1 6 2015 Operations Manager Hilcorp Alaska, LLC ca. 114 - 1 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 21C-04 Permit to Drill Number: 214-169 Sundry Number: 316-061 Dear Mr. Helgeson: 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 this3 day of February, 2016. RBDMS L'- FrqII 4 MO il r RECEIVED STATE OF ALASKA JAN 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION , S .213/14 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ 'erforate 0~ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Pertorate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dnll Number: Hilcorp Alaska,LLC _ Exploratory ❑ Development ❑ 214-169 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El 6.API Number. Anchorage,Alaska 99503 50-133-20276-02 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)21C-04 Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996r f t'A U"1. W J A../.,,(4' Swanson River/Hemlock 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): 12,090' - 10,806' - 11,190', ( 10,736' 1,400' WA N/A Casing Length Size' L"If" MD TVD / Burst - Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130psi 1,580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8"&2-3/8" 6.5#&4.7#/L80 7,763 &11,316 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): G-77 Hydraulic Pkr;N/A 11,240'MD/10,227'TVD;N/A 12.Attachments: Proposal Summary ❑I Wellbore schematic ❑I 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development p - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingOperations: February 15,2016 OILWINJ 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 Joe Kaiser-777-8393 Email ikaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature (/ 4i—G Phone 907-777-8405 Date (/7-'1/I Co 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 ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No LTJ' Subsequent Form Required: / 0 Z' 0 1 APPROVED BY Approved by: � �4�. COMMISSIONER THE COMMISSION Date: Z •3-7`j ORIG31pNA.f .2 `l fL' Submit Form and Form 10-403 Revised 11/2015 alid for 12 1lronths from the date of approval. Attachments in Duplicate RDDMIS 0- FEB 0 4 2016 -_f e z 6 • 4110 Well Prognosis Well: SCU 21C-04 Hileorp Alaska,LL Date:01/29/2016 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: Gas Lifted Oil Well Leg: N/A Estimated Start Date: February 15th, 2016 Rig: E- Line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,197 psi @ 10,600' TVD (Based on PT survey 1/6/2016) Max. Potential Surface Pressure: — 1,400 psi (Based on gas lift pressure.) Brief Well Summary This well was drilled as a side track of the SCU 44-05 well in November 2014 with the Saxon#169 rig. The new well named SCU 21C-04 was originally perforated in the Hemlock bench 6 (H-6) sand in December 2014. The Hemlock bench 1 and 2 sands were perforated in January 2015. In August 2015,the H-1, H-2, and H-6 were reperforated. The purpose of this work/sundry is to perform the reperforations H-3 intervals of this well. E-line Procedure: 1. MIRU E-line, PT Lubricator to 2,000 psi Hi 250 Low for 10min. a. Tree connection is 3.5" Bowen. 2. RU 1.75" GR Assembly. RIH and tag bottom. Clean out paraffin with Slickline if present. POOH. 3. RU 1-9/16" (or 1-11/16")wireline guns (hollow carrier or strip guns). 4. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Hemlock H-3 11,476' 11,494' 18 6 a. Proposed perf interval shown on the proposed schematic. b. Final perfs tie-in sheet will be provided to the field for exact perf intervals. c. Correlate using Cement Bond Log (pending Tie-in log). d. Use Gamma/CCL to correlate. e. All perforations in table above are located in the Hemlock Pool based on Conservation Order No. 123B Rule 5. 5. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • ! II SCU 210-04 Swanson River Unit Well SCU 21C-04 Schematic Completion Ran: 12/13/14 Hilcorp Alaska,LLC. RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" AA1 : Conductor 20" - - - - Surf 44' 44' 4.1 2 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' ,� 26.4 N-80 BTC 6.969" Surf 3,798' k;j Production 7.5/8, 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 3 i Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' , 3372TUBING DETAIL 3,372' Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC4 i 4,,,:' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' liAl 4,240' kPA' JEWELRY DETAIL No. Depth ID OD Item m 5 1 1 17.83' 2.992" Tubing Hanger,3-1/2"8RD Box x Box 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL "". 6 ,.; 3 2,777' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Live Valve) 7,798 `, [ 4 4,978' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) }� 5 6,770' 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Live Valve) @) ,;"ir r L, 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 0 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 1' 7 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) r° 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) &L d. 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) , 8 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) =` 13 11,283' 1.875" 3.063" X-Nipple 4 14 11,316' 1.995" 3.063" WL Entry Guide ,.CBL(TOC) #••t4 12/11/14 'T ' PERFORATION DETAIL 10,384' 4, ,'s Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 1/05/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) 10 . 8/20/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) c 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) x11 8/20/15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) 4' c 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) s=' 4.:' 12/23/14 H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 12'x` '• 1 ` - - 11 A Sof 4 13 144 14 GLV Port Temp RA Mrk Jt # Size Depth TCF PSC PSO PTRO Descr!pt;en H-1 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 6 16 148 0.835 1216 1341 1345 IPOR-1/1P0C-1/PPOR-1 ' 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1/PPOR-1 4 H-2 4 16 184 0.783 1166 1226 1290 IPOR-1/IPOC-1/PPOR-1 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 .: 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt vo k 1 20 200 0.762 ORIFICE-1 ft RA Mrk Jt R WELL DATA PTD:214-169 r4 H-6 Short RA Marker Joints API: 50-133-20276-02 Tag Fill @ 11,885'KB @ 11,350'-11,364'MD Lease: FEDA-028996 RA Mrk Jt' 1.75"G-ring @ 11,601'-11,615'MD Spud Date:11/22/2014 1�1!!, '44'f* u @ 11,696'-11,710'MD 4-1/2" r T 7/30/2015 Tree cxn: 3.5"Bowen 12 088 @ 11,913'-11,927 MD Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' SCU 21C-04 Schematic 8-21-15 Updated by DMA 09-01-15 • • SCU21C-04 Swanson River Unit V Well SCU 21C-04 Proposed Schematic Completion Ran: 12/13/14 Hikora Alaska.LL(: RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" 1ii Conductor 20" Surf 44' 44' 2 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 4 26.4 N-80 _ BTC 6.969" Surf 3,798' r 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 31- Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' , : 3372TUBING DETAIL 3,372' Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC"*A 41 4Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' kktl P* JEWELRY DETAIL ``" N . o. Depth ID OD Item 5 r 1 17.83' 2.992" Tubing Hanger,3-1/2"8RD Box x Box a ' sr . f 2 19.71' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 A3 2,777' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Live Valve) 7798' ?a* 4 4,978' 2.441" _ 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) i r V, A "1 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) @fit 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD a 7 8,152' 1.990" _ 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 ,• 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 V 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple btl' 14 11,316' 1.995" 3.063" WL Entry Guide CBL { 12/11/14(TOC) 9 '; PERFORATION DETAIL 10,384' ', Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 0 10 , 1/05/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) 8/20/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) I " 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) 11 8/20/15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) (4: H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 Proposed nI , I 12/23/14 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 12x, _ 12/23/14 H 6 1 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 1 13 X 43 14 _ GLV Port Temp @ RAMrkJt 't # Size Depth TCF PSC PSO PTRO Description H_1 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1/PPOR-1 6 16 148 0.835 1216 1341 1345 IPOR-1/1P0C-1/PPOR-1 5 16 169 0.804 1191 1280 1315 IPOR-1/1P0C-1/PPOR-1 i 11-2 4 16 184 0.783 1166 1226 1290 IPOR-1/IPOC-11PPOR-1 `' 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 '.« H-34 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt 1.,11 1 20 200 0.762 ORIFICE-1 1 P Ii RA Mrk Jt, Ji WELL DATA �o J 11-6 PTD:214-169 Short RA Marker Joints API: 50-133-20276-02 "d` Tag Fill @ 11,885'KB @ 11,350'-11,364'MD Lease: FEDA-028996 RA MrkJt • 11,601'-11,615'MD 1.75"G-ring 17 696'11,710'MD Spud Date:11/22/2014 + 7/30/2015 Tree cxn: 3.5"Bowen 12,088' .• ,.*", @ 11,913'-11,927'MD lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' Updated by JEK 1-29-2016 STATE OF ALASKA AIDA OIL AND GAS CONSERVATION COMI ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate Li Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Reperf 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑.r Exploratory ❑ 214-169 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 " 50-133-20276-02 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028996,FEDA028997— • Soldotna Creek Unit(SCU)21C-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A • Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 12,090 feet Plugs measured N/A fRECEIVED true vertical • 10,806 feet Junk measured N/A feet S E p 0 2 2015 Effective Depth measured • 11,990 feet Packer measured 11,240 feet OGCC true vertical • 10,736 feet true vertical 10,227 feet �j Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130 psi 1,580 psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020 psi 3,400 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic littilVEP Tubing(size,grade,measured and true vertical depth) 2-7/8"&2-3/8" 6.5#&4.7#/L-80 7,763'&11,316'MD 7,760'&10,278'ND G-77 Hydraulic Pkr; 11,240'MD 10,227'ND Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 155 462 27 640 150 Subsequent to operation: 155 462 27 640 150 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 ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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: 315-479 Contact Joe Kaiser Email jkaisera.hilcorp.com Printed Name Joe Kaiser Title Operations Engineer // i / Signature ( . ._ r - Phone 907-777-8393 Date 7//// - /[ Form 10-404 Revised 5/2015 BDM534.AEP 0 1 nit Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 21C-04 50-133-20276-02 214-169 8/20/15 8/20/15 Daily Operations: 08/20/2015-Thursday Meet at office. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high.Shut well in. RIH w/ 1-9/16" x 20' Razor HC, 6 SPF, 60 deg phase perf gun and tie into SLB RST log dated 30 Dec 2014. Run correlation log from 11,600'to 11,250' and send to town. Get ok to perforate from 11,435'to 11,455'. Fired gun with 790 psi on tubing. Saw no pressure increase. POOH. All shots fired. RIH w/1-9/16" x 2' Razor HC, 6 SPF, 60 deg phase perf gun and tie into SLB RST log dated 30 Dec 2014. Run correlation log from and send to town. Get ok to perforate from 11,433'to 11,435'. Fired gun with 900 psi on tubing.Saw no pressure increase. POOH. All shots fired. RIH w/1-9/16" x 20' Razor HC, 6 SPF, 60 deg phase perf gun and tie into SLB RST log dated 30 Dec 2014. Run correlation log from and send to town. Get ok to perforate from 11,380' to 11,400'. Fired gun with 915 psi on tubing.Saw no pressure increase. POOH.All shots fired. RIH w/ 1-9/16"x 15' Razor HC, 6 SPF, 60 deg phase perf gun and tie into SLB RST log dated 30 Dec 2014. Run correlation log from and send to town. Get ok to perforate from 11,365'to 11,380'. Fired gun with 925 psi on tubing. Saw no pressure increase. POOH. All shots fired. Rig down lubricator and turn well over to field. vi 0 Swanson River Unit 40 SCU 21C-04 Well SCU 21C-04 Schematic Completion Ran: 12/13/14 Hilcorp Alaska,LLC RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB–THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" I Conductor 20" - - - Surf 44' 44' 2\ ii"s Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' !:/: 29.7 N-80 BTC 6.875" 3,798' 5,733' .a - Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 3n—lil ''i Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' ,372 3372TUBING DETAIL 3, ' Tubing 2-7/8" _ 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC 4 I r Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' JEWELRY DETAIL No. Depth ID OD Item 511 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box ur , 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7,795 4 4,978' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Live Valve) 4 r 5 6,770' 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Live Valve) ', U 4 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD a 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 I-1 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8`—W 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple p, 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 12/11/14 9 � t' PERFORATION DETAIL jo,3sa' t ` Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 10 F-11/05/15 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) a P 8/20/15 H 1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-9/16"HC(Razor) 1/05/15 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) I I r-- 8/20/15 H 2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-9/16"HC(Razor) _ 12/23/14H 6 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) ICE1 12/23/14 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 12 KA KM 13 X ' GLV Port Temp @ 14 # Size Depth TCF PSC PSO PTRO Description RA Mrk Jt ' t 1I-1 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-1IPPOR-1 6 16 148 0.835`1216 1341 1345 IPOR-1/1P0C-11PPOR-1 -- 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1IPPOR-1 H-2 4 16 184 0.783 1166 1226 1290 IPOR-1/IPOC-1/PPOR-1 3 16 194 0.770 1141 1177 1265 IPOR-1/1P0C-1/PPOR-1 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt I V 1 20 200 0.762 ORIFICE-1 RA Mrk Jt , N WELL DATA PTD:214-169 - H-6 i- hort RA Marker Joints API: 50-133-20276-02 11,350'-11,364'MD ? Lease: FEDA-028996 RA MrkJt 'I t: Tag Fill @ 11,885' KB @ , , 1.75"G-ring @ 11601%11615'MD Spud Date:11/22/2014 @ 11,696'-11,710'MD 4-1/2" 7/30/2015 Tree cxn: 3.5"Bowen @ 11,913'-11,927'MD 12,088' y Lift Threads: 3-1/2"8RD TD=12,090' PBTD=11,965' MAX HOLE ANGLE=58°@ 9,408' SCU 21C-04 Schematic 8-21-15 Updated by DMA 09-01-15 yTy ' ,,w\�\\1oF�j,s THE STATE Alaska Oil and Gas ofALASI�:A Conservation Commission Witt=== 333 West Seventh Avenue ' F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main907 279 1433 04t, ALAS�� Fax 907.276 7542 www.aogcc.alaska gov Joe Kaiser iCA"Efi Operations EngineerI14--- 161 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 21C-04 Sundry Number: 315-479 Dear Mr. Kaiser: 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, aze Cathy P. Foerster Chair DATED this wD day of August, 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ti ,' APPLICATION FOR SUNDRY APPROVALS A"t criis/o- 20 AAC 25.280 (1l�""s,,', C., 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑., • Other Stimulate ❑ Alter Casing ❑ Change ApprovedProgram ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. &e eu . • N 2.Operator Name: 4.Current Well Class: 5.Permit to DriN Number. Hilcorp Alaska,LLC Exploratory ❑ Development 2 • 214-169 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-133-20276-02 • 7.If perforating: S.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B • Sddotna Creek Unit(SCU)21C-04 • Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 1 cEPil 6 70 717 g,,&( . Swanson River/Hemlock Oil• 11. PRESENT LL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,090 ' 10,806- 11,990 10,736 N/A N/A Casing Length Size MD TVD Burst Collapse Structural • Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130psi 1,580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8"&2-3/8" 6.5#&4.7#/L80 7,763 &11,316 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): G-77 Hydraulic Pkr;N/A 11,240'MD/10,227'ND;N/A 12.Attachments: Description Summary of Proposal 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: Commencing Operations: August 20,2015 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 correct to the best of my knowledge. Contact Joe Kaiser Email jkaiserahilcoro.com Printed NameJoe Kaiser Title Operations Engineer y..-7 Signature ro-C Phone 907-777-8393 Date 61(.115-- COMMISSION /(s'1SCOMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t 5-Ln q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test p Location Clearance ❑ Other: 11 Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: `d i-j/0 y APPROVED BY Approved by: elee62 P%�,, ICOMMISSIONER THE COMMISSION Date: 25".../3 /5' 7�,„ �e•i t 15 Submit Form and Well Prognosis Well: SCU 21C-04 Hilcorp Alaska,LL' Date:08/06/2015 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: New Sidetrack Leg: N/A Estimated Start Date: August 20th, 2015 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,543 psi @ 10,300' TVD (Based on PT survey 4/11/15) Maximum Expected BHP: — 1,543 psi @ 10,300' TVD (Based on PT survey 4/11/15) Max. Allowable Surface Pressure: — 513 psi (Based on gas gradient of 0.10 psi/ft.) Brief Well Summary This well was drilled as a side track of the SCU 44-05 well in November 2014 with the Saxon #169 rig. The new well named SCU 21C-04 was originally perforated in the Hemlock bench 6 (H-6) sand in December 2014. The Hemlock bench 1 and 2 sands were perforated in January 2015. The purpose of this work/sundry is to perform the reperforations H-1, H-2, and H-6 intervals of this well. 11/4 There are no spacing exceptions in Swanson River Field for the Hemlock Oil. This work is regulated by conservation order, CO 123B. E-line Procedure: 1. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 2. RU 1-11/16" wireline guns (hollow carrier or strip guns). 3. SI well for perforating. 4. RIH and reperforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Hemlock H-1 11,365' 11,400' 35 6 Hemlock H-2 11,433' 11,455' 22 6 Hemlock H-6 11,772' 11,787' 15 6 Hemlock H-6 11,794' 11,798' 4 6 a. Proposed reperfs shown on the proposed schematic in red font. b. Final reperfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Cement Bond log. d. Record tubing pressures before and after each perforating run. 5. RD E-line. 6. Turn well over to production. Attachments: 1. Proposed Schematic Swanson River Unit • SCU 21C-04 Well SCU 21C-04 Completion Ran: 12/13/14 Proposed Schematic Fillilellorp Updated: 8/06/15 RKB:171.34'/GL: 153.34'AMSL CASING DETAIL KB-THF: 18.0' 1 Type Size WT Grade Conn ID Top Btm. 20" + 1 , Conductor 20" - - - - Surf 44' )/ 44' �4; 2 '- Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC _ 6.969" Surf 3,798' , )F 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' ' 33.7 P-110 BTC 6.765" 6,906' 7,993' • 3 1 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4" . rbet . 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" _ Surf 7,763' CBL TOC `11 4 1,-"—'D 42. Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' ij IP P JEWELRY DETAIL ` No. Depth ID OD Item 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box 4r — i 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL - 6 3 2,777' 2.441" 4.750" 2-7/8"5F0-1 GLM#7(Live Valve) 7798 ' . 4 4,978' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Live Valve) V4 h = 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) 6 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 0 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) , 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) ' 8 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple d, 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) '4,i 9 12/11/14 10,384' 1' 10 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments I l 1/OS/15(reperf) H-1 11,365' 11,400 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) _ 1/05/15(reperf) H-2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) z I i 12/23/14(reperf) H-6 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 12V - 1 = 12/23/14(reperf) H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) 1 13 , 14 RA Mrk Jt ' t --- 11-1 GLV Port Temp @ # Size Depth TCF PSC PSO PTRO Description 7 16 122 0.878 1241 1400 1385 IPOR-1/1P0C-1/PPOR-1 11-2 6 16 148 0.8351216 1341 1345 IPOR-1/1P0C-1/PPOR-1 5 18 169 0.804 1191 1280 1315 IPOR-1/IPOC-1/PPOR-1 4 16 184 0.783 1166 12261 1290 IPOR-1/1P0C-1/PPOR-1 RA Mrk Jt.,. � 3 16 194 0.770' 1141 '1177 1265 IPOR-1/1POC-1/PPOR-1 2 16 199 0.763 1116':1124 1245 IPOR-1/1POC-1/PPOR-1 RA Mrk Jt �� 11 20 200 0.762 j ORIFICE-1 4 —...e..— WELL DATA Short RA Marker Joints ` ,� _ H-6 PTD:214-169 @ 11,350'-11,364'MD RA Mrk Jt Tag Fill @ 11,885'KB @ 11,601'-11,615'MD API: 50-133-20276-02 1.75"G-ring @ 11,696'-11,710'MD Lease: FEDA-028996 4-1/2" ' a^ ri" tit' 7/30/2015 @ 11,913'-11,927'MD Spud Date:11/22/2014 12,088' Tree cxn: 3.5"Bowen TD=12,090' PBTD=11,965' Lift Threads: 3-1/2"8RD MAX HOLE ANGLE=58°@ 9,408' SCU 21C-04 Proposed Schematic 8-06-15 Updated by JK 8/6/15 211-I (0V II Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive 1 Cj 3 Anchorage, AK 99503 Tele: 907 777-8308 Hihnrr 1.14'41.1,1kFax: 907 777-8510 E-mail: snolan@hilcorp.com RECEIVED APR 162015 DATE 04/15/2015 AOGCC To: Alaska Oil & Gas Conservation Commission AOGCC Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 21C-04 2 boxes: Dry Cuttings Transmitted herewith are cuttings from SCU 21 C-04 , WELL: SAMPLE INTERVAL SCU 21C-04 8030'—10160' SCU 21C-04 10160'—12090' Please include current contact information if different from above. SCANNED . :' : Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Rec ived Date: RECEIVED MAR 0 6 2015 STATE OF ALASKA AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑� Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25 105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _ 1 Service ❑ Stratigraphic T;st ❑ 2.Operator Name: 5. Date Comp.,Susp.,or .,, 12.Permit to Drill Number: Hilcorp Alaska,LLC Aband.: J 214-169 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 11/23/2014 50-133-20276-02-00 4a.Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1950'FSL,567'FEL,Sec 5.T7N.R9W.SM.AK 12/3/2014 Sddotna Creek Unit(SCU)213-04 Top of Productive Horizon: 8. KB(ft above MSL): 171.3 15.Field/Pod(s): 1734'FNL, 1188'FWL,Sec 4,T7N.R9W,SM.AK GL(ft above MSL): 153.3 Swanson River/Hemlock Oil Total Depth: 9. Plug Back Depth(MD+TVD): 1309'FNL, 1531'FWL,Sec 4,T7N,R9W.SM.AK 11965'MD/10719'TVD 4b.Location of Well(State Base Plane Coordinates.NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 341744.45 y- 2457909.95 Zone- 4 12090'MD/10807'TVD FED028996/028997 TPI: x- 343525.77 y- 2459495.25 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 343865.99 y- 2459902.97 Zone- 4 N/A N/A(SRF Sddotna CreekUnit) 18.Directional Survey: Yes Q No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/PD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window METVD: FEL 2"/5"MD,DEL 2"MD,GRL 2"MD.ROP-DGR-EWR 7/5"MD/TVD 7993'MD/7990'TVD 23. CASING.LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGFT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 4-1/2" 12.6 L-80 7798' 12088' 7790' 10807' 6-1/8" 102 bbls, 15.3#.Class G 24.Open to production or injection? Yes ❑ 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): 2-3/8"x2-7/8" 11,316' 11.240'MD/10.:27'TVD • Zone Top(MD/TVD) Btm(MD/TVD) SPF Ft Size H-6 11,772'/10,586' 11,787'/10,596' 6 15 1-11/16" 26. ACID,FRACTURE,CEMENT SQUEEZE.ETC. 1-1-6 11,794'/10,600' 11,798710.604' 6 4 1-11/16" Was hydraulic fracturing used during completion? Yes ❑ No El H-2 11,433'/10,356' 11,455'/10,371' 6 22 1-11/16" H-1 11,365'/10,311' 11,400'/10,334' 6 35 1-11/16" DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED .i...-_, (., 27. ? • ).i- PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 12/23/2014 Gaslift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/13/2015 24 Test Period ..4 325 391 72 N/A 1,203 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press. 220 810 24-Hour Rate - 325 391 72 31 28. CORE DATA Conventional Core(s)Acquired'? Yes❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. y p APR 1 0 2015 RBDMS.` 1 APR 1 0 2015 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? ❑ Yes ❑� No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Tyonek_G2ST 11243 10229 Hemlock 11353 10303 H2 11425 10351 H3 11476 10385 H4 11602 10470 H5 11633 10491 H6 11759 10577 H7 11810 10612 H8 11892 10668 H8 Base 11946 10706 Formation at total depth: Hemlock 11000 31. List of Attachments:Well Schematic,Days vs.Depth&MW vs Depth Graphs, Definitive Directional Survey,Daily Drilling Composite, Casing&Cementing Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporhola(p)hilcorp.com Printed Name: Stan Porholaa Title: Operations Engineer 06/6 Signature: ) � Phone: 907-777-8412 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 Donna Ambruz From: Donna Ambruz Sent: Friday, March 06, 2015 3:11 PM To: Guy Schwartz(guy.schwartz@alaska.gov) Cc: Stan Porhola Subject: Updated SCU 21C-04 10-407 (PTD 214-169) Missing H1 & H2 Perfs Attachments: SCU 21C-04 AOGCC 10-407 Completion Resubmitted 3-6-15.pdf ce pec- Hi Guy—Please accept the attached updated 10-407 applitlfriin and schematic for SCU 21C-04 10-407 (PTD 214-169) previously submitted on February 2, 2015 as we inadvertently omitted the H1 & H2 perforations. The originals will follow under separate cover via courier on Monday, March 9, 2015. Thank you. Dannac Qm buvz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310-Fax dambruzPhilcorp.com 1 • 21C-04 Swanson River Unit SCUWell SCU 21C-04 • Completion Ran. 12/13/14 Actual Schematic Updated: 1/05/15 Hikorp Alaska,LLC RKB: 171.34'/GL:153.34'AMSL CASING DETAIL KB—THF: 18.0' Type Size WT Grade Conn ID Top Btm. 20" 1 Conductor 20" - Surf 44' 44' �., '- I libilil Surface 10-3/4" 40.5 K-55 BTC 10.050" _ Surf _ 3,372' litY.4 26.4 N-80 BTC 6.969" Surf 3,798' I' 29.7 N-80 BTC 6.875" 3,798' 5,733' r°,'i Production 7-5/8" - ' 33.7 S-95 BTC 6.765" 5,733' 6,906' t 33.7 P410 BTC 6.765" 6,906' 7,993' • 31-11 ,4 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' , '° ,.3372' TUBING DETAIL 3,372 Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' CBL TOC . 4 I iI ti, Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' . JEWELRY DETAIL No. Depth ID OD Item 51 h1 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box ,+ _ 2 19.71' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TO!, 6 _ 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7,798 4 4,978' _2.441" 4.750" 2-7/8"SFO-1 GLM#6(Live Valve) '4 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) U. ,11. 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 0 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7.5/8L 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,993' 7 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) ;• 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) 12/11/14 10,384' y' r.- IH to PERFORATION DETAIL °.• Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 111/05/15 H-1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC(Titan) "A` 1/05/15 H-2 11,433' 11,455' 10,356' 10,371' 6 22 60 1-11/16"HC(Titan) �, 1411 I 12/23/14 H-6 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC(Titan) 1297 LL ♦E _ .`'' 12/23/14 H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC(Titan) it . 13 is 1.4 RA\Irk.lt ' II 1 GLV Port Temp @ # Size Depth TCF PSC PSO PTRO Description 7 16 122 0.878 1241 1400 1385 IPOR-1l1P0C-1/PPOR-1 11-2 6 16 148 0.835 1216 1341 1345;IPOR-1/1P0C-1/PPOR-1 • 5 16 169 0.804 1191 1280 1315'IPOR-1!IPOC-1/PPOR-1 4 16 184 0.783 1166 1226 1290'•:IPOR-1/IPOC-1/PPOR-1 RA Irk Jt 3 16 194 0.770 1141 1177 1265;IPOR-1/IPOC-1/PPOR-1 2 16 199 0.763 1116 1124 1245 IPOR-1 IIPOC-11PPOR-1 1 20 200 0.762 ORIFICE-1 RA Mrk Jt,' 11-6• • — WELL DATA Short RA Marker Joints fa' @ 11,350'-11,364'MD PTD:214-169 RA Mrk Jt • Tag PBTD @ 11,975'SLM @ 11,601'-11,615'MD API: 50-133-20276-02 1.75"P/T Gauges @ 11,696'-11,710'MD Lease: FEDA-028996 4-1/2" .i s12/24/14 @ 11,913'-11,927'MD Spud Date:11/22/2014 " ar+ 12,088' "`""x� . 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C G G w U U U `� .o .0 07 J � N d N a7 CJ E 0 a 0 a 03 o E a O 0 0 0 2 m Q rn — LL E o EE E a 2 w w 3 ? 0 c� 0 p 0 O WAtf RECEIVED Hilcorp Alaska, LLC Post Office Box 244027 FEB 0 2 2015 Anchorage,AK 99524-4027 3800 Centerpoint Drive AOGCC Suite 1400 Anchorage,AK 99503 Phone: 907/777.8300 February 2, 2015 Fax: 907/777.8301 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage,Alaska 99501 Re: SCU 21C-04 Form 10-407 PTD: 214-169 API: 50-133-20276-02-00 Dear Commissioner: Please find the enclosed Well Completion Form 10-407 for SCU 21C-04. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LC // — Cody Di•ger Drilling Technician (907)777-8389 cdinger@hilcorp.com • 1 of 1 _RECEIVED • FEB 022015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4(Y CC WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil Q - Gas ❑ SPLUG El Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAc 25.105 20AAC25110 Development o • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _ 1 • Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Suis) . 12.Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 1/5f 1 214-169 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 •11/23/2014 50-133-20276-02-00 • 4a. Location of Well(Governmental Section): 7.Date TD Readied: 14.Well Name and Number: Surface: 1950'FSL,567'FEL,Sec 5,T7N,R9W,SM,AK • • 12/4/2014 Soldotna Creek Unit(SCU)21C-04 • Top of Productive Horizon: 8.KB(ft above MSL): 171.3- 15.Field/Pool(s): 1734'FNL, 1188'FWL,Sec 4,T7N,R9W,SM,AK GL(ft above MSL): 153.3 Swanson River/Hemlock 0/ • Total Depth: 9.Plug Back Depth(MD+TVD): 1309'FNL, 1531'FWL.Sec 4,T7N,R9W,SM,AK . 11965'MD/10719'TVD • 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: _ Surface: x- 341744.45 . y- 2457909.95 - Zone- 4 ' 12090'MD/10807'TVD . FED028996/028997 TPI: x- 343525.77 y- 2459495.25 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 343865.99 y- 2459902.97 Zone- 4 N/A N/A(SRF Soldotna Creek Unit) 18.Directional Survey: Yes Q No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: FEL 2"/5"MD,DEL 2"MD,GRL 2"MD,ROP-DGR-EWR 2"/5"MD/TVD • 7993'MD/7990'TVD 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 4-1/2" 12.6 L-80 7798' 12088' 7790' 10807' 6-1/8" 102 bbls,15.34,Class G . •1315x 24.Open to production or injection? Yes Q 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 anc Number): 2-3/8"x2-7/8" 11,316' 11,240'MD/10,227'TVD Zone Top(MD/TVD) Btm(MD/TVD) SPF Ft Size H-6 11,772'/10,586' 11,787'/10,596' 6 15 1-11/16" 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. H-6 11,794'/10,600' 11,798'!10,604' 6 4 1-11/16" Was hydraulic fracturing used during completion? Yes ElLJ No nt.Ei7v" DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L L 1_- rl .. 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,eta): 12/23/2014 Gaslift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/13/2015 24 Test Period .-►325 391 72 N/A 1,203 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF. Water-Bbl. Oil Gravity-API(corr): Press. 220 810 24-Hour Rate -4- 325 • 391 72 31 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ • Sidewall Cores Acquired? Yes ❑ No El ' If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. ` i ,2-5-6 RBDM8.1 FEB - 4 2015 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only � �� • • - J 29. GEOLOGIC MARKERS (List all formations and markers encountered). 30. FORMATION TESTS NAME MD TVD Well tested? n Yes E No r If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base Tyonek_G2ST 11243 10229 Hemlock 11353 10303 H2 11425 10351 H3 11476 10385 H4 11602 10470 H5 11633 10491 4_0/7/ ,3ZS Bpr-p H6 11759 10577 — T2as""f, 3¢/ 11'14 G..6 H7 11810 10612 J H8 11892 10668 i-l�'� 77-34,1?),H8 Base 11946 10706 Formation at total depth: Hemlock 11000 31. List of Attachments:Well Schematic,Days vs.Depth&MW vs Depth Graphs,Definitive Directional Survey,Daily Drilling Composite, Casing&Cementing Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email: mmyershilcorp.com Printed Name: Monty Myers Title: Drilling Engineer Signature: Phone: 907-777-8431 Date: ,2. .Z 2 C INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8• The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits(ex.50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 SCU 21C-04 Well SCU 21C-04 Completion Ran: 1 Actual ScheSwanson River Uni matic Updated: 12/23/14'".:', Mirnik.,,,,,Aia.ka.lic RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB–THF:18.0' Type Size WT Grade Conn ID Top Btm. zu' 1 Conductor 20" - - - - Surf 44' 44' J 2 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' . 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 3_i1 % Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-32•' — ki 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,763' c , CBL TOC 4 » Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,763' 11,316' 4,240' 1 JEWELRY DETAIL No. Depth ID OD Item 'I hl� 1 17.83' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box 2 19.71' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 3 2,777' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Live Valve) 7,798 4 4,978' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Live Valve) 5 6,770' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Live Valve) C; 6 7,763' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 5 01 1 7 8,152' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Live Valve) 7-5/8" 8 9,250' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Live Valve) 7,99 7 111. 9 10,185' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Live Valve) 10 11,118' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Live Valve) 11 11,193' 1.990" 3.750" Chemical Injection Mandrel(Live Valve,3kpsi spring) 8 12 11,240' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(15k to release) t 13 11,283' 1.875" 3.063" X-Nipple 14 11,316' 1.995" 3.063" WL Entry Guide CBL(TOC) -L 9 12/11/14 mllmPo 10,384' , 10 PERFORATION DETAIL k 44 14 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments i1 4.0. 12/23/14 H-6 11,772' 11,787' 10,586' 10,596' 6 15 60 1-11/16"HC 12/23/14 H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC 31 I ti 12 13X -p , 14 , RA Dirk JtV GLV Port Temp @ # Size Depth TCF PSC PSO PTRO Description 7 16 122 0.878 1241 1400 1385 IPOR-1/IPOC-11PPOR-1 ifsl 6 16 148 0.835 1216 1341 1345 IPOR-1/IPOC-1/PPOR-1 5 16 169 0.804 1191 1280 1315 IPOR-1/IPOC-1/PPOR-1 4 16 184 0.783 1166 1226 1290 IPOR-111P0C-1/PPOR-1 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1/PPOR-1 RAMrkJt t: 1 2 16 199 0.763 1116 1124 1245 IPOR-1/1P0C-1/PPOR-1 1 20 200 0.762ORIFICE-1 RA Mrk it t4' '"� WELL DATA -- 11-6 Short RA Marker Joints @ 11,350'-11,364'MD PTD:214-169 RA MrkJt . t: @ 11,601'-11,615'MD API: 50-133-20276-02 i @ 11,696'-11,710'MD Lease: FEDA-028996 4-1/2' ','` r.. @ 11,913'-11,927'MD Spud Date:11/22/2014 12,088' Tree cxn: 3.5"Bowen TD=12,090' PBTD=11,965' Lift Threads: 3-1/2"8RD MAX 11OLE ANGLE=58°@ 9,408' SCU 21C-04 Actual Schematic 01-06-15 Updated by STP 12/23/14 V N a) , > co ai n 0 ns C a• C ai a c = m m a) O- co o Q Y a�,� 2 L C CL a)U 0 ai o C O C o 0 a0 O c0 o E 'a > .> o — ,� O c c 301- -1- -0 aacri � � o = o aaa)) o a) oV c a 3 CL 0 CD = Epm o =c o • • .S p0 -a0 - .- c- N30a ' LN a) EaN - C " 0 > > o 3 u- ar m� o .0QaN o -•DC OCcN La) NUo rnaY •- . 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O Il 0 O. > 0 m EIS_ Y L co N _ 'C C rn•> = o = rCo00 .c0a) a)oJo � VV3Eco) c n 3 .L co r-- a O = o N a m 'c cp:cr U 3 � o m @ o Com # m -a -oa � 2 c c o Q 8 2 o a n o $ o u' ._c en_ m w >, m w a E 3 C L @@ a) •Q n aa) m � c o a) 0 - CO o as 7-a- aoE3C@)= C' a) -?.5 c , •EE • c O o.v oN cm°nooM L n m E rnp ca c o o aEi m o c a'c i F- u@i 3 moM• o rn� > N c 3 N a) 8 C `a _ co T� o CC O :NLL cL_ � a`> = O > Y � o o a) c N � Jc >, o _2 — a o v .a -E 8. _c @ • O N E O N0 0 o I- c @ 0 .. = a - @oma ooh c _a3 vi m in ' a) U S = o v Y U 2 E 0) jr_ a c H o o c 3 o N ,-°) o 0 3 > to a) E _ > o L @ 0 3 co J@o o C U (n @ L O @ .O U o @ f6 Q' C N C — .�X N d = u) '-' c� M 'O @ C = — — u) " = a) c 0c‘l -c = L,,, _•' -aM > > U @r LO L a C yCS Y � 70 3 co a> 3 0 �I Ca. N dm co c ~0 = hi! U wa E U >a � 3ca w oL _ � rn a) r� = E � � = tT @N CO Co aa)) co) 3 —. o Co .0 0 g= o w- a) ui � > N .E E c x .0 o C c ch a 4) a U > o .E a) LL co C a) M M N C "- N 0@ ,C > a) Q C C '=O 04, 0 -0 LL O O "L••' C 7 C 0 = .0 U d C •c N d co Q = U co O N - In = L = d 0 CO X N CO c@j 0 O co.@ a) 7 C C to 7 w _ 'C COpa) a) �- U U a V .fl Co p 3 `- O co 'a_ =O C •a ui a s C O - .0 C) C L N O U J •� C ' LL > C U CO a) c E 0 T CO @ N O Lo N U C O U il a) E •Cl)' Q CO = co CO u) a) a N N O 0 m c .0 O CD 0.E'0 M 0 -o co N U- 2 O a U n3 0) •c > O 'C U o - y T Cj m- '- °� °O 'ato Yo cM o - . a • 03 @ g = a g E °)-O a u0) N Co , N L N c0 E cn in ti ` -v im O O • OO L U c @ .c > v7 0 tv in ab m U o o ` 3 C a? Q .G -.E. ' °)- > Co O N in e u) o f col a co a) N—0a) o •Q.• )n o a) O o o gi @ y = Y m U) rn r- O tri O ' a). a) cvj to a r 3 0 .� us C L -a 'U 3 @ CC O ") O LI c 49:- ai o = c c a> to c -i H Y= a a, a © '0 7 a) o a) o C c Ti 0 o c J 0 0 a) .� a a Cl) .0 c C C E o <) v = rn C') ° « N c c 0 •c = = C)>>@ 0) @ o •- �p Z = ° >' CI) (I) N 3 75 @ fl•CO in M Q V 0 O C ..- p Q 0 0 0 2 C I y 3 CO d I- Q Hrb 3 cn aa)) NICO Ea? Ua .2wH F- ccoocotod _o E _c .L_. @ 42N Q 0 on U a E d a. O co a_ � O 0 O O o O O O O o '� o Q N N N N N N N N _c-...1 54- N O N M CO c� Co 0) 0 M Tt 0 -c...\.1 \ ` r r r r r N N N Cr) N N N r (.-.. (..-j (N r d N N T r arr r r t� r _ 3 ® 2 .2 o C ± t ® � : § gE / § 7 / � 2 ' 0a) _ CO E 2 C y c _j . 07 : 273 caa) aSl L a .> o 0 0 � `- °- 0 Zoom I 0-rY ƒ . /_ m & > / mcr '7) ) k2 r0Q. W ° 2Tee $ \ = - a85� e > _ = e u- c0 % 7 @ E C E ƒ \r- 0 .0 / wco - § 2 § 2 „,- c \ &� � • & omr � B •c o # % § G \ / I = = Z.: _ or)© 0 = F- I '- rx ® � \ § \ \ / \ kms / \ '4205 *oe 2R22 � R � � = � GEa � o2oom 2Econt 10g 0. . E'2f D k 0 §(13 k 0 / 2 c 0 u, po� 0_ - a; lz ± k w U)E. ƒI § f / k [ E 2 E + Ia2c tea - » n = 17 -o BR » 2 . > � • \ 0/ a £ , &» Cl) .� o 2 2ain0 ' eo o_r _ m .zu 'Es o _* U) > E , O ' c,O , .0 - ® = o E R \ E 2 3 2f � E± 12 ® 0_> 2 co 0- o = I * -a \ % 09 2 ® 02 = > 13 � I11). r \ 2 # a Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit SCU 21C-04 0 I 50-133-20276-02-00 11 50-133-20276-02-00 Sperry Drilling Definitive Survey Report 15 December, 2014 pi 1 HAL.LIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Project: Soldotna CK Unit TVD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) . Site: Soldotna CK Unit MD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Well: Soldotna CK Unit 33-05 North Reference: True Wellbore: SCU 21C-04 Survey Calculation Method: Minimum Curvature Design: SCU 21C-04 Database: Sperry EDM-NORTH US+CANADA Project Soldotna CK Unit,Swanson River Field Map System: US State Plane 1927(Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) _ Using Well Reference Point Map Zone: Alaska Zone 04 . Well Soldotna CK Unit 33-05 Well Position +N/-S 0.00 usft Northing: 2,457,909.95 usft _ Latitude: 60.7247852 +El-W 0.00 usft Easting: 341,744.45 usft _ Longitude: -150.8839274 'Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 153.34 usft Wellbore SCU 21C-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) (0) (nT) BGGM2014 11/10/2014 16.94 73.71 55,471 Design SCU 21C-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,765.34 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 18.00 0.00 0.00 51.30 Survey Program Date 12/15/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 296.34 7,765.34 SCU 33-5(SCU 33-05) CB-Gyro-SS Fixed:v2:Camera based gyro single shot 02/11/2014 7,993.00 8,106.21 SCU 21C-04 MWD+Interp Azi+sag(SCU MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 11/25/2014 8,167.47 12,053.86 SCU 21C-04 MWD+SC+Sag(SCU 21C- MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 11/25/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -153.34 0.00 0.00 2,457,909.95 341,744.45 0.00 0.00 UNDEFINED 296.34 0.50 320.00 296.34 125.00 0.93 -0.78 2,457,910.89 341,743.68 0.18 -0.03 CB-Gyro-SS(1) 609.34 0.25 305.00 609.33 437.99 2.37 -2.22 2,457,912.34 341,742.26 0.09 -0.25 CB-Gyro-SS(1) 912.34 0.25 279.00 912.33 740.99 2.85 -3.41 2,457,912.84 341,741.07 0.04 -0.88 CB-Gyro-SS(1) 1,224.34 0.50 115.00 1,224.32 1,052.98 2.38 -2.85 2,457,912 37 341,741.63 0.24 -0.74 CB-Gyro-SS(1) 1,511.34 0.50 130.00 1,511.31 1,339.97 1.05 -0.76 2,457,911.00 341,743.71 0.05 0.06 CB-Gyro-SS(1) 1,794.34 0.50 103.00 1,794.30 1,622.96 -0.02 1.39 2,457,909.90 341,745.84 0.08 1.07 CB-Gyro-SS(1) 2,105.34 0.50 30.00 2,105.29 1,933.95 0.85 3.39 2,457,910.75 341,747.85 0.19 3.18 CB-Gyro-SS(1) 2,421.34 0.25 105.00 2,421.29 2,249.95 1.86 4.75 2,457,911.74 341,749.22 0.16 4.87 CB-Gyro-SS(1) 2,701.34 0.25 65.00 2,701.29 2,529.95 1.96 5.89 2,457,911.83 341,750.37 0.06 5.82 CB-Gyro-SS(1) 3,016.34 0.50 162.00 3,016.28 2,844.94 0.95 6.94 2,457,910.80 341,751.40 0.19 6.01 CB-Gyro-SS(1) 3,169.34 0.25 136.00 3,169.28 2,997.94 0.07 7.38 2,457,909.92 341,751.83 0.19 5.80 CB-Gyro-SS(1) 12/15/2014 5:11:10PM Page 2 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Project: Soldotna CK Unit TVD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Site: Soldotna CK Unit MD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Well: Soldotna CK Unit 33-05 North Reference: True Wellbore: SCU 21C-04 Survey Calculation Method: Minimum Curvature Design: SCU 21C-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,401.34 0.50 118.00 3,401.27 3,229.93 -0.77 8.62 2,457,909.06 341,753.06 0.12 6.25 C8-Gyro-SS(1) 3,720.34 0.75 90.00 3,720.25 3,548.91 -1.42 11.94 2,457,908.36 341,756.37 0.12 8.43 CB-Gyro-SS(1) 4,010.34 1.00 86.00 4,010.22 3,838.88 -1.25 16.36 2,457,908.48 341,760.79 0.09 11.99 CB-Gyro-SS(1) 4,191.34 1.25 91.00 4,191.18 4,019.84 -1.17 19.91 2,457,908.51 341,764.34 0.15 14.81 CB-Gyro-SS(1) 4,443.34 1.50 90.00 4,443.11 4,271.77 -1.22 25.96 2,457,908.38 341,770.39 0.10 19.50 CB-Gyro-SS(1) 4,753.34 1.75 82.00 4,752.99 4,581.65 -0.56 34.70 2,457,908.92 341,779.14 0.11 26.73 CB-Gyro-SS(1) 4,943.34 1.25 81.00 4,942.92 4,771.58 0.17 39.62 2,457,909.58 341,784.07 0.26 31.03 CB-Gyro-SS(1) 5,223.34 1.50 65.00 5,222.84 5,051.50 2.19 45.96 2,457,911.52 341,790.43 0.16 37.24 CB-Gyro-SS(1) 5,413.34 1.50 62.00 5,412.78 5,241.44 4.41 50.41 2,457,913.68 341,794.91 0.04 42.10 CB-Gyro-SS(1) 5,726.34 1.25 59.00 5,725.69 5,554.35 8.10 56.95 2,457,917.27 341,801.51 0.08 49.51 CB-Gyro-SS(1) 5,898.34 1.50 46.00 5,897.64 5,726.30 10.63 60.18 2,457,919.76 341,804.77 0.23 53.61 CB-Gyro-SS(1) 6,204.34 1.75 35.00 6,203.51 6,032.17 17.23 65.74 2,457,926.29 341,810.42 0.13 62.08 CB-Gyro-SS(1) 6,540.34 2.50 39.00 6,539.28 6,367.94 27.13 73.30 2,457,936.09 341,818.10 0.23 74.17 CB-Gyro-SS(1) 6,969.34 3.00 39.00 6,967.79 6,796.45 43.13 86.25 2,457,951.91 341,831.27 0.12 94.28 CB-Gyro-SS(1) 7,168.34 3.00 39.00 7,166.51 6,995.17 51.22 92.80 2,457,959.91 341,837.93 0.00 104.45 CB-Gyro-SS(1) 7,399.34 3.00 39.00 7,397.20 7,225.86 60.62 100.41 2,457,969.21 341,845.67 0.00 116.26 CB-Gyro-SS(1) 7,765.34 2.25 32.00 7,762.81 7,591.47 74.15 110.25 2,457,982.61 341,855.68 0.22 132.40 CB-Gyro-SS(1) 7,993.00 2.25 30.30 7,990.30 7,818.96 81.80 114.87 2,457,990.19 341,860.41 0.03 140.79 MWD_InterpAzi+sag(2) 8,044.89 4.43 41.36 8,042.09 7,870.75 84.19 116.71 2,457,992.55 341,862.28 4.36 143.72 MWD_Interp Azi+sag(2) 8,106.21 7.06 46.03 8,103.10 7,931.76 88.58 120.99 2,457,996.89 341,866.62 4.35 149.81 MWD_InterpAzi+sag(2) 8,167.47 8.59 48.26 8,163.79 7,992.45 94.24 127.11 2,458,002.47 341,872.82 2.55 158.12 MWD+SC+sag(3) 8,231.11 10.83 49.61 8,226.51 8,055.17 101.28 135.21 2,458,009.40 341,881.01 3.54 168.85 MWD+SC+sag(3) 8,293.16 13.74 49.75 8,287.14 8,115.80 109.82 145.28 2,458,017.80 341,891.19 4.69 182.04 MWD+SC+sag(3) 8,355.00 14.82 49.16 8,347.07 8,175.73 119.74 156.87 2,458,027.56 341,902.91 1.76 197.29 MWD+SC+sag(3) 8,416.07 17.01 49.93 8,405.79 8,234.45 130.60 169.61 2,458,038.25 341,915.80 3.60 214.03 MWD+SC+sag(3) 8,479.32 19.70 47.61 8,465.82 8,294.48 143.74 184.57 2,458,051.19 341,930.94 4.41 233.92 MWD+SC+sag(3) 8,541.80 21.00 46.95 8,524.40 8,353.06 158.48 200.53 2,458,065.72 341,947.09 2.11 255.59 MWD+SC+sag(3) I 8,602.90 23.00 49.57 8,581.05 8,409.71 173.70 217.62 2,458,080.70 341,964.38 3.65 278.44 MWD+SC+sag(3) 8,666.07 25.75 51.48 8,638.58 8,467.24 190.25 237.75 2,458,096.98 341,984.74 4.53 304.50 MWD+SC+sag(3) 8,728.79 29.56 50.41 8,694.13 8,522.79 208.61 260.34 2,458,115.03 342,007.57 6.13 333.61 MWD+SC+sag(3) 8,792.59 32.28 50.07 8,748.85 8,577.51 229.57 285.54 2,458,135.66 342,033.05 4.27 366.38 MWD+SC+sag(3) 8,855.19 34.64 51.43 8,801.08 8,629.74 251.40 312.27 2,458,157.12 342,060.07 3.96 400.89 MWD+SC+sag(3) 8,919.11 37.20 52.50 8,852.84 8,681.50 274.49 341.81 2,458,179.81 342,089.92 4.12 438.38 MWD+SC+sag(3) 8,982.22 39.58 53.04 8,902.30 8,730.96 298.20 373.02 2,458,203.10 342,121.44 3.81 477.56 MWD+SC+sag(3) 9,045.89 43.11 53.15 8,950.09 8,778.75 323.45 406.64 2,458,227.89 342,155.41 5.55 519.59 MWD+SC+sag(3) 9,109.63 45.66 52.94 8,995.64 8,824.30 350.25 442.27 2,458,254.21 342,191.39 4.01 564.15 MWD+SC+sag(3) 9,171.21 48.16 50.94 9,037.71 8,866.37 377.98 477.66 2,458,281.47 342,227.15 4.70 609.11 MWD+SC+sag(3) 9,222.70 50.68 50.23 9,071.20 8,899.86 402.82 507.87 2,458,305.89 342,257.69 5.00 648.21 MWD+SC+sag(3) 9,285.36 54.79 48.84 9,109.13 8,937.79 435.18 545.79 2,458,337.74 342,296.04 6.79 698.04 MWD+SC+sag(3) 9,345.57 57.02 48.89 9,142.88 8,971.54 467.98 583.34 2,458,370.03 342,334.03 3.70 747.85 MWD+SC+sag(3) 12/15/2014 5:11:10PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Project: Soldotna CK Unit TVD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Site: Soldotna CK Unit MD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Well: Soldotna CK Unit 33-05 North Reference: True Wellbore: SCU 21C-04 Survey Calculation Method: Minimum Curvature Design: SCU 21C-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,408.07 57.75 48.67 9,176.57 9,005.23 502.67 622.93 2,458,404.19 342,374.09 1.21 800.45 MWD+SC+sag(3) 9,470.81 57.52 48.22 9,210.16 9,038.82 537.82 662.59 2,458,438.80 342,414.22 0.71 853.38 MWD+SC+sag(3) 9,533.77 57.30 48.20 9,244.07 9,072.73 573.17 702.14 2,458,473.62 342,454.24 0.35 906.35 MWD+SC+sag(3) 9,596.56 57.10 48.48 9,278.08 9,106.74 608.26 741.57 2,458,508.17 342,494.14 0.49 959.05 MWD+SC+sag(3) 9,658.25 56.65 48.25 9,311.79 9,140.45 642.58 780.19 2,458,541.97 342,533.21 0.79 1,010.65 MWD+SC+sag(3) 9,722.24 56.06 48.66 9,347.25 9,175.91 677.91 820.06 2,458,576.76 342,573.55 1.07 1,063.86 MWD+SC+sag(3) 9,785.80 57.38 47.48 9,382.12 9,210.78 713.42 859.58 2,458,611.73 342,613.55 2.59 1,116.90 MWD+SC+sag(3) 9,848.09 57.40 46.99 9,415.69 9,244.35 749.05 898.10 2,458,646.84 342,652.55 0.66 1,169.24 MWD+SC+sag(3) 9,910.35 56.94 47.52 9,449.45 9,278.11 784.55 936.52 2,458,681.83 342,691.44 1.03 1,221.43 MWD+SC+sag(3) 9,974.57 56.97 47.06 9,484.47 9,313.13 821.07 976.08 2,458,717.80 342,731.49 0.60 1,275.13 MWD+SC+sag(3) 10,038.09 57.15 47.12 9,519.01 9,347.67 857.36 1,015.12 2,458,753.57 342,771.02 0.29 1,328.29 MWD+SC+sag(3) 10,101.51 57.63 46.47 9,553.18 9,381.84 893.94 1,054.06 2,458,789.62 342,810.44 1.15 1,381.55 MWD+SC+sag(3) 10,163.33 57.33 47.13 9,586.42 9,415.08 929.62 1,092.06 2,458,824.79 342,848.92 1.02 1,433.52 MWD+SC+sag(3) 10,215.94 57.67 46.91 9,614.69 9,443.35 959.87 1,124.52 2,458,854.60 342,881.78 0.74 1,477.76 MWD+SC+sag(3) 10,278.96 57.48 47.10 9,648.48 9,477.14 996.14 1,163.43 2,458,890.34 342,921.17 0.39 1,530.81 MWD+SC+sag(3) 10,340.59 57.57 47.00 9,681.57 9,510.23 1,031.57 1,201.48 2,458,925.25 342,959.70 0.20 1,582.66 MWD+SC+sag(3) 10,402.66 57.66 47.06 9,714.81 9,543.47 1,067.30 1,239.84 2,458,960.46 342,998.53 0.17 1,634.93 MWD+SC+sag(3) 10,465.62 57.42 46.96 9,748.60 9,577.26 1,103.52 1,278.69 2,458,996.16 343,037.88 0.40 1,687.91 MWD+SC+sag(3) 10,527.74 55.57 46.85 9,782.89 9,611.55 1,138.91 1,316.52 2,459,031.03 343,076.17 2.98 1,739.55 MWD+SC+sag(3) 10,589.80 55.26 48.56 9,818.12 9,646.78 1,173.95 1,353.70 2,459,065.57 343,113.83 0.63 1,790.48 MWD+SC+sag(3) 10,652.11 53.55 45.77 9,854.39 9,683.05 1,209.03 1,390.25 2,459,100.16 343,150.85 2.93 1,840.94 MWD+SC+sag(3) 10,715.31 52.34 45.58 9,892.47 9,721.13 1,244.27 1,426.34 2,459,134.91 343,187.40 1.93 1,891.13 MWD+SC+sag(3) 10,778.96 51.86 44.74 9,931.57 9,760.23 1,279.69 1,461.95 2,459,169.84 343,223.49 1.29 1,941.07 MWD+SC+sag(3) 10,842.38 51.53 44.66 9,970.88 9,799.54 1,315.06 1,496.96 2,459,204.74 343,258.97 0.53 1,990.51 MWD+SC+sag(3) 10,905.41 51.43 44.44 10,010.13 9,838.79 1,350.20 1,531.55 2,459,239.42 343,294.03 0.32 2,039.48 MWD+SC+sag(3) 10,969.43 50.50 43.69 10,050.45 9,879.11 1,385.93 1,566.14 2,459,274.68 343,329.09 1.71 2,088.81 MWD+SC+sag(3) 11,031.91 50.28 43.84 10,090.29 9,918.95 1,420.70 1,599.43 2,459,308.99 343,362.85 0.40 2,136.53 MWD+SC+sag(3) 11,095.10 49.81 43.21 10,130.87 9,959.53 1,455.82 1,632.79 2,459,343.66 343,396.68 1.07 2,184.53 MWD+SC+sag(3) 11,156.30 48.69 40.93 10,170.82 9,999.48 1,490.22 1,663.86 2,459,377.64 343,428.21 3.36 2,230.28 MWD+SC+sag(3) 11,217.96 47.65 39.14 10,211.94 10,040.60 1,525.39 1,693.41 2,459,412.41 343,458.23 2.74 2,275.34 MWD+SC+sag(3) 11,280.59 47.70 39.38 10,254.11 10,082.77 1,561.25 1,722.72 2,459,447.87 343,488.02 0.29 2,320.63 MWD+SC+sag(3) 11,342.18 47.94 39.38 10,295.47 10,124.13 1,596.52 1,751.67 2,459,482.75 343,517.45 0.39 2,365.28 MWD+SC+sag(3) 11,404.43 47.99 39.35 10,337.15 10,165.81 1,632.27 1,781.00 2,459,518.10 343,547.25 0.09 2,410.52 MWD+SC+sag(3) 11,467.16 47.90 39.22 10,379.17 10,207.83 1,668.32 1,810.49 2,459,553.75 343,577.22 0.21 2,456.08 MWD+SC+sag(3) 11,530.71 47.66 39.23 10,421.88 10,250.54 1,704.78 1,840.25 2,459,589.81 343,607.47 0.38 2,502.10 MWD+SC+sag(3) 11,591.63 47.48 38.77 10,462.98 10,291.64 1,739.72 1,868.55 2,459,624.37 343,636.24 0.63 2,546.03 MWD+SC+sag(3) 11,654.98 47.09 38.64 10,505.95 10,334.61 1,776.05 1,897.65 2,459,660.29 343,665.83 0.63 2,591.46 MWD+SC+sag(3) 11,717.43 46.98 38.83 10,548.51 10,377.17 1,811.69 1,926.25 2,459,695.55 343,694.90 0.28 2,636.07 MWD+SC+sag(3) 11,779.11 46.73 39.21 10,590.69 10,419.35 1,846.66 1,954.58 2,459,730.13 343,723.70 0.61 2,680.04 MWD+SC+sag(3) 11,841.20 46.57 39.24 10,633.32 10,461.98 1,881.63 1,983.13 2,459,764.72 343,752.72 0.26 2,724.19 MWD+SC+sag(3) 12/15/2014 5:11:10PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Project: Soldotna CK Unit TVD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Site: Soldotna CK Unit MD Reference: SCU 21C-04 @ 171.34usft(Saxon169(18+153.34)) Well: Soldotna CK Unit 33-05 North Reference: True Wellbore: SCU 21C-04 Survey Calculation Method: Minimum Curvature Design: SCU 21C-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°!100') (ft) Survey Tool Name 11,902.78 46.19 38.96 10,675.80 10,504.46 1,916.23 2,011.25 2,459,798.94 343,781.30 0.70 2,767.77MWD+SC+sag(3) 11,966.02 45.81 38.33 10,719.73 10,548.39 1,951.76 2,039.66 2,459,834.08 343,810.19 0.94 2,812.15 MWD+SC+sa9(3) 12,027.89 45.55 38.52 10,762.95 10,591.61 1,986.44 2,067.17 2,459,868.38 343,838.16 0.47 2,855.30 MWD+SC+sag(3) 12,053.86 45.65 37.93 10,781.12 10,609.78 2,001.01 2,078.65 2,459,882.81 343,849.84 1.67 2,873.38 MWD+SC+sag(3) 12,090.00 45.65 37.93 10,806.39 , 10,635.05 2,021.40 2,094.53 2,459,902.97 343,865.99 0.00 2,898.52 PROJECTED to TD °«ww+°+aac..m,o- Patrick Walker - Cary Taylor ' Checked By: .,.,,,,,.,mmW Approved By: ,a,.„„� Date: 12/15/2014 5:11:10PM Page 5 COMPASS 5000.1 Build 70 SCU 21C-04 MW Vs Depth 8000 SCU 21C-04 Plan SCU 21C-04 Final 8500 — 9000 9500 t 10000 a v 0 v v af0, 10500 2 11000 11500 ► __ 12000 12500 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) SCU 21C-04 Days Vs Depth 6500 -- SCU 21C-04 Actual SCU 21C-04 Plan 7500 8500 .44\ Y Q. v 9500 GJ (13 {) 10500 11500 12500 0 5 10 15 20 25 Days 11 Hitrorp Energy Company CASII :EMENTING REPORT Or Lease&Well No. SCU 21C-04 Date 7-Dec-14 County Kenai Peninsula Burough State Alaska Supv Rance Pederson/Jimmy Greco CASING RECORD TD 12090.00 Shoe Depth 12088 00 PBTD MD/'TVD Casing(Or Liner)Detail Setting Depths No of Jts Size Wt Grade THD Make Length Bottom Top Shoe 41/2 STL Wfd 1.61 12,088.00 12,086.39 2 41/2 12.6 L-80 DWC/C-HT 79.79 12,088.00 12,006.60 F.Collar 41/2 STL Wfd 1.36 12,006.60 12,005.24 1 41/2 2.6 L-80 DWC/C-HT 38.44 12,005.24 11,966.80 Landing collar 41/2 STL 1.02 11,966.80 11,965.78 107 jts 4 1/2 123.6 L-80 DWC/C-HT 4,135.78 7,873.52 11,927.00 LH/PKR 32.65 7,830.65 7,798.00 Running TOOL 4.40 7,798.00 7,793.60 Totals Csg Wt On Hook: 63,353 Type Float Collar Float No Hrs to Run 23 Csg Wt On Slips Type of Shoe' Bullnose Casing Crew. Wfd Fluid Description' 10 7 ppg 6%KCL/ PV=12 YP=21 HTHP=15.9 Liner hanger Info(Make/Model). HRD-E ZXPN PKR- Flex-Lock Liner Hanger Liner top Packer?. x Yes _No Liner hanger test pressure. 1000 Centralizer Placement centralizers on each joint in shoe track,and ever other joint in csg string Total of 58 centralizers ran CEMENTING REPORT Preflush(Spacer) Type. Mud Push II Density(ppg) 12 Volume pumped(BBLs) 40 Lead Slurry Type: EZBLOK Density(ppg) 15 3 Volume pumped(BBLs) 102 Mixing/Pumping Rate(bpm) 15.3 Tail Slurry Type. O Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Post Flush(Spacer) co F- u) Type Density(ppg) Rate(bpm)• Volume. re E Displacement: Type' 6%KCL Density(ppg) 10 7 Rate(bpm) 5 bpm Volume(actual/calculated). 167/167 FCP(psi) 1000 Pump used for disp: Schlumberger pump Plug Bumped? x Yes No Bump press 3500 Casing Rotated? Yes x No Reciprocated? x Yes _No %Returns during job 100 Cement returns to surface? Yes x No Spacer returns? x Yes No Vol to Surf: 2 bbl Cement In Place At 15 30 Date 12/7/2014 Estimated TOC• 10,384 Method Used To Determine TOC• Bond Logs Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 0) Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm). Volume w Displacement: 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. WELLHEAD Make Type Senal No. Size W.P. Test Head To PSIG MIN OK Remarks: 2„... kbot Seth Nolan Hilcorp Alaska, LLC r2--S 323 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 DATA LOGGED 11Jrur, tl.i ka.1.1.(. Fax: 907 777-8510 E-mail: snolan@hilcorp.com M.K•BEND DATE 01/23/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 21C-04 Digital Survey Data CD: SCU 21C-04 Survey LAS 121412014 9139 AM LAS File 11 KB SCU 21C-04 Survey Report 121412014 9144 AM PDF Document 21 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this trans eet f E T77.8337 1'1 11 Received B)oitaa.#14 o�y� Date: JAN 2 6 2015 AOGCC 214169 II Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 2 5 2 9 2 Tele: 907 777-8308 Irarurp ti,t4„1.1.1.i Fax: 907 777-8510 2 5 2 9 E-mail: snolan@hilcorp.com 3 DATE 01/20/15 RECEIVED JAN 2 2 2015 To: Alaska Oil & Gas Conservation Commission Makana Bender AOGCC Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 21-04 Elog and Mudlog prints and digital data Prints: 2"/5" ROP-DGR-EWR MD 2"/5" DGR-EWR TVD 2" FORMATION EVALUATION MD 5" FORMATION EVALUATION MD 2" DRILLING ENGINEERING MD 2" GAS RATIO MD CD1: Elog digital data ji CGM 12/17/2014 2:39 PM File folder ji DLIS+LAS 12/17/2014 2:39 PM File folder EMF 12/17/2014 2:39 PM File folder 61i PDF 12/17/2014 2:39 PM File folder I TIFF 12/17/2014 2:39 PM File folder CD2: Mudlog digital data 41, EMF Log Viewer 12115/2014 2:55 PM File folder jil Halliburton Log Viewer 121/5/2014 2:55 PM File folder ji SOLDOTNA CREEK UNIT21C-04 FINAL L... 12/15/2014 2:54 PM File folder bli SOLDOTNA CREEK UNIT 21C-04 LAS EXP... 12/15/2014 2:54 PM File folder El SCU 21C-04 FINAL END OF WELL REPORT 12/15/2014 2:15 PM PDF Document 2,934 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 (17)Received By: ALadzav6 - 4/Date: �� or rot �wAlaska Oil and Gas ��\I/� ' I'11L' S'1'A'1'1: ��► .�,� �„ of A L A.SKA Conservation Commission -#)t 333 West Seventh Avenue ,fir-�- - "-, Anchorage,Alaska 99501-3572 (,<►VERNt)R `1 BILL ALKFR Main:907.279.1433 � �y.p. Fax:907.276.7542 www.aogcc.alaska.gov Joe Kaiser Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 21C-04 Sundry Number: 314-661 Dear Mr. Kaiser: 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, r D avid J. Mayberry / Commissioner DATED this i Aday of December, 2014. Encl. RECEIVED STATE OF ALASKA . i t' ` ''? ALASKA OIL AND GAS CONSERVATION COMMISSION DQ"S t7_14 L id APPLICATION FOR SUNDRY APPROVALS A0000 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril 0 Perforate New Pod ❑ Repair Weill] Change Approved Program❑ Suspend❑ Plug Perforations 0 • Perforate 0 • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other: 0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 214-169 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service CI6.API Number: Anchorage,Alaska 99503 50-133-20276-02 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B • Soldotna Creek Unit(SCU)21 C-04 Will planned perforations require a spacing exception? Yes ❑ No 0❑ . 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996i f CDr( 0 . 7�2 /� '1L r At Swanson River/Hemlock Oil . 11• PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): 'Junk(measured): 12,090 10,806 11,965 10,719 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,32T 3,130psi 1, 580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner 4,290' 4-1/2" 12,088' 10,1105' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A WA Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A NIA;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratignphic❑ Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 12/15/14 Commencing Operations: Oil 0 Gas ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Kaiser Phone: 907-777-8393 Email jkaisertathilcorD.com Printed Name Joe Kaiser Title Operations Engineer Signatures ' ,,,, f Phone 907-777-8393 Date /Z A7'; COMMISSION USE ONLY Condit* ns of approval: Notify Commission so that a representative may witness Sundry Number. 3`-4— CQLIZ` Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: �/ r = (, c�{�k (Cf) Spacing Exception Required? Yes ❑ No L Subsequent Form Required: %Q - `i(-7 t. C/"^ APPROVED BY Approved by: ......M9 COMMISSIONER THE COMMISSION Date: (74)oil Form 1 -403 ise of i4,141„N,Actio:12 months from the date of a Submit Form and R$C,S or tfi 22 p pprovall. ��/� Aria ments in Duplicate f1/t1 ( �id�--C�?` 'Y(y /y./d // Well Prognosis Well: SCU 21C-04 llileorp Alaska,LL Date: 12/09/2014 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: New Sidetrack Leg: N/A Estimated Start Date: December 15th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Joe Kaiser (907) 777-8393(0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 0 psi @ 10,600' TVD (No open perforations) Maximum Expected BHP: —2,756 psi @ 10,600' TVD (Based on offset wells, 0.26 psi/ft grad) Max. Allowable Surface Pressure: — 1,696 psi (Based on gas gradient of 0.10 psi/ft.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated.A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench. The well has had limited productivity since this workover(approximately 1 bopd on gaslift).The well was plugged back and sidetracked as SCU 44-05 in April 2014. Following the sidetrack of this well, the completion was ran with the Aurora AWS#1 in June 2014, completed in the Hemlock H-11 and H-12.These zones were shown to be wet and non-productive. The H-11 and H-12 were plugged back with a thru-tubing plug in June 2014. This plug was leaking and a 2nd thru-tubing plug was set in July 2014. A gaslift survey run in July 2014 found the zone to be damaged with limited fluid influx. The well was re-perforated in the Hemlock H-1 thru H-3 in August and September 2014 with a minimal increase in flow.The well was plugged back in November 2014 with the Saxon #169 rig and sidetracked as SCU 21C-04. The purpose of this work/sundry is to perform the initial perforation of this well. Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 2. RIH and pull dummy valves from each gaslift mandrel (7 mandrels). POOH. 3. RIH and pull dummy valve from the chemical injection mandrel. POOH. 4. RIH and set live valve in chemical injection mandrel. POOH. a. Set spring pressure to 3,000 psi. 5. RIH and set live valves in each gaslift mandrel (7 mandrels). POOH. 6. RIH and pull RHBC plug body from X-profile. POOH. 7. RIH w/ 1.75"x20' dummy gun to PBTD. E-line Procedure: 8. Rig up gas lift lines to tree. Production to gaslift off top of well to achieve desired underbalance. a. Est BHP= 2,756 psi. Est hydrostatic = 2,100 psi. (Fluid level at GLM #5 at 6,750' MD and SITP of 400 psi) 9. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 10. RU 1-11/16" " 6 spf HC wireline guns ( 6 spf shot density). Well Prognosis Well: SCU 21C-04 Ilileora Alaska,LU Date:12/09/2014 11. Bleed tubing pressure down to below 400 psi, as directed by Reservoir Engineer. 12. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Hemlock H-1 11,365' 11,400' 35 6 Hemlock H-2 11,433' 11,455' 22 6 Hemlock H-3 11,476' 11,494' 18 6 Hemlock H-3 11,508' 11,543' 35 6 Hemlock H-6 11,772' 11,787' 15 6 Hemlock H-6 11,794' 11,798' 4 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using proposed Cement Bond log. (Tie-in log depth is pending). d. Record tubing pressures before and after each perforating run. 13. RD E-line. 14. Turn well over to production. E-line Procedure(Contingency): 1. If any zone produces sand and/or water. 2. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. b. SITP will be+/-400 psi (remaining gas lift). 3. RIH and set 4-1/2"thru tubing plug at depth above zone. Attachments: 1. Proposed Schematic �Y SCU 21C-04 Swanson River Unit Well SCU 21C-04 Proposed Schematic Completion: Proposed Ilikora Alaska,LLC RKB: 171.34'/GL:153.34'AMSI, CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" 1L Conductor 20" - - - Surf 44' 44' 2 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' Production 7_5/8" 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 3k 1.1 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,798' 12,088' 10-3/4 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf _ 7,750' CBL TOC {I , Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,750' 11,320' 4,240' $y• +a JEWELRY DETAIL No. Depth ID OD Item ' 5 41111111, I 1 19.28' 2.992" Tubing Hanger,3-1/2"8RD Box x Box 2 19.75' 2.441" 3.668" XO,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 • 3 2,750' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Dummy) 7,798' iff 4 4,950' 2.441" 4.750" 2-7/8"SFO-1 GLM#6(Dummy) •a r •+ 5 6,750' 2.441" 4.750" 2-7/8"SFO-1 GLM#5(Dummy) 6'o; g '° 6 7,750' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD 7 8,100' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Dummy) 7-5/8" 4,,r 8 9,270' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Dummy) 7,993' 7 ! , 9 10,190' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Dummy) I A` 10 11,150' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Dummy) 11 11,190' 1.990" 3.750" Chemical Injection Mandrel(Dummy) 8 12 11,250' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(30k to release) s 13 11,290' 1.875" 3.063" X-Nipple CBL(EST) fa 14 11,320' 1.995" 3.063" WL Entry Guide 10,000' 9 .t) 1•' 10 I 1 PERFORATION DETAIL '• 4 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 1I P Proposed H-1 11,365' 11,400' 10,311' 10,334' 6 35 60 1-11/16"HC I I 2 Proposed H-3 11,476' 11,494' 10,385' 10,397' 6 18 60 1-11/16"HC 12 = Proposed H-3 11,508' 11,543' 10,407' 10,430' 6 35 60 1-11/16"HC Proposed H-6 11,772' 11,787' 10,58x' 10,596' 6 15 60 1-11/16"HC Proposed H-6 11,794' 11,798' 10,600' 10,604' 6 4 60 1-11/16"HC , s RA Mrk Jt g7, GLV Port Temp ci 11-1 Size Depth TCF PSC PSO PTRO Description t'' 2 7 16 122 0.878 1241 1400 1385 IPOR-1/1POC-1/PPOR-1 6 16 148 0.835 1216 1341 1345 IPOR-111P0C-1/PPOR-1 / 5 16 169 0.804 1191 1280 1315 IPOR-1/1P0C-11PPOR-1 �� A H-3 Contingency t/ 4 16 184 0.783 1166 1226 1290 IPOR-1/IPOC-11PPOR-1 Thru-Tubing Plugs 3 16 194 0.770 1141 1177 1265 IPOR-1/IPOC-1IPPOR-1 RA Mrk Jt• 2 16 199 0.763 1116 1124 1245 IPOR-1/IPOC-11PPOR-1 1 20 200 0.762 I ORIFICE-1 RA Mrk Jt i • • -` l I-a Short RA Marker Joints WELL DATA @ 11,350'-11,364'MD PTD:214-169 RA Mrk Jt "' @ 11,601'-11,615'MD API: 50-133-20276-02 , @ 11,696'-11,710'MD Lease: FEDA-028996 4-1/2" ' •• @ 11,913'-11,927 MD Spud Date:11/22/2014 12,088' `" ,y" Tree cxn: 3.5"Bowen TD=12,090' PB•I'D=11,965' Lift Threads: 3-1/2"8RD MAX HOLE ANGLE=58°(a;9,408' SCU 21C-04 Proposed Schematic 12-09-14 Updated by STP 12/09/14 �.•,or Tod Alaska Oil and Gas 4,�',"�\\�//y�s �11Ih STATE ? 'J— +M (ALASKA Conservation Commission 0114----,_-_-_-_t_-_,; _ _ ___ _ 333 West Seventh Avenue Anchorage,Alaska 99501-3572 (1+i\'ERN{�1-4 FII 1, \��'ALKl 14 Main:907.279.1433 O p. Fax:907.276.7542 ALAtswww.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 21C-04 Sundry Number: 314-657 Dear Mr. Porhola: 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, ----4ef. Cathy P. Foerster Chair DATED thiseay of December, 2014. Encl. RECEIVED ' STATE OF ALASKA DEC 0 8 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION tZ. 9 1 ( 9— 0�-1 APPLICATION FOR SUNDRY APPROVALS AOGCC 17-1 ct i)Li 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Weil❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other: Run Completion ❑., . 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 . 214-169 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20276-02 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)21C-04. Will planned perforations require a spacing exception? Yes [11 No No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 Swanson River/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,090 10,806 11,990 10,736 N/A N/A Casing Length Size MD 1VD Burst Collapse Structural Conductor 44' 20" 44' 44' - Surface 3,372' 10-3/4" 3,327' 3,327' 3,130psi 1,580psi Intermediate Production 7,993' 7-5/8" 7,993' 7,990' 6,020psi 3,400psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: . Detailed Operations Program [l BOP Sketch n Exploratory n Stratigraphicri Development ] Service [f 14.Estimated Date for 15.Well Status after prorosed work: Commencing Operations: 12/07/14 Oil Q . Gas ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: 12/5/2014 ✓ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Guy Schwartz GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole' Phone: 907-777-8412 Email soorholaffihilcorD.coft1 Printed Name Stan Porhola� Title Operations Engineer Signature „.\441C. / 0 Phone 907-777-8412 Date 41/i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\I—k- (IQ S7 Plug Integrity ❑ BOP Test EK Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,1 S Sc C /�S. 6,-,7 (114,4s ( 7 I /Zf( f'a`) .,_A__L—L e(crt [le' -6',r--,---f;cri----..—- f —7 /r 1),K .0 4,1,i— )Spacing Exception Required? Yes ❑ No R Subsequent Form Required: `r 1 - LIZ: 7� ( APPROVED BY Approved by: 6' COMMISSIONER THE COMMISSION Date: 2., 5_ j ' i �iy i � Submit Form and For,10-403 Revis o/201 DR, i AIL12 months from the date of approval. Attachme sin Duplicate RBCMS DEC 102014 ��� ,L �`>/ Well Prognosis—rev2 Well: SCU 21C-04 LL Date: 12/05/2014 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: New Sidetrack Leg: N/A Estimated Start Date: December 7th, 2014 Rig: N/A Reg.Approval Req'd? 401 (supplement) Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: Current Bottom Hole Pressure: —2,810 psi @ 10,806' TVD (Based on offset wells, 0.26 psi/ft grad) Maximum Expected BHP: 2,810 psi @ 10,806' TVD (Based on offset wells, 0.26 psi/ft grad) Max. Allowable Surface Pressure: — 1,729 psi (Based on gas gradient of 0.10 psi/ft.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05.A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated. A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench.The well has had limited productivity since this workover(approximately 1 bopd on gaslift). The well was plugged back and sidetracked as SCU 44-05 in April 2014. Following the sidetrack of this well,the completion was ran with the Aurora AWS#1 in June 2014, completed in the Hemlock H-11 and H-12.These zones were shown to be wet and non-productive.The H-11 and H-12 were plugged back with a thru-tubing plug in June 2014.This plug was leaking and a 2nd thru-tubing plug was set in July 2014. A gaslift survey run in July 2014 found the zone to be damaged with limited fluid influx.The well was re-perforated in the Hemlock H-1 thru H-3 in August and September 2014 with a minimal increase in flow.The well was plugged back in November 2014 with the Saxon #169 rig and sidetracked as SCU 21C-04. The purpose of this work/sundry is to run the completion with the drilling rig as a continuation of the drilling permit application. Notes Regarding Wellbore Condition • Well TD'd at 12,090' MD(10,806'TVD). Preparing to run 4-1/2" liner. WO Rig Procedure: 1. ***Continue from Step 16.22 in PTD 214-169/APD*** 2. Change out rams to 2-3/8" pipe rams. RU 2-3/8" test joint. 3. Perform BOPE test of 2-3/8" rams. Test to 250 psi Low/3,500 psi High, annular to 250 psi Low/ 1,500 psi High (test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. 4. PU 3-1/4" mill and 4-1/2" casing scraper on 2-3/8"Tbg and X0 to 4-1/2" DP and 7-5/8" Casing Scraper. 5. RIH w/3-1/4" mill to +/-30' above landing collar. 6. RU and pressure test liner lap to 3,000psi for 30 min and chart. 7. RIH to tag liner top at+/- 7,793' with 7-5/8" casing scraper. a. Setup BHA to have 3-1/4" mill to +/- 30' above landing collar. 8. Circ 75 bbl chem wash (25 bbl caustic, 25 bbl surfactant, 25 bbl hi-vis pill). Well Prognosis—rev2 Well: SCU 21C-04 Hilcorp Alaska,LL Date: 12/05/2014 9. Circulate well clean w/3% KCI fluid (filter fluid going downhole). 10. POOH. LD 3-1/4" mill,4-1/2" Casing Scraper, 7-5/8" Casing Scraper. a. Rack back the 2-3/8" tubing. 11. MIRU E-line. 12. RIH and run cement bond log from PBTD to 7,700' MD. 13. RD E-line. 14. Change out rams to 2-7/8" pipe rams. RU 2-7/8" test joint. 15. Perform BOPE test of 2-7/8" rams.Test to 250 psi Low/3,500 psi High, annular to 250 psi Low/ 1,500 psi High (test for 10-min). Record accumulator pre-charge pressures and chart tests. c. Notify AOGCC 24 hrs in advance to witness. d. Notify BLM 48 hrs in advance of BOP test. 16. PU 2-3/8" completion jewelry and 4-1/2" hydraulic packer and RIH. 17. PU 2-7/8" completion jewelry and 2-7/8"tubing and RIH and set packer at+/- 11,250' MD. a. Leave tubing tail to land 30' above proposed top perf at+/- 11,350' MD. b. Use conventional bands to secure chemical injection line to tubing. c. Space out Gaslift Mandrels per proposed schematic. d. Run dummy valves in all Gaslift Mandrels. e. Run dummy valve in Chemical Injection Mandrel. 18. MIRU Slickline. 19. RIH w/1.75"x20' dummy gun to PBTD. a. Maximum deviation is 58°. 20. RIH and set RHCP plug body in X-profile. 21. RIH and set RHCP ball and rod. Keep setting tools latched. 22. Pressure up to 3,500 psi and set hydraulic packer. 23. Test tubing to 3,500 psi for 30 min and chart. 24. Pull RHCP ball and rod. RD Slickline. 25. Test casing to 3,000 psi for 30 min and chart. (I M Ir-/,) 26. Lay down landing joint. Set BPV. ND BOPE. NU tree. Pull BPV. 27. Set TWC. Test hanger to 250/3,500 psi.Test tree to 250/5,000 psi. Pull TWC. 28. RD Saxon#169 Drlg Rig. 29. Turn well over to production in preparation of moving off the Saxon #169 Drlg Rig. 30. Replace IA x OA pressure gauge if removed (7-5/8" x 11-3/4"). 31. ***Remaining completion work to be submitted under new sundry(perf thru-tubing)*** Attachments: 1. Proposed Schematic 2. BOPE Schematic SCU 21C-04 WeSwansonllSCU River21C04 Unit Proposed Schematic Completion: Proposed IMITHileorp RKB:171.34'/GL:15334'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20" 1 Conductor 20" - - Surf 44' 44' 2 LSurface 10-3/4" 40.5 _ K-55 BTC 10.050" Surf _ 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' Production 7-5/8" 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 31 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,793' 12,090' 1,374" 3,372' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,750' CBL TOC a 4 017 Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,750' 11,320' 4,240' ; ° JEWELRY DETAIL VA L,0 "O No. Depth ID OD Item 5 1 19.28' 2.992" Tubing Hanger,3-1/2"8RD Box x Box },�. 7,4 2 19.75' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL }, "" 6 +� N, 3 2,750' 2.441" 4.750" 2-7/8"SFO-1 GLM#7(Dummy) 7793' 9, a 4 4,950' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Dummy) - i P.(. ` 5 6,750 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Dummy) Ua, 6 7,750' 1.995" 3.063" _ X0,2-7/8"8RD x 2-3/8"8RD a 7 8,100' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Dummy) 7-5/8" A 4" 8 9,270' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Dummy) 7,993' ',, 7 Mill 9 10,550' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Dummy) 10 11,150' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Dummy) 'i 11 11,190' _ 1.990" 3.750" Chemical Injection Mandrel(Dummy) 11, 8 MN 12 11,250' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(30k to release) i� 13 11,290' 1.875" 3.063" . X-Nipple CBL(EST) t-'' 14 11,320' 1.995" 3.063" WL Entry Guide 10,000' I 9IMO ' ' 10_ 2 PERFORATION DETAIL dTi Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments e' y, 11M 4 "X r I I ` I 12yy ;r 4 4141,0 13 X ;r 14 illik 0, iii GL's.' Port Temp C r # Size Depth TCF PSC PSO PTRO Description yt 7 16 93 0.931 1244 1400 1475 IPOR-1/IPOC-1/PPOR-1 `4 6 16 110 0199 1219 1343 1470 IPOR-1/IPOC-1/PPOR-1 y 5 16 132 0-861 1194 1281 1440 IPOR-111P0C-1/PPOR-1 .i, 4 16 150 0.832 1169 1228 1410 IPOR-1/IPOC-1/PPOR-1 ft: tat' 3 16 161 0.816 1144 1178 1390 IPOR-1/1POC-1/PPOR-1 OA 2 16 167 0.807 1119 1144 1375 IPOR-1/IPOC-1/PPOR-1 r 1 16 172 0.800 ORIFICE-1 WELL DATA VV, Mt PTD:214-169 , ;r, API: 50-133-20276-02 Lease: FEDA-028996 41/2" . .yx - fir% Spud Date:11/22/2014 12,090' , Tree cxn: 3.5"Bowen TD=12,090' PBTD=11,990' Lift Threads: 3-1/2"8RD MAX HOLE ANGLE=58°@ 9,408' SCU 21C-04 Proposed Schematic 12-05-14 Updated by STP 12/05/14 , ti SCU 21C-04 Completion Procedure Rev 0 1111.4,1i, %11.1.1 I H - BOPE Schematic • 1 Y _ _ iii III it' 18i 181 iii 181l 181 ni ModetbOUL r. ,I i11i1 1i1 NI Iii Mil — 2-7/8"x 5"VBR - Am, 0 1 3 therm, - - t:, Mode 170151' �. —4. I 1fl 11 5000 Il I-i 11"Blind 181 1811111 III III ' I !IC) 1 1.181 Ii1 III tit NA 2 1/16 SM Kill Side IIII 1/8 5M Choke Side 141 I1: T3 y ,. — 2-3/8"Pipe Ram w rr_ y�.r _ ill 101 191 Ili 1111 Grade 1a1 Ii1 la 1l1 IU 11.11111.11112 ks r..! 4.1Wrat :074"‘ (.1 1111 IL SIN- O W: ai min 1 iL Revision 0 October,2014 II ` SCU 21C-04 Completion Procedure Rev 0 Ililrorp,Ual.ka,1.I.0 - - Choke Manifold Schematic 67 24 6142 I 4362 n,. S • ,�� tlq KUei i •.6: -_-._... •e.4, ltd : 0.19 - -at! �i!/ _ r 0f9- - 9, 0141118 0 10 40 leo Ma r0.,9 -. o,9 Al � 019-C6��fetli I. 0 _ ,•�a r 9.,151 1i1LI °° .1 f\;` ,� i 9.. _ I 0.,1 _._- ©' 6 4 a,I.111n»f 0.1•J I 1,•� .0 019J 7.61 01117 �' J 4 ! 9.64 a HNMI 7.64 10.19 --1 al«' . -- 1 I IMS ., i• I 0.19) .116 1 r!!1 .1.• o.,9J ..,i 'c .620.11j'`• 7, Saw 11.62 .' "^ 14.62 '71P7 110i ikdi. - 11.62 k mu_ A. r0,9 0.19J 16.130 a . i .. it . •1 t•.. i - 1 '0.150 limist teem -0.19 } 42 CHOKE 10 -0.19 -0.19 019-- - _ WVUAL 0.19 -0.19 OPERA1ON —6.31 —14.62 —14.62— 14.62 14.62 —6.31 PAI ,,• 4162 4162 G"441, 6734-- [y_ 6t0OL. {J-.E1- ___ _,rr.r r� i.LAYOUT MN 6 64.3¢16 :Ili'? C K.Fc ..Y rir O (;........' �E--- `ti t� �ti � m�in'ruo `ti Vii., -✓ - Revision 0 October, 2014 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, December 05, 2014 4:13 PM To: 'Stan Porhola' Cc: Monty Myers; Rance Pederson - (C);Jerrod Rose - (C) Subject: RE:SCU 21C-04 (PTD 214-169)verbal approval request to run tubing Stan, I have reviewed the procedure submitted. No issues with running the tubing as proposed. Well should be hydraulically isolated from reservoir after 4 1/2 liner is set but make sure you have ram coverage for each size of pipe you are running. You have verbal approval to run tubing as proposed... submit formal sundry as soon as possible on Monday. Guy Schwartz Senior 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: Stan Porhola [mailto:sporhola@ahilcorp.com] Sent: Friday, December 05, 2014 3:56 PM To: Schwartz, Guy L(DOA) Cc: Monty Myers; Rance Pederson - (C); Jerrod Rose- (C) Subject: SCU 21C-04(PTD 214-169)verbal approval request to run tubing Guy, Per our conversation, I have updated the procedure to reflect the 3,500 psi BOPE test for running tubing in SCU 21C-04 (PTD 214-169). Requesting verbal approval to start this work with a sundry to follow up on Monday, 12/08. Regards, Stan Porhola I Operations Engineer Kenai Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, December 05, 2014 4:13 PM To: 'Stan Porhola' Cc: Monty Myers; Rance Pederson - (C);Jerrod Rose- (C) Subject: RE: SCU 21C-04 (PTD 214-169)verbal approval request to run tubing Stan, I have reviewed the procedure submitted. No issues with running the tubing as proposed. Well should be hydraulically isolated from reservoir after 4%z liner is set but make sure you have ram coverage for each size of pipe you are running. You have verbal approval to run tubing as proposed... submit formal sundry as soon as possible on Monday. Guy Schwartz Senior 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: Stan Porhola [mailto:sporhola@hilcoro.com] Sent: Friday, December 05, 2014 3:56 PM To: Schwartz, Guy L(DOA) Cc: Monty Myers; Rance Pederson - (C); Jerrod Rose - (C) Subject: SCU 21C-04 (PTD 214-169) verbal approval request to run tubing Guy, Per our conversation, I have updated the procedure to reflect the 3,500 psi BOPE test for running tubing in SCU 21C-04 (PTD 214-169). Requesting verbal approval to start this work with a sundryto follow upon Monday, 12/08. q g PP Regards, Stan Porhola j Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 1 Well Prognosis Well: SCU 21C-04 Hilcor')Alaska.LI: Date: 12/05/2014 Well Name: SCU 21C-04 API Number: 50-133-20276-02 Current Status: New Sidetrack Leg: N/A Estimated Start Date: December 7th, 2014 Rig: N/A Reg.Approval Req'd? 401 (supplement) Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-169 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: Current Bottom Hole Pressure: —2,810 psi @ 10,806' ND (Based on offset wells, 0.26 psi/ft grad) Maximum Expected BHP: —2,810 psi @ 10,806'TVD (Based on offset wells, 0.26 psi/ft grad) Max. Allowable Surface Pressure: — 1,729 psi (Based on gas gradient of 0.10 psi/ft.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated.A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench.The well has had limited productivity since this workover(approximately 1 bopd on gaslift).The well was plugged back and sidetracked as SCU 44-05 in April 2014. Following the sidetrack of this well,the completion was ran with the Aurora AWS#1 in June 2014,completed in the Hemlock H-11 and H-12.These zones were shown to be wet and non-productive.The H-11 and H-12 were plugged back with a thru-tubing plug in June 2014.This plug was leaking and a 2nd thru-tubing plug was set in July 2014. A gaslift survey run in July 2014 found the zone to be damaged with limited fluid influx.The well was re-perforated in the Hemlock H-1 thru H-3 in August and September 2014 with a minimal increase in flow.The well was plugged back in November 2014 with the Saxon #169 rig and sidetracked as SCU 21C-04. The purpose of this work/sundry is to run the completion with the drilling rig as a continuation of the drilling permit application. Notes Regarding Wellbore Condition • Well TD'd at 12,090' MD (10,806'TVD). Preparing to run 4-1/2" liner. WO Rig Procedure: 1. ***Continue from Step 16.22 in PTD 214-169/APD*** 2. Change out rams to 2-3/8" pipe rams. RU 2-3/8" test joint. .,Sc° 3. Perform BOPE test of 2-3/8" rams.Test to 250 psi Low/3,000-psi High, annular to 250 psi Low/ 1,500 psi High (test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. 4. PU 3-1/4" mill and 4-1/2" casing scraper on 2-3/8"Tbg and X0 to 4-1/2" DP and 7-5/8" Casing Scraper. 5. RIH w/3-1/4" mill to+/-30' above landing collar. 6. RU and pressure test liner lap to 3,000 psi for 30 min and chart. 7. RIH to tag liner top at+/-7,793'with 7-5/8" casing scraper. a. Setup BHA to have 3-1/4" mill to+/-30' above landing collar. 8. Circ 75 bbl chem wash (25 bbl caustic, 25 bbl surfactant, 25 bbl hi-vis pill). Well Prognosis Well: SCU 21C-04 Hilcora Alaska,LL Date: 12/05/2014 9. Circulate well clean w/3%KCI fluid (filter fluid going downhole). 10. POOH. LD 3-1/4" mill,4-1/2" Casing Scraper, 7-5/8" Casing Scraper. a. Rack back the 2-3/8"tubing. 11. MIRU E-line. 12. RIH and run cement bond log from PBTD to 7,700' MD. 13. RD E-line. 14. Change out rams to 2-7/8" pipe rams. RU 2-7/8"test joint. 15. Perform BOPE test of 2-7/8" rams. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/ 1,500 psi High (test for 10-min). Record accumulator pre-charge pressures and chart tests. c. Notify AOGCC 24 hrs in advance to witness. d. Notify BLM 48 hrs in advance of BOP test. 16. PU 2-3/8" completion jewelry and 4-1/2" hydraulic packer and RIH. 17. PU 2-7/8" completion jewelry and 2-7/8" tubing and RIH and set packer at+/- 11,250' MD. a. Leave tubing tail to land 30' above proposed top perf at+/- 11,350' MD. b. Use conventional bands to secure chemical injection line to tubing. c. Space out Gaslift Mandrels per proposed schematic. d. Run dummy valves in all Gaslift Mandrels. e. Run dummy valve in Chemical Injection Mandrel. 18. MIRU Slickline. 19. RIH w/ 1.75"x20'dummy gun to PBTD. a. Maximum deviation is 58°. 20. RIH and set RHCP plug body in X-profile. 21. RIH and set RHCP ball and rod. Keep setting tools latched. 22. Pressure up to 3,500 psi and set hydraulic packer. 23. Test tubing to 3,500 psi for 30 min and chart. 24. Pull RHCP ball and rod. RD Slickline. KHC P fi� 25. Test casing to 3,000 psi for 30 min and chart. 26. Lay down landing joint. Set BPV. ND BOPE. NU tree. Pull BPV. 27. Set TWC.Test hanger to 250/3,500 psi.Test tree to 250/5,000 psi. Pull TWC. 28. RD Saxon#169 Drlg Rig. 29. Turn well over to production in preparation of moving off the Saxon#169 DrIg Rig. 30. Replace IA x OA pressure gauge if removed (7-5/8" x 11-3/4"). 31. ***Remaining completion work to be submitted under new sundry(perf thru-tubing)*** Attachments: 1. Proposed Schematic Swanson River Unit SCU 21C-04 Well SCU 21C-04 Proposed Schematic Completion: Proposed H iiii;„: II Hilcorp Alaska,LLC RKB:171.34'/GL:153.34'AMSL CASING DETAIL KB—THF:18.0' Type Size WT Grade Conn ID Top Btm. 20., I 1I l i Conductor 20" - - - - Surf 44' 44' J \ L Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' Production 7_5/8" 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 5-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 7,993' 31-1) Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 7,793' 12,090' , 3372' TUBING DETAIL 3,372' Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 7,750' CBL TOC 4 I ill Tubing 2-3/8" 4.7 L-80 8RD 1.995" 7,750' 11,320' 4,240' JEWELRY DETAIL No. Depth ID OD Item 5 I—lil 1 19.28' 2.992" - Tubing Hanger,3-1/2"8RD Box x Box 2 19.75' 2.441" 3.668" X0,3-1/2"8RD Pin x 2-7/8"8RD Box TOL 6 / 3 2,750' 2.441" 4.750" 2-7/8"SF0-1 GLM#7(Dummy) 7,793' 4 4,950' 2.441" 4.750" 2-7/8"SF0-1 GLM#6(Dummy) ^w 5 6,750' 2.441" 4.750" 2-7/8"SF0-1 GLM#5(Dummy) ®,,' 66 7,750' 1.995" 3.063" X0,2-7/8"8RD x 2-3/8"8RD a 7 8,100' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#4(T-1 latch)(Dummy) 7-5/8" 8 9,270' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#3(T-1 latch)(Dummy) 7,993' . 7 F 9 9 10,550' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#2(T-1 latch)(Dummy) ',' 10 11,150' 1.990" 3.750" 2-3/8"GLMAX-1 GLM#1(T-1 latch)(Dummy) A. 11 11,190' 1.990" 3.750" Chemical Injection Mandrel(Dummy) 8r v 4. 12 11,250' 1.940" 3.750" Halliburton G-77 Hydraulic Packer(30k to release) pl. 13 11,290' 1.875" 3.063" X-Nipple rt 14 11,320' 1.995" 3.063" WL Entry Guide CBL(EST) 10,000' • itl PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 11 r-- . 12 • 13 x 14 GLV Port Temp @ A Size Depth TCF PSC PSO PTRO Description 7 16 93 0.931 1244 1400 1475 IPOR-11IPOC-1/PPOR-1 6 16 110 0.899 1219 1343 1470 IPOR-1/IPOC-1;PPOR-1 5 16 132 0-861 1194 1281 1440 IPOR-1:IPOC-1/PPOR-1 4 16 150 0.832 1169 1228 1410 IPOR-1;IPOC-1/PPOR-1 3 16 161 0.816 1144 1178 1390 IPOR-1'IPOC-1/PPOR-1 2 16 167 0.807 1119 1144 1375 IPOR-1;IPOC-1 IPPOR-1 1 16 172 0-800 ORIFICE-1 WELL DATA PTD:214-169 API: 50-133-20276-02 ' Lease: FEDA-028996 412" Spud Date:11/22/2014 12,090' , Tree cxn: 3.5"Bowen TD=12,090' PBT1)=11,990' Lift Threads: 3-1/2"8RD MAX HOLE ANGLE=58°(sr- 9,408' SCU 21C-04 Proposed Schematic 12-05-14.doc Updated by STP 12/05/14 %ti THE STATE , 1--25,, E; Ii,. 333 Wes! Severin AvEnte ( OVER` OR SEAN P.ARNFLI anchorage Alc,s/a 99KI-3572 9n7 779 1 ?' Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Pool, SCU 21C-04 Hilcorp Alaska, LLC Permit No: 214-169 Surface Location: 3323' FNL, 571' FEL, SEC. 5, T7N, R9W, SM, AK Bottomhole Location: 1372' FNL, 1475' FWL, SEC. 4, T7N, R9W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to re-drill the above referenced development 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 applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this / day of November, 2014. ;, b ,5 s,K, , '—nisi ,'. ,,.! STATE OF ALASKA A OIL AND GAS CONSERVATION COMA )N ij;'? I g) t1:-1 PERMIT TO DRILL 20 AAC 25.005 rs-\(,,)c:LeC la.Type of Work. 1 b.Proposed Well Class: Development-Oil 0• Service- Wind 0 Single Zone 0 . 1 c.Specify if well is proposed for. Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas 0 Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Redril 0, Reentry 0 Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No 022035244 • Soldotna Creek Unit(SCU)21C-04 • (SCU 44-05 ST) 3.Address: 6.Proposed Depth: 12.Field/Pool(s). 3800 Centerpoint Drive,Anchorage AK 99503 MD: 12000 TVD. 10762 Hemlock 4a. Location of Well(Governmental Section). 7.Property Designation(Lease Number): 7� Surface. 3323'FNL,571'FEL,Sec 5,T7N,R9W,SM,AK • r p A028996 7 �L c?/� t Hti` J / r/,c+ S? /Z Top of Productive Horizon: 8.Land Use Permit. 13.Approximate Spud Date: 1691'FNL,1205'FWL,Sec 4,T7N,R9W,SM,AK NA(SRF Soldotna Creek Unit) 11/17/2014 Total Depth. 9 Acres in Property. 14.Distance to Nearest Property: 1372'FNL,1475'FWL,Sec 4,T7N,R9W,SM,AK A028996-1,000 Unit Acres 4,601'FWL(Unit Boundary) 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: f 7 J_1 et 15 Distance to Nearest Well Open Surface. x-341744.448 • y- 2457909.946 • Zone-4 GL Elevation above MSL:/,4-3 3 f et to Sam Pool: 1,860ft , '•i7./ 16.Deviated wells: Kickoff depth' 8,035' feet 17.Maximum Anticipated Pressures in pg g(see 20 AAC 25.035) Maximum Hole Angle: 60 degrees Downhole: 2800 • Surface: 1695 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) 6-1/8" 4-1/2" 12.6 L-80 DWC/C 4165 7835 7835 12000 10762 474 sxs 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): 10,870 10,760 NA 10,827 10,723 NA Casing - Length Size Cement Volume MD TVD Conductor/Structural 44' 20" none 44' 44' Surface 3372' 10-3/4" 1035 sks G cmt 3,327' 3,327' Intermediate Production 10585' 7-5/8" 645 sks G cmt 10,585' 10,510' Liner 9173' 4-1/2" 330 sks 10,923' 9,173' Perforation Depth MD(ft): See attached schematic Perforation Depth TVD(ft): See attached schematic 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date !o• ICJ ' L o 14 22. I hereby certify that the foregoing is true and correct. Monty M Myers Contact mmyers@hilcorp.com Email Printed Name Monty Mack Myers Title Drilling Engineer Signature �` ..... ....5 Phone 907-777-8431 Date 10/10/2014 Commission Use Only Permit to Drill ^� `/ / API Number: �?,O� Permit Approval See cover letter for other Number. 2�`� /�� 50-1, "lY -6ZYZiDate: I i 11 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: [G Other: •i j Set ( j," S0 r 7735 /- Samples req'd. Yes 0 No© Mud log req'd.Yes Nod H25 measures: Yes❑ No[ Directional svy req'd.Yes f. 'No❑ Spacing exception req'd. Yes❑ No le Inclination-only svy req'd.Yes❑ No Er Ay - V APPROVED BY 1I ' ( I& Approved by: COMMISSIONER THE COMMISSION Date. l Submit Form and Form 10-401(Reviss`eed 10/2012)z. t�'°�' i ff°(2hminths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Y`` / - • r`l Ri V� I V A L -' 797.2,7(7' -4-1S ,". ;ti RECEIVED OCT 102014 Monty Myers Hilcorp Alaska, LLC AUG CC Hilcorp Drilling Engineer P.O. Box 244027 �14J e ilcorp Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com 10/10/14 Commissioner Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage,Alaska 99501 Re: SCU 21C-04(SCU 44-05 ST) Dear Commissioner, Please find enclosed the 10-401 Application for Permit to Drill for the SCU 21C-04. SCU 21C-04 is a development oil well planned to be re-drilled in a Northeasterly direction from SCU 44-05 utilizing the existing casing program down to 8035' MD / 8032' TVD. At 8035' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 3965' x 6-1/8" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated based on LWD data obtained while drilling the interval. The well will be completed with a gas lift assembly on 3-1/2" production tubing. Drilling operations are expected to commence approximately November 17th, 2014. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack. General sequence of operations pertaining to this approved drilling procedure: • MOB Saxon Rig#169 to SCU 21C-04, NU and test BOPE (5 days) • Perform clean out run to plug (-8055')and test casing. Displace to mud. (1 day) • Set Whipstock, mill 6.625"window at 8035'. Perform FIT to 12.5 ppg (2 Days) • Drill 6-1/8" production hole from 8035'to 12000' MD. (6 Days) • Perform short trip and condition mud. POOH (1 day) • LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. (1 Days) • POOH, laying down DP and liner running tools, ND BOPE(1 day) • RDMO (1 Day) If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC SCU 21C-04 (SCU 44-05 ST) Drilling Program Soldotna Creek ro d by: M My Revision 0 October 10, 2014 SCU 21C-04 Drilling Procedure Rev 0 flilaorp Alaska,1;1.1: Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 BOP N/U and Test 12 11.0 Mud Program and Density Selection Criteria 13 12.0 Whipstock Running Procedure 14 13.0 Whipstock Setting Procedure: 17 14.0 Drill 6-1/8"Hole Section 19 15.0 Run 4.5"Production Casing 22 16.0 Cement 4.5"Production Casing 25 17.0 RDMO 28 18.0 BOP Schematic 29 19.0 Wellhead Schematic 30 20.0 Days vs Depth 31 21.0 Geo-Prog 32 22.0 Anticipated Drilling Hazards 33 23.0 Rig Layout 34 24.0 FIT Procedure 35 25.0 Choke Manifold Schematic 36 26.0 Casing Design Information 37 27.0 6-1/8"Hole Section MASP 38 28.0 Plot(NAD 27) (Governmental Sections) 39 29.0 Surface Plat(As Built)(NAD 27) 40 30.0 Surface Plat(As Built)(NAD 83) 41 31.0 Directional Program (P1) 42 SCU 21C-04 Drilling Procedure Rev 0 llilcorp Alaska,LLL 1.0 Well Summary Well SCU 21C-04 Pad&Old Well Designation Sidetrack of existing well SCU 44-05 (PTD#214-038) Planned Completion Type 4-1/2" 12.6#L-80 Liner Target Reservoir(s) Hemlock Planned Well TD,MD/TVD 12000' MD/ 10762' TVD PBTD,MD/TVD 11880' MD/ 10675' TVD Surface Location(Governmental) 3323' FNL, 571' FEL, Sec 5, T7N,R9W, SM,AK Surface Location(NAD 27) X=341744.448,Y=2457909.946 Surface Location(NAD 83) X=1481767.093,Y=2457671.200 Top of Productive Horizon (Governmental) 1691'FNL, 1205'FWL, Sec 4,T7N,R9W, SM,AK TPH Location(NAD 27) X=343534.99,Y=2459524.83 TPH Location(NAD 83) X=1483557.753,Y=2459286.137 BHL(Governmental) 1372'FNL, 1475'FWL, Sec 4,T7N,R9W, SM,AK . BHL(NAD 27) X=343809.58,Y=2459841.18 BHL(NAD 83) X=1483832.357,Y=2459602.484 AFE Number AFE Drilling Days 18 AFE Drilling Amount $3.4 MM Work String 4-1/2" 16.6# S-135 CDS-40 RKB—GL 18.6' Ground Elevation 170' AMSL BOP Equipment 11" 5M T3-Energy(Model 7082)Annular BOP 11" 5M T3-Energy(Model 6011i)Double Ram 11" 5M T3-Energy(Model 6011i) Single Ram Page 2 Revision 0 October,2014 TSCU 21C-04 Drilling Procedure Rev 0 Ilileorp Alaska.Ii i 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: October 10,2014 Subject Changes to Approved Permit to Drill for SCU 21C-04(SCU 44-05 ST) File#: SCU 21C-04(SCU 44-05 ST)Drilling Program Any modifications to SC 21 C-04 Drilling Program will be documented and approved below. Changes to an approved APD will e BLM and A CC. 3,-r. 4. C Z.42-i fy Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 October, 2014 rSCU 21C-04 II Drilling Procedure Rev 0 Ililcorp Ala.ka,IAA. 3.0 Tubular Program: To 1 Bottom Conductor 20 0 44 Surface 10-3/4" 40.5 0 3372 Production 7-5/8" 26.4 6.969 6.844 N-80 BTC 0 3798 Production 7-5/8" 29.7 6.875 6.750 N-80 BTC 3798 5733 L,,,N0'- Production 7-5/8" 33.7 6.765 6.640 S-95/P-110 BTC 5733 85 ,_k Xaa$ 6-1/8" 4-1/2" 12.6 5.0" 3.918 3.833 L-80 DWC/C 8035 12000 /1•L I 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Co 4. , +: Section (in) (in) (#/ft) (psi) (psi) (k-lbs) 6-1/8" 4-1/2" 3.826 2-11/16" 5-1/4" 16.6 S-135 CDS-40 17693 16769 595k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Ililcor1,Alaska,LU 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates i. Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com, mmyers@hilcorp.com and jbarrett@hilcorp.com 5.3 5am Weekend Update i. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. ii. Copy pmazzolini@hilcorp.com, lkeller(cihilcorp.com and mmyers@hilcorp.com 5.4 EHS Incident Reporting i. Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 ii. Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 iii. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally i. Send final"As-Run"Casing tally to mmyers@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report i. Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 IIiI,o,,:%la.<ka.1.1.1: 6.0 Planned Wellbore Schematic Soldotna Creek unit ii Well SCU 21C-04 (Stu 44-0SS1 PROPOSED SCHEMATIC EXISTING CASING DETAIL RKB to TBG Hanger= 18.6' Type Size WT Grade Conr ID Top g93. tordLrtor 20" Surf 44' 5.-fe:e 1O-3/e 40.5 K-55 Surf 3,372' 20" ,j 26.4 N-80 6.969'" Surf 3,798' 29.7 R-60 6.675 3'7°8 - Productior 7-5/8`" 33.7 5-95 6.765' 5,733' ,_- 33.7 P-110 6.755' 6,905' 1-,535 L'e 5-1'2 h-60 4.77r 10,364' 12,57:' 1.0-3/42 -,_ - 10-3/42 , . 371g PROPOSED JEWELRY DETAIL no. Depth ID OD Item 1 7,835' 7-5/8"x 4-1/2"ZXP finer hanger 2 7335'—12,000' 44/2"12.6#L-80 DWG/C EE ,.1 l l'i' INCLINATION DETAIL "'999 i 71D35 ?(,t KOP: 6035'MD/6032'TVD .\ 7 Build: 4A=/10O' ,1/ \ Hold: 60! from 9464'-9641' MD ,�� Drop: 1.0a/100'to 60!from 9541-11592' MD 17� Inclination at TD: 44e 1.)1 , Azimuth: 43! at 9540' MD&4Q`-to TO boa 0 _,, 7-5/S" A a,' . ..N .. .., Window at 8,035',Drill 6-1'6"bele to 12.Co0'. • Run 4-1.'2- 12.6=,L-SO Liner. Cement w'114 bots to above liner top. 14, E.-_-- s C: = , II s l' 4-112'. / ! Page 6 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 lIileorp Alaska,LU: 7.0 Drilling Summary 14/4-11 4s��'� SCU 21C-04 is a development oil well planned to be re-drilled in a S9arefry direction from the recently sidetracked SCU 44-05 utilizing the existing casing program down to 8035' MD/8032' TVD. At 8035' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 3965' x 6-1/8"open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated based on LWD data obtained while drilling the interval. The well will be completed with a gas lift assembly on 2-7/8"production tubing. Drilling operations are expected to commence approximately November 17th, 2014. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack. General sequence of operations pertaining to this approved drilling procedure: 1. MOB Saxon Rig#169 to SCU 21C-04,NU and test BOPE (5 days) 2. Perform clean out run to plug(8035') and test casing. Displace to mud. (1 day) 3. Set Whipstock, mill 6.625"window at 8035'. Perform FITt o 12,.5 ppg (2 Days) ' 4. Drill 6-1/8" production hole from 8035' to 12000' MD. (4 Days) 5. Perform short trip and condition mud. POOH (1 day) 6. LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. (1 Days) 7. POOH, laying down DP and liner running tools,ND BOPE (1 day) 8. RDMO (1 Day) Page 7 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 Ilileorp Alueku,LLA: 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2)week intervals during the drilling of SCU 44-05. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC and BLM approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. ��r C� o Hilcorp requests approval to install a 2-1/16" 5M HCR valve on kill line in lieu of a check valve. �;\U Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. CAL- ie Page 8 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 llikorp Alaska,UA: Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 6-1/8" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. i Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, &testing • Any other notifications required in APD. Additional requirements may be stipulated on APD. Page 9 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Ilikorp Alaska,LLf. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Justin Miller/BLM Petroleum Engineer/ (0): 907-271-3406 (C): 907-717-4039 Use the below email address for BOP notifications to the BLM: BLM AK AKSO EnergySectionNotifications@b1m.gov V Page 10 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 Ililcorp Alaska,1.Lf. 9.0 R/U and Preparatory Work 9.1 A separate sundry will be submitted that will include the following: • MIRU workover rig. 511'• Set BPV, remove tree. ( • N/U and test BOP. • Pull existing production tubing. Plug back well with cmt. • Tag &pressure test cmt plug. • Run and set a CIBP at 8055' MD. • RDMO workover rig. 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Layout Herculite on pad to extend beyond footprint of rig. 9.4 R/U Saxon Rig#169, spot service company shacks, spot& R/U company man&toolpusher offices. 9.5 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.6 Mix mud for 6-1/8"hole section. 9.7 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.8 Verify 5" liners installed in mud pumps. • HHF-1000 Pumps are rated at 3457 psi (80%) with 5" liners and can deliver 306 gpm at 120 spm. This will allow us to drill the 6-1/8"hole section with(1)mud pump. Page 11 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Hilcorp Alaska,LLC 10.0 BOP N/U and Test 10.1 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 11"x 5M annular BOP/11" x 5M double ram/11"x 5M mud cross/11"x 5M single ram. • Double ram should be dressed with 2-7/8"x 5"VBR in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8"x 5"VBR. • N/U bell nipple, install flowline. 10.2 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 4-1/2"test joint. • Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 10.3 R/D BOP test assy. 10.4 Continue mixing mud for 6-1/8"hole section. 10.5 Set wearbushing in wellhead. Ensure ID of wearbushing> 7". Page 12 Revision 0 October, 2014 SCU 21C-04 H Drilling Procedure Rev 0 Ili[cor1,Alaska,1.I.0 11.0 Mud Program and Density Selection Criteria 11.1 6-1/8"Production hole mud program summary: Primary weighting material to be used for the hole section will be Calcium Carbonate to minimize solids. We will have barite on location to weight up the active system 1ppg above ,/ highest anticipated MW in the event of a well control situation. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.5 ppg 6%KC1/PHPA fresh water based drilling fluid. Properties: MD Density Viscosity Plastic Viscosity Yield Point pH API Fluid Loss 8035' — 12000' 9.5-10.5 40-53 15-25 15-25 8.5-9.5 <_6.0 ,- System System Formulation: 6% KCI / EZ Mud DP Product Concentration Water 0.905 bbl KC1 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 10-20 ppb BAROTROL PLUS 2 ppb SOLTEX 2 ppb(if needed) BAROID 41 as required for a 9.5—10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 11.2 Program mud weights are generated by reviewing data from producing& shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be — overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 13 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 llileorp Alaska,Ii.€ 12.0 Whipstock Running Procedure 12.1 M/U window milling assembly and TIH w/4-1/2" DP off of pipe rack. • Use a 6.625"taper mill and a 6.625" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (��-5=-M). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the # of joints picked up so we know where we are. 12.3 Pressure test casing to 2500 psi/ 30 min. Chart record casing test&keep track of the amount of fluid pumped. Stage up to 2500 psi in 500 psi increments. 12.4 CBU & circ at least(1)hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Make up UBHO sub. 12.10 Orient UBHO to starter mill. 12.11 Leave assembly hanging in the elevators, and stand back on floor. 12.12 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.13 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Page 14 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 Ilileorp Alaska,LIA: Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1)35k mill shear bolt. 12.14 If needed, open BOP Blinds. 12.15 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.16 Release pick up system at this point, Make up mills. 12.17 With the top drive,pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 12.18 The assembly can now be picked up to ensure that the shear bolt is tight. 12.19 Remove the handling system. 12.20 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.21 Run in hole at 1 V2 to 2 minutes per stand. 12.22 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.23 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.24 Orient at least 30' —45' above the CIBP. Ensure to have gyro personnel and equipment as well as a wireline unit R/U and ready. e r 6.S'm Page 15 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Ililrorp Alaska,1.1A. WindowMaster G2 System on TorqueMaster BTA 7-5/8"33.7#Csg—WindowMaster G2 On BTA BHA#1 Connection Length O.D. BOTTOM TRIP ANCHOR 3/:IF-Box X Bottom Guide 3.21' 6.18" WINDOW MASTER WHIPSTOCK Shear Bolt X 3''A IF-Pin 14.6' 6.00" WINDOW MILL 3-1/2 Reg-Pin X Mill 1.5' 6.63" LOWER WATER MELON MILL 3-1/2 IF-Box X 3-1/2 Reg-Box 5.5' 6.50" FLEX JOINT 3-1/2 IF-Box X 3-1/2 IF-Pin 6.6' 4.75" UPPER WATER MELON MILL 3-1/2 IF-Box X 3-1/2 IF-Pin 5.8' 6.63" 1 JT HWDP 3-1/2 IF-Box X 3-1/2 IF-Pin 30' 5.25" MWD Survey Tool 3-1/2 IF-Box X 3-1/2 IF-Pin 3' 4.75" UBHO 3-1/2 IF-Box X 3-1/2 IF-Pin 3' 4.75" Bowen Lubricated 3-1/2 IF-Box X 3-1/2 IF-Pin 15' 4.75" Bumper Jar 6 DRILL COLLARS 3-1/2 IF-Box X 3-1/2 IF-Pin 180' 4.75" 30 JTS—HWDP 4-1/2 CDS40 Box X 4-1/2 CDS40-Pin 900' 4.75" CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 16 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 IIileorp Alaska,LLC 13.0 Whipstock Setting Procedure: 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using MWD and will have Gyrodata as backup. Ensure that UBHO and gyro tool mate up properly before making up UBHO sub. 13.2 Orient Whipstock to desired direction by turning DP in Vi round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 350 AZI 60 AZI Desired orientation of the Whipstock face is in 350 to 60 degrees azimuth. vrHole Angle at window interval (8035' MD) is < 1 deg. The wellbore trajectory is also planned to 53 to 40 degrees azimuth. Highside of the casing at 8035' is negligible. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. , 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The (),.. !�, window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.56%KC1/PHPA drillingfluid. p ppg 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. "4-j' ,sem 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 17 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 llikorp Alaska,1.1.0 13.10 Estimated metal cuttings volume from cutting window: 7-5/8" 33.7# N-80 Cuttings Weight Window Length Casing Weight Min (lbs) Avg(lbs) Max(lbs) 13 33.7# 80 110 140 13.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in= MW out. 13.13 Conduct FIT to 12.5 ppg EMW. • (12.5 —9.5) * 0.052 * 9389' tvd= 1464 psi Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A ' 12.5 ppg FIT results in a 2 ppg kick margin while drilling the interval with a 10.5 ppg fluid density. 13.14 Slug pipe and POOH. Gauge Mills for wear. 13.15 Should a second run be required pick up the following BHA. Back Up Mills Connection Length O.D. WINDOW MILL 3 % REG-P X MILL 0.98 6.63 NEW LOWER WATERMELON MILL 3 '/2 IF-B X 3 '/2 REG-B 5.5 6.5 FLEX JOINT 3 'h IF-B X 3 '/2 IF-P 6.5 4.75 UPPER WATERMELON MILL 3 '/2" IF-B X 3 '/2" IF-P 5.83 6.63 FLOAT SUB 3 '/2" IF-B X 3 '/2" IF-P 3.00 4.75 XO sub and 30 jts-HWDP 4 '/2" CDS40-B X 3 '/2" IF-P 900' 5.25 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! I Page 18 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 Itikorp Alaska, 14.0 Drill 6-1/8" Hole Section 14.1 P/U 6-1/8" directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.46—0.56 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 200 - 300 gpm. 14.6 Motor AKO should be set at 1.2 deg. Must keep up with 4 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the HDBS 6-1/8" MM55 PDC bit. Ensure to have a back up bit available on location. / Page 19 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Hileorp Alaska,MA: k-$ALLIEL RTON t?' °r. rap ` 6-'1 /8" (156mm) M PRODUCT SPECIFICATIONS Cutter Type SelcciCutter ,� 1ADC Code M424 4 le 10 Body Type MATRIX Total Cutler Count 27 40r t Cutter Distribution j; jL+am, Face I 16 . Gauge 0 Up Drill 5 0 Oqq Number of Large Nozzles 0 a p Number of Medium Nozzles 0 x Number of Small Nozzles 5 Number of Micro Nozzles 0 ; Number of Ports(Size) 0 *,"€v. Number of Replaceable Ports(Size) 0 5` : Junk Slot Area(sq ie) 71 €` Normalized Face Volume 39.86'. in API Connection 3-If2 REG.PMN Recommended Make-Lip Torque* 5.173-7,6615 Ft•lb& Nominal Dimensions•• Make-Up Face to Nose 9.18 in-233 man Gauge Length 2 in-51 mm Sleeve Length 0 in-0 mm Shank Diameter 4 i in-114 mm % Break Out Plate(Mat.*lLegacy19 101953144030 �/ Approximate Shipping Weight EOLbs.-36Kg. SPECIAL FEATURES Smaller cutters in center,1116"Relieved Gape Material#780284 'Bit specific recommended make-up torque is a function of the bit I.D.and actut bit sub O.D.utilized as specified in API RP7G Section A.L2. **Design dimensions are nominal and may+my slightly on manufactured product.Hallib non Drill Bits and Sen ices models are continumuly reviewed and refined. Product specifications may change without notice.. 2019 Italliburion.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburian and the customer that is applicable to the sale. www.halliburton.corn Page 20 Revision 0 October, 2014 TSCU 21C-04 14 Drilling Procedure Rev 0 liilcorp Alaska,1.1k, 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill 6-1/8"hole to 12000' MD using motor assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. / • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss < 6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.11 Hilcorp Geologists will follow mud log closely to determine exact TD. ' 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Ilil•orp.%la.ka.I.ii. 15.0 Run 4.5" Production Casing 15.1 R/U Weatherford 4.5"casing running equipment. • Ensure 4.5"DWC/C x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total#of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1)Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • (1)Joint with landing collar bucked up. • Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 15.4 Continue running 4.5"production casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every other joint to window. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 4.5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5800 ft-lbs 6500 ft-lbs 7200 ft-lbs Page 22 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 tlilcorp Alaska,LL(: Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-112 in 12.60 lb/ft(0.271 in) L-80 standard Material L-80 Grade "Wie 80,000 Minimum Yield Strength (psi) 111111111111111111111111,U SA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 4.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 3.958 Nominal Pipe Body I.D.(in) e-mail VAM1USAsales(dtvam-usa corn 0.271 Nominal Wall Thickness(in) 12.60 Nominal Weight(lbs/ft) 12.25 Plain End Weight(lbs/it) 3.600 Nominal Pipe Body Area(sq in) Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (lbs) 7,500 Minimum Collapse Pressure(psi) 8,430 Minimum Internal Yield Pressure(psi) 7,700 Hydrostatic Test Pressure (psi) Connection Dimensions 5.000 Connection O.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter(in) 3.94 Make-up Loss(in) 3.600 Critical Area(sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 288,000 Joint Strength (lbs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs) 288,000 Compression Rating (lbs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance(psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] � Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-lbs) 6,500 Maximum Final Torque(ft-lbs) 7,200 Connection Yield Torque (ft-lbs) Page 23 Revision 0 October, 2014 SCU 21C-04 H Drilling Procedure Rev 0 llilcorp Alaska,11A: 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 7-5/8" casing. Ensure hanger/pkr will not be set in a 7-5/8" connection. 15.8 Before picking up Baker ZXP liner hanger/packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/liner on DP no faster than 1 min/stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 7" window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 October, 2014 nSCU 21C-04 Drilling Procedure Rev 0 Ifikorp Alaska,LLC 16.0 Cement 4.5" Production Casing • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 5 bbls 12.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 10 bbls 12.5 ppg MUDPUSH II spacer. 16.6 Mix and pump 114 bbls of 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to give 500' of cement inside window in annulus between 7-5/8" casing and 4-1/2" casing. Est TOC 7535' TMD. 16.7 Displacement fluid will be produced water or 3% KCL. —170 bbls of displacement fluid Cement Calculations 7-5/8"x 4-1/2 DP"Overlap: (7835' —7535') x 0.026 = 7.8 bbls 7-5/8"x 4-1/2"Liner Overlap: (8035' —7835') x 0.026= 5.2 bbls 6-1/8"OH x 4-1/2"Liner: (12000' —8035') x 0.01677 x 1.5 = 99.7 bbls ,✓ Shoe Track: 80' x 0.01522 = 1.2 bbls Total Volume(bbls): 7.8 + 5.2 + 99.7 + 1.2 = 114 bbls Total Volume(ft3): 114 bbls x 5.615 ft3/bbl= 640 ft3 Total Volume(sx): 640 ft3 / 1.35 ft3/sk= 474 sx, / Page 25 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 IliIcorp:11u.kaa.I:I.0 Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2%BWOC Additives D202 Dispersant 1.5%BWOC D400 Gas Control Agent 0.8%BWOC D154 Extender 8.0%BWOC 16.8 Drop DP dart and displace with 8.6 ppg produced water. 16.9 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point 16.10 If elevated displacement pressures are encountered,position liner at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.11 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger(15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.12 Slack off total liner weight plus 30k to confirm hanger is set. 16.13 Do not overdisplace by more than '/2 shoe track(-1 bbls). Shoe track volume is 1.8 bbls. ✓ 16.14 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 October,2014 SCU 21C-04 Drilling Procedure Rev 0 Hikor1,Alaska,LIA: 16.15 Bleed pressure to zero to check float equipment. 16.16 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.17 Rotate slowly and slack off 50k downhole to set ZXPN. 16.18 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.19 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.20 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 16.21 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.22 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.23 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.24 NOTE: Some hole conditions may require movement of the drillpipe to "work"the torque down to the setting tool. 16.25 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 October, 2014 I- SCU 21C-04 Drilling Procedure Rev 0 liilcorp Alaska,IIA: Ensure to report the following on Wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg& cmt report+ "As-Run"liner tally to mmyers(ai)iilcorp.com 17.0 RDMO 17.1 Install BPV in wellhead. RILDs. 17.2 N/D BOP. 17.3 N/U temp abandonment cap. 17.4 RDMO Saxon Rig#169. Page 28 Revision 0 October, 2014 I- SCU 21C-04 Drilling Procedure Rev 0 Ilikorp Alaska,I,!A, 18.0 BOP Schematic tT lit Ill lit Iii Ill III lite til LIT Made160 1i IiI til iil Iii Iii ' : '" - 3.0(1' _ +,y 7-3 Ener, 1/13 ® _ _ t ?G ril del 2 mi., 11' 5U00 ', 131-IA-)1) ..---- 111 111 111 111 Ill Ii:{ • 200' Ii IIS,0lir #1\41 M }II.III 2 1/16 SM Kill Side AIIIIIIIIIIIII 3 1/8 5M Choke Side T� T-3 Energy 1.41' :— ill `m Model 7082 Ilk — 1/ 6 J '-1111111r- 00:, it"-Sb KI ■- 6 r IEu Ill Ill lel ill Grade 2.00' 1iI Iii 141141 1!I It • ' fps ^': ,,,,,�iM .fi c,:ir --, if. r.1 , 1 .- - ,.....1,0 Io..1 1,.... I... X1 20„ 5/8., Page 29 Revision 0 October, 2014 • SCU 21C-04 Drilling Procedure Rev 0 11ileorp:%la..ka.1.I.0 19.0 Wellhead Schematic Swanson River Tubing hanger,Seaboard SC-E- SCU 44-05 CL,7 X 3 Y:EUE 8rd Lift and 10'%X 7 5/8 X 2 7/8 susp,3"Type H BPV profil4 3/8 control line prep,dovetail body seals BHTA,Bowen,3 1/8 5M FE X 3"Bowen top Valve,swab,WKM-M, allffx �c�' t 1�0 3 1/8 5M FE,HWO,DD o/' , , \-P4\�'s 2''41\`",- trim . Ja�g ,a� , Valve,Wing WKM-M, "may' 2 1/16 5M FE,HWO, _ i 4rim j1_,,w�o I ii �,,,. ii Al,[�7®�� Valve,master,WKM-M, o�.. 3 1/8 5M FE,HWO,DD t'. 0 trim o 0 ct R Valve,master,WKM-M, •®0 3 1/8 5M FE,HWO,DD l O' -- trim ,,., tnm a 75.0' Adapter,Seaboard SM-E-CLN '•'N"„' 7 1/16 5M stdd X 3 1/8 5M stdd Tbg head,Seaboard,S-8, top,w/34 npt control line exit 11 5M X 7 1/16"5M, ;Vi=i w/2-2 1/16 5M SSO,BG :.D_,I p °" a'st bottom prep,bored out for 7 III l III 5/8 casing Valve,WKM-M,2 1/16 5M FE, 10 'JOT**, A.- I (0, HWO,AA JA 1 • - , _. 1-0, 11 ii ,, 5 Casing head,CIW-WF, IIIt t i 11 5M X 10'%SOW bottom, - 4, w/2-2"LPO I U r, ..i. 4. o .�- OfilITI Page 30 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 IIiicorp Alaska.1.IA. 20.0 Days vs Depth Days Vs Depth 0r SCU 21C-04 (SCU 44-05 ST) 2400 : ---b, 4000 r 6000 t, r 8000 } 10040 I/ 12004 t, ✓ 14000 — 0 2 4 6 8 10 12 14 16 18 20 Days Page 31 Revision 0 October, 2014 GEOLOGICAL PROGNOSIS WELL NAME: SCU 21C aka 44-05ST FIELD: Swanson River SCU 42-05 Pad SURFACE X 341744.38 STATE Alaska I SURFACE Y 2457910.03 BOTTOM HOLE X: 343809.58 TVD REF DATU KB BOTTOM HOLE Y: 2459841.18 TVD REF ELEV 171 18'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV 152.4 _ PROPOSED TD: 12000.00 MD I PROPOSED TD: 10762.13 TVD A sidetrack well out of the SCU 44-05 to the H1-8 benches. The well will offest the successful Objective: SCU 22-04 and SCU 31-04 wells. 1 . Geo Summary/ Based on subsurface evaluation . Justification: RMATION TOPS& GEOHAZARDS EXPECTED TOP Formation FORMATION FLUID MD TVD Est Pressure X Y +1- SSTVD KOP 8034 8031 341866.2 2457997.1 -7860 HP-H20_SAND Wet Sand Water 9050 8950 4300-4900# 342158.3 2458244.0 20 -8779 3SE_HP-H20_KRE_GRIE Wet Sand Water 9271 9099 4300-4900# 342281.1 2458349.7 20 -8928 SR_G1ST Tyonek Oil Oil 11050 10096 2000-2600# 343363.8 2459343.0 20 -9925 SR_G2ST Tyonek Oil Oil 11231 10217 2000-2600# 343456.1 2459441.1 20 -10046 SR_H1ST Hemlock Oil Oil 11384 10322 1000-14001* 343531.3 2459523.3 20 -10151 SR_H5ST Hemlock Oil Oil 11586 10464 1200-28001* 343625.4 2459630.3 20 -10293 SR_H7ST Hemlock Oil Oil 11758 10588 1200-28001* 343703.3 2459720.8 20 -10417 SR H1OST Hemlock Oil Oil 11936 10716 1200-28001* 343784.1 2459814.6 20 -10545 �.:. — 00 moi;i1• � -1059 =Primary Objective =Secondary Objective TARGET RADIUS 50 FT @ the Hemlock level DATA COLLECTION REQUIREMENTS: Mud Logging Full crew of 4 from KOP. LWD Data. Triple Combo LWD on Production hole section _ E-Line Lo. Data COMPLETION TYPE Gas lift completion ANTICIPATED RATES 2000 bpd gross fluid ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2 7/8"or 3.5" OTHER COMMENTSRECEIVED EC CG I V Offset wells have seen water flows and lost circulation in the lower Tyonek! i 1We be be kicking off above the high pressured water sand and will encounter it in the well 1 OCT 302014 AOGCC 1 1 SCU 21C-04 Drilling Procedure 1 H Rev 0 I lileorp Alaska.1.1.1: 21.0 Geo-Prog GEOLOGICAL PROGNOSIS I , WELL NAME: SCU 21C aka 44-05ST FIELD: Swanson Riv-j SCU 42-05 Pad SURFACE X: 341744.38 STATE Alaska SURFACE Y: 2457910.03 1 BOTTOMHOLE X 343809.58 TVD REF DATUM KB /JV` j BOTTOM HOLE Y. 2459841.18 TVD REF ELEV 171 18'KB(Saxon 169) COORD REF.SYSTEM ,NAD27 GROUND ELEV 152.4 PROPOSED TO i 12000.00 MD _�.__. i.. t PROPOSED TD 10762.13 TVD Asidetrack well out of the SCU 44-05 to the H1-8 benches. The ell will off-stthe suc essful SCU 22-04 Objective. and SCU 31-04 wells. '______ __ __�__ _._v_ ___ _____c Geo Summary/ Based on subsurface evaluation 742- Justification: i ANTICIPATED FORMATION TOFS& GEOHAZARDS I ; EXPECTED i TOP Formation FORMATION FLUID �� TVD Est Pressure X Y +/- KOP Clrir 8031 341866.2 2457997.1 HP-H20_SAND Wet Sand I 8950 ; 342158.3 2458244.0 20 BSE_HP-H20_KRE_GRID i V 9271 9099 ! 342281.1 2458349.7 20 SR G1ST 1050 10096 343363.8 2459343.0 20 SR_G2ST Tyonek Oil Oil 11231 I 10217 343456.1 2459441.1 20 SR_H1ST Hemlock Oil Oil 11384 10322 1000-1400# 343531.3 2459523.3 20 SR_H5ST Hemlock Oil Oil 11586 10464 1200-2800# 343625.4 2459630.3 20 SR_ Hemlock Oil Oil 11758 10588 1200-2800# 343703.3 2459720.8 20 SR_H1OST Hemlock Oil Oil 11936 10716 1200-2800# 343784.1 2459814.6 20 TD i 12000 10762 343809.6 2459841.2 11111111 =Primary Objective =Secondary Objective TARGET RADIUS 50 FT @ the Hemlock level DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 from KOP. I . LWD Data: Triple Combo LWD on •roduction hole section ✓ 1 ; E-Line Log Data: « -t- t--- T^ COMPLETION TYPE Gas lift completion ANTICIPATED RATES 2000 bpd gross fluid 1 ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2 7/8"or 3.5" I t _ 1 OTHERCOMMENTS '-.-._.__.. y_ _____ _______________________ ________ _ _._........-4 Offset wells have seen water flows and I.stcirculation .-_..-. ---_- 1.---_..__-_in the IowerTyonek! ! We be be kicking off above the high pressured water sand and will encounter it in the well , Page 32 Revision 0 October, 2014 SCU 21C-04 H Drilling Procedure Rev 0 Ilileorp Alaska,LLC 22.0 Anticipated Drilling Hazards Water Flow: --ter. The Tyonek water sands will be open. Ensure to treat the initial flow as gas. After we are confident we are only dealing with water from the sands we will drill the interval while the well is flowing water. Utilize MW and ECD to keep the well dead will drilling. During trips We will use heavy pills and ✓ viscous pills to control the flow and trip in and out of the well. Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition • carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The • need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. 'v I No abnormal temperatures or pressures are present in this hole section. Page 33 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 Il ilrorp:%laaka,lit.. - 23.0 Rig Layout a 1 I $ i( iZ Fail •N9 II 5��.. ..I� i t 1 r 1 A 9 i i III II , r. 1 .1 'I•t d ' '�■YIQ. ' ::Taal!, . 1 1.7.! 1 IIIIIIIIIIIL, _� I'�I I I, I� iii. I .,:..1.-77..c:..1 -% mmnc�llt!! '� _ ,!!III CIIII� '' : �iGMOI�6 1 �„ T • I Fiji , �' TI;��t. i -- rat: __ 1 . 1, €_ . .. _141:,,iiii. . . _ , . , ,.4,jI! IMF ' I' lI�iimull :.:,.,r i 11711il ( T 0ialdNl I 1:mmw.: -in .- �� i i 5--1 t-,----q ._ _. .� 1 ` 1 - - 111". I�I�I��I�Ii � �16��;1 , •I I 1111 I II • ' ! 1 I I! i D , 'VIII I I�! 1111. II�,�I'. � ' 1111�� y - =t A Page 34 Revision 0 October,2014 SCU 21C-04 H Drilling Procedure Rev 0 llileorp Alaska,IJA 24.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 35 Revision 0 October, 2014 SCU 21C-04 H Drilling Procedure Rev 0 II ileorll Alaska,LLC 25.0 Choke Manifold Schematic . 1.,'''',0'.... 47 : ,i~ %c.- /,,,,.r - 2' put,:G_ 97 24 4111 43.62 i n 70A 1pyr •.,�.� � 1143 -14.62 = 41.62 t643 .0 tiC 1 �_` 0.19 --0.19 O'.0 019 0.19 A.111- '90 11-.111 ,,,� . 0.19 -� I i J 0 �!• J 1 0.19 yy,,,,•'.. ' U ■1'1■1 1■1M1 0.19 , 0.19 zla4 r�:!�.1 ►D ° �« 9 7.84 1-0.19 ' .11St 1■t1.i I 7 I "MEW ' i 1 ( 111.11111110!14. at9 I " J 1 M,.,,: 3103 4510 tai wig,- ,0 0.19 I ,o �,4 v4 h 91os 14.82 ��',. 1 Cs) �OO�]C� I -f.4 14.62 ,I� i �}, •1� . = t662 ��. A I aro 9...F ' I 8:21.ilia I 1 1111111111111111 PI two '1-19 �� areJ aL.+�.J a 11 ■11a il.i..�t�.. laso N >� ' A, AA. zf19I 10.50 ' If! ix:464 rwr4ms 10_ ii.,44k1 za0.1 , II .� 180.1.1■011 -- 10 CID i. 112 CHOKE �_� � �� -0.l5 -0.19 0.19--• 0.19-- - 0.19 MANUAL 1 3\lk7m+ m OPE71A'MIN PA-C4,64; j'�/ r -6._t--14.62 -14.62--- -14.62 14.62- 131 "j/-3 --- 43.62 4162 T(j'Age#„ 87.24 1 1F2 1,uxw£51114 6 GASKETS C .4+Ct- `CAO_ „-E_- T494F7r.�+� .:.^� :� C e.ww I- - O .•. 1 MT 44'1ORS.04 Y1 N1 veld`. ... ...-'-r_._.�:. c-''-t _ 1. Y-210246-ss-11_' Page 36 Revision 0 October, 2014 TSCU 21C-04 Drilling Procedure Rev 0 Ilileorp.Ua+l:a. • 26.0 Casing Design Information Calculation & Casing Design Factors Swanson River Unit DATE: 10/10/2014 WELL:SCU 21C-04(SCU 44-05 ST) FIELD:Soldotna Creek Unit DESIGN BY:Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 6-1/8" Mud Density: 10.5 ppg Hole Size Mud Density: • Drilling Mode MASP: 1695 psi (See attached MASP determination& calculation) Production Mode MASP: 2754 psi (See attached MASP determination& calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.406 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 4-1/2" Top(MD) 7,835 Top(TVD) 7,833 Bottom (MD) 12,000 Bottom (TVD) 10,591 Length i 4,165 _....__..---._._.........._.............................._Weight(ppf) 12:6._..............__-.......___....____...__._.____...____. Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 52,479 Tension at Top of Section (lbs) 52,479 Min strength Tension(1000 lbs) 288 Worst Case Safety Factor(Tension) 5.49 Collapse Pressure at bottom (Psi) 4,300 Collapse Resistance w/o tension(Psi) 7,500 Worst Case Safety Factor(Collapse) 1.74 MASP(psi) 3,226 Minimum Yield (psi) 8,430 Worst case safety factor(Burst) 2.61 Page 37 Revision 0 October, 2014 SCU 21C-04 Drilling Procedure Rev 0 niieorp IAA 27.0 6-1/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-1/8"Hole Section Hilcorp SCU 21C-04 Kenai,Alaska MD ND Planned Top: 0 0 Planned TD: 12000 10591 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad HP-H20_SAND 8,950 2800 WATER 6.0 0.313 BSE_HP-H20_KRE_ 9,099 2800 WATER 5.9 0.308 SR_G1ST 10,096 2100 OIL 4.0 0.208 SR_G2ST 10,217 2100 OIL 4.0 0.206 SR_H1ST 10,322 2200 OIL 4.1 0.213 SR_H5ST 10,464 2800 OIL 5.1 0.268 SR_H7ST 10,588 2800 OIL 5.1 0.264 SR_H1OST 10,716 2800 OIL 5.0 0.261, TD 10,762 2800 OIL 5.0 0.260 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date SCU 4405 9.8-lOppg 9,400 10,925 2014 SCU 21-4 12 ppg 0 10,965 1961 SCU 44-33 11.3-12.5 ppg 9,216 10,747 2013 SCU 41A-4 11.2 ppg 9,300 10,807 2013 Assumptions: 1. Maximum planned mud density for the 6-1/8"hole section is 10.5 ppg. 2. Calculations assume reservoirs contain 100%gas(worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticipated fracture gradient at 8035'ND=12.5 ppg EMW Fracture Pressure at 6-1/8"window considering a full column of gas from window to surface: 8035(ft)x 0.65(psi/ft)= 5222 5222(psi)-[0.1(psi/ft)*8035(ft)]= 4419 psi MASP from pore pressure;entire wellbore evacuated to gas from TD j tti� 10591(ft)x 0.26(psi/ft)= 2754 psi 6100 c 2754(psi)-[0.1(psi/ft)*10591(ft)]= 1695 psi -' 4( 14 Summary: �. 1. MASP while drilling 6-1/8"production hole is governed by SIBHP minus entire wellbore evacuated to gas from TD. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. Page 38 Revision 0 October, 2014 SCU 21C-04 H Drilling Procedure Rev 0 Hileorp Alaska,1,I,C 28.0 Plot (NAD 27) (Governmental Sections) SOO8N009W m a) A028399 SRU24-33 BHL! • A028396 BCU_41-00 BHA fir' N, SCU_A.04d HL P N. \ 1 SCU 2IC-04 BHL i BCU 42&.06 BHI: 1 SGU42-m U_4:..0 RD\Bhilkk. ,0,0 I 1 l I ��s -03 BH 1 ' °' SCU 21 C-04 TPH aY� ".�� r, ! SCU_12-04 EMS, 12&-41 BHL I SCU_32A-47 13t4.3111� e• -O SCU BHL i .0 SCU 22-04PH 131-,_•I SCU_428.07 B o oa /,� SCU_22-04 Si'- 1 ma v 5GU_42-0SY a0_42-o n:�-IL �t1 vo 1 1111 a ao ttf� S l42E-OSP8 r 1 1 ! SCU_33-06 BHLS-,,ti '13-04 -• yI . ' - EHL P SCU_ 3-os BNL S007N009Wi SCU 21C-04 SHL A028996 i A028997 SCU_14A-O BHL r_^--- _. r I 'SCU_14-OS BH1._.. _„, "'f'S'�C: dk-GS BHLi""'".. 1 ::CU_44-O5 BHL.• SGU_24-07 SHLI" SCU 34-ttb 13144SC'U_314-34 SHOO BCU_41.-06 BM1.I.,. BC Legend a SCU 21C-04 SHL SCU 21C-04 TPH 0 -+- SCU 21C-04 BHL SGU_31-0e Bl* ---• Other Surface Well Locations �"'y • Othe•Bottom Hole Locations /' SCU_17501 scu 2-0OiBI*a °•'- Well Paths i) 1 SRF Unit Boundary 9i \ II 0 1000 2.CO0 SoldQotnaCreek Unit Feet SCU 21C-04 Alaska Stale Plane Zone 4 NAL*27 A 111karp Alaska,LIZ Kap Data:10.S'201 4 Page 39 Revision 0 October, 2014 SCU 21C-04 ta Drilling Procedure Rev 0 11ilcorp Alaska,LTA: 29.0 Surface Plat (As Built) (NAD 27) T8N SECTION LINE(NOT TO SCALE) 32 33 T7N R9W S 4 SECTION COR'COMPUTED! 4.[ N:2451225492 E:342363.112 SCU 33-05 ASBUILT SURFACE LOCATION 332T FNL(NTSI NAD 27 ASP ZONE 4 N:2457909.946 uJ E:341744.448 z LAT:60'43'29.227"N —\\ \---"1-171'm — Z LON: 150`53'02.139"W ' 571'FEL U 3323'FNL w ELEV: 153.335'NAVD88 — D _ 0SU4amr - Well 91'F6L 0 arCaj 0 \ 3pY,20.q! -.�, II SRF 42-05 PAD r NOTES 1. BASIS OF HORIZONTAL;NAU133 US FEET POSITION;EPOCH 20101 „» AND VERTICAL CONTROL(NAVD8B1(S AN OPUS SOLUTION FROM s..s'`sOF Ag 111+ NGS STATIONS TBON.TSEA AND ANC2 TO ESTABLISH CP-2. THE -- _�1....- -"f 4S•/i ALASKA STATE PLANE COORDINATES NAD 63 ZONE 4 IN FEET ARE — y. :7. N=2458384 57$ :,..!..f.49]21 `.*�i E=1483669.444 �+�" 5. ibA.c....,' ELEV.=212.690?NAVD88I _.�. .STAN A.NdANE i + 2.SECTION LINES SHOWN ARE COMPUTED FROM MONUMENT TIES o, 1. f ALONG THE NORTH TOWNSHIP LINE OF TOWNSHIP 7N RANGE OW SCALE , 'R 3. DATUM TRANSFORMATIONS(NAMASPZ4 TO NAD27 ASPZ4} '> Jot' n X11 t 1 L 5„"`sss� _VFRF,Doer UfIttG CORPSCON SOFTWARE VERSION 6 0.1. Ih..._. FEET I ''''1'''HILLCORP ALASKA,LLC Pr�tIla. SWANSON RIVER FIELD "� °" �'° C0115L1(t111.3 Inc 1'F:,YM hw' Y.R — WELL SCU 33-05 AS BUILT SURFACE LOCATION xc"`F '��» NAD 27 hh0.ECt1�.7 uym6 4:i I'0IaeLM501.13,14* vrr.:Tcanr. eati!1ro +btt.vo! r.D.Mr.N 50LU]+NA W wre. "X"t J SECTION.05 TO7N RO9W e"fR �:sec is<�i xta�w cax Nrlxw,s s�..s.EAMO.A.144/MLNLKXJW M Ililrrrnrp Alaska.Ilk 1 SEWARD MERIDIAN,ALASKA Page 40 Revision 0 October, 2014 SCU 21C-04 ini Drilling Procedure Rev 0 Ui!carp Alaska,LIA 30.0 Surface Plat (As Built) (NAD 83) TSN SECTION LINE(NOT TO SCALE) I 32 33 - T7N R94\+ 4 SECTION GOR/ 038 TEU) jil N:24•9096.Bf1B E:1a62373.B+S6 244 SCU 33-05 ASBUILT SURFACE LOCATION FNS; TS; NAD 83 ASP ZONE 4 N_2457671.2000 to E:1481767,093 Z J LAT:60'43'27.196"N z LON-150'5310.131-W O 571'FEL U 3323'FNL W ELEV: 153.335 NAVD88 I 1 6Grcce Ram *xuQmr •sCu t H5 51'FEL 'l9J IS-1�.xLe-a •ago 0 1 -.[IlQl ar° SRF 42-05PAD . ,r T NOTES 1. BASIS OF HORIZONTAL NAO83 US FEET POSITION/EPOCH 2D101 ,,� �I AND VERTICAL CONTROL INAVD88)IS AN OPUS SOLUTION FROM I I NGS STATIONS TBON.TSEA AND ANC2 TO ESTABLISH CP-2. THE \ ........„9_F.„....4„, S � ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE- _to/ ,i/ N=245ti:'184 578 WINN _*. g .*i E=14E36E9.444 Za fC// ELEV.=212.690(NAVD88I /"' " �i� / STAN A.Yd AK r 2 SECTION LINES SHOWN ARE COMPUTED FROM MONUMENT TIES SCALE '�, 'm''m 14 1 A.()NG THE NORTH TOWNSHIP GINE OF TOWNSHIP 7N RANGE 9W 9 '.1�;, f C:! t/I I I5t„`%��2 iI I FEET ;,,..HILLCORP ALASKA,LLC RV:W% . Consulting In_ H SWANSON RIVER FIELD row ��"'i''` WELL SCU 33-05 Moetnirl, WA ,, ' xiF ,'-2�I AS BUILT SURFACE LOCATION cC • NAD 83 cnoEcr» +s` r a f.\IMAM saux nAK We iccanur+ ',WE Iau1V MX ranamSECTION.05 107N RO9W ,. t...... “ u .0.0” oveomoacce Hilrnrp Ala4ka.1.1t 1 SEWARD MERIDIAN,ALASKA Page 41 Revision 0 October, 2014 1 ti Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit Soldotna CK Unit 33-05 SCU 21C-04 4,g. k Plan: SCU 21C-04 WP1.0 i Standard Proposal Report At 19 September, 2014 T-P V., gli 6 r 3 1,1 0 111V illr HALL Aff If ^E Sperry Drilling Services WELL DETA lotna CK Unit 33-05 90% c( 4 1/2" _ Ground Level: 153.34 +N/-S +E/-W Northing Easting Latittude Longitude Slot v ,6:c.) SCU 21C-04 WP1.0 0.00 0.00 2457909.95 341744.45 60.7247852 -150.8839274 1600- I ,°Q °° 80% conf. %s Project: Soldotna CK Unit 9 0 Site: Soldotna CK Unit 900 SCU 21C-04 SR H7ST tgt Well: Soldotna CK Unit 33-05 — c Wellbore: SCU 21C-04 cc 800— Plan: SCU 21C-04 WP1.0 s , + °o , o _ .' A , 76 �l_'•'----____ SCU 2IC-04 SR_H5ST tgt o 0— 75/8" TOW 10 3/4" HALLIBURTON • 1 • Sperry Drilling Services U 44-05 -800— - 1 I I I 1 I I 1 I , 1 I I 1 I I 1 I 1 I I I I I 1 1 , -1600 -800 0 800 1600 2400 3200 West(-)/East(+) (800 usft/in) - 7 5/8"TOW_-_, KOP:Start Dir 12°/100':8035'MD,8032.26'TVD:45°RT TF 8100— ------- --------- End Dir :8055'MD,8052.23'TVD T -_ M Azimuths to True North _ - Magnetic North:16.99° 8400— Start Dir 4°/100':8085'MD,8082.15'TVD Magnetic Field _ 00 Strength:55477.2snT Dip Angle:73.70° - _ Date:9/17/2014 Model:BGGM2014 8700— 00 qO 9000— SR_TYNK_HP_H20 o� End Dir :9483.97'MD,9218.69'TVD �� ----- 0 - p 9300— R Start Dir 1°/100':9840.68'MD,9395.76'TVD o _ co - ,o _C - a - End Dir : 11592.5'MD, 10469'TVD Q 9600— Do 1 O<° I ▪ _ • Total Depth: 12000'MD, 10766.02'TVD f - • 9900— o0 - ^O I a) SR H1ST It - - I , 10200— gse HP H2O Sand SCU 21C-04 SR_H5ST tgt o0 --- NWj _ 10500 SR_H5ST _ ' 00 O SCU 21C-04 SR H7ST tgt �`„� /10800— , SCU 44-05 - , - 4 1/2” REFERENCE INFORMATION SCU 33-05 Co-ordinate(N/E)Reference: Well Soldotna CK Unit 33-05,True North - SR H10ST Vertical(TVD)Reference: SCU 21C-04 Prelim @ 171.00usft SCU 21C-04 WP1.0 11100— - Measured Depth Reference: SCU 21C-04 Prelim @ 171.00usft Calculation Method: Minimum Curvature - l 1 1 I 1 1 I 1 I I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I l I 1 1 I I l I 1 l I I I I I I I I I I 1 1 1 1 -900 -600 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 Vertical Section at 46.15° (600 usft/in) South(-)/North(+)(500 usft/in) Jto N Nv. J 0 N J DJ O N tN1, J to 0 to to 0 to 0 Lotto O to O to O 0 0 0 0 0 0 0 0 O 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 vlO <43 ".'" - ; r pl O fD fD N N,n•. _ o J. g tO C Cr)co co U)V) w c aof? w m E nnaaa LA b „ •9. �M • - CCO_ O_- b cC).42 -i S Q _ _,7 0 i oo�wl=� • 0007 C7(7 mo AAT�T�T\ _..M� I 4,.r..W ' C C C o—- C c o` o 'R; J N w y o o$ ��► o _ I ss c so W - N 'de o 0 0 p may` „• _ cn (T - n JQ0. O b o S O o d d,*11 \. _ O o , 1 ^' O o0 1 A I Y I Y - I 1 b o— li e' n 11 o J c c' N 0i A _ H N CC ut O J o �• _ V; n c O y o cO . 108±1 OOSOf v) n N = O0 \ 0009 • CD r to n— i. 0 m U 0 _ N • N A -1 -. V O - O� � cn H y - n �O ` �In"N O N _ 'o n , \' 8 b' I \ °^ A I \ _ fo \ Vl In 7> A \ n N - 'x -' \ c c N N \N N O 0+ .-i n - - O N A <.. N 0 CTC U 7 O G 8 ; ( In m<o N n =a Jz c 12 51 ,— m50m m [� �' 000 0 s +� O _ o A z A m r O° 4b 0. o o °°0 `47` _ s a N� m = $) [d[[1 S - 5 2 N 2 n A c yHy _ 2.222' m N�'o. o _ :cc= O _ _o` c 10 Al CS 21 - QQD n 5 -1 N r n • W A .-- n W - ZS��� Z N= .X v,— C=,7C 6w o _ 333c Nf° A . �o_ - �� b o W - co-1 os o o— gg2 W0 O \ 01 4.6 i AfG• \C L O l,JO Y J w b 0 Halliburton HALLIBURTD. + Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Company: Hilcorp Energy Company TVD Reference: SCU 21C-04 Prelim @ 171.00usft Project: Soldotna CK Unit MD Reference: SCU 21C-04 Prelim @ 171.00usft - Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 33-05 Survey Calculation Method: Minimum Curvature Wellbore: SCU 21C-04 Design: SCU 21C-04 WP1.0 Project Soldotna CK Unit,Swanson River Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Soldotna CK Unit Site Position: Northing: 2,460,278.17 usft Latitude: 60.7313645 From: Map Easting: 344,519.07usft Longitude: -150.8686069 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.76 ° Well Soldotna CK Unit 33-05 Well Position +N/-S 0.00 usft Northing: 2,457,909.95 usf - Latitude: 60.7247852 +E/-W 0.00 usft Easting: 341,744.45 usf r Longitude: -150.8839274 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usf Ground Level: - 153.34 usft FWellbore SCU 21C-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 9/17/2014 16.99 73.70 55,477 Design SCU 21C-04 WP1.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,035.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 17.66 0.00 0.00 46.15 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (usft) (0) (0) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (0) 8,035.00 2.25 30.00 8,032.26 7,861.26 83.24 115.71 0.00 0.00 0.00 0.00 8,055.00 4.30 53.28 8,052.23 7,881.23 84.03 116.50 12.00 10.23 116.41 45.00 8,085.00 4.30 53.28 8,082.15 7,911.15 85.37 118.30 0.00 0.00 0.00 0.00 9,483.97 60.24 48.41 9,218.69 9,047.69 557.96 658.06 4.00 4.00 -0.35 -5.11 9,840.68 60.24 48.41 9,395.76 9,224.76 763.51 889.65 0.00 0.00 0.00 0.00 11,592.50 44.00 40.00 10,469.00 10,298.00 1,742.00 1,857.00 1.00 -0.93 -0.48 -160.28 11,759.32 44.00 40.00 10,589.00 10,418.00 1,830.77 1,931.49 0.00 0.00 0.00 0.00 12,000.00 44.00 40.00 10,762.13 10,591.13 1,958.85 2,038.96 0.00 0.00 0.00 0.00 9/19/2014 12:40:49PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Company: Hilcorp Energy Company TVD Reference: SCU 21C-04 Prelim @ 171.00usft Project: Soldotna CK Unit MD Reference: SCU 21C-04 Prelim @ 171.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 33-05 Survey Calculation Method: Minimum Curvature Wellbore: SCU 21C-04 Design: SCU 21C-04 WP1.0 Planned Survey Measured Vertical Map Map • Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) 7,861.26 8,035.00 2.25 30.00 8,032.26 7,861.26 83.24 115.71 2,457,991.62 341,861.26 0.03 141.11 KOP:Start Dir 12°/100':8035'MD,8032.26'TVD:45°RT TF 8,035.10 2.25 30.00 8,032.36 7,861.36 83.24 115.71 2,457,991.62 341,861.27 0.00 141.11 7 5/8"TOW 8,055.00 4.30 53.28 8,052.23 7,881.23 84.03 116.50 2,457,992.40 341,862.07 12.06 142.23 End Dir :8055'MD,8052.23'ND 8,085.00 4.30 53.28 8,082.15 7,911.15 85.37 118.30 2,457,993.72 341,863.89 0.00 144.46 Start Dir 4°/100':8085'MD,8082.15'TVD 8,100.00 4.89 52.66 8,097.10 7,926.10 86.09 119.26 2,457,994.43 341,864.86 4.00 145.65 8,200.00 8.89 50.63 8,196.36 8,025.36 93.58 128.63 2,458,001.79 341,874.33 4.00 157.59 8,300.00 12.88 49.86 8,294.54 8,123.54 105.68 143.13 2,458,013.69 341,888.99 4.00 176.43 8,400.00 16.88 49.45 8,391.16 8,220.16 122.31 162.70 2,458,030.06 341,908.78 4.00 202.06 8,500.00 20.88 49.19 8,485.76 8,314.76 143.41 187.23 2,458,050.82 341,933.59 4.00 234.37 8,600.00 24.88 49.01 8,577.87 8,406.87 168.86 216.61 2,458,075.88 341,963.32 4.00 273.20 8,700.00 28.88 48.88 8,667.05 8,496.05 198.55 250.70 2,458,105.11 341,997.80 4.00 318.35 8,800.00 32.88 48.78 8,752.85 8,581.85 232.34 289.33 2,458,138.37 342,036.88 4.00 369.61 8,900.00 36.88 48.70 8,834.87 8,663.87 270.04 332.31 2,458,175.49 342,080.36 4.00 426.73 9,000.00 40.88 48.63 8,912.70 8,741.70 311.49 379.43 2,458,216.30 342,128.04 4.00 489.42 9,048.06 42.80 48.60 8,948.51 8,777.51 332.69 403.49 2,458,237.17 342,152.38 4.00 521.45 SR_TYNK_HP_H20 9,100.00 44.88 48.57 8,985.96 8,814.96 356.48 430.47 2,458,260.60 342,179.67 4.00 557.39 9,200.00 48.88 48.52 9,054.30 8,883.30 404.79 485.16 2,458,308.17 342,235.02 4.00 630.31 9,300.00 52.88 48.48 9,117.38 8,946.38 456.19 543.26 2,458,358.78 342,293.80 4.00 707.81 9,400.00 56.88 48.44 9,174.90 9,003.90 510.42 604.47 2,458,412.19 342,355.73 4.00 789.52 9,483.97 60.24 48.41 9,218.69 9,047.69 557.96 658.06 2,458,459.00 342,409.95 4.00 861.10 End Dir :9483.97'MD,9218.69'ND 9,500.00 60.24 48.41 9,226.65 9,055.65 567.19 668.46 2,458,468.09 342,420.48 0.00 875.00 9,600.00 60.24 48.41 9,276.29 9,105.29 624.82 733.39 2,458,524.84 342,486.18 0.00 961.74 9,700.00 60.24 48.41 9,325.93 9,154.93 682.44 798.31 2,458,581.59 342,551.87 0.00 1,048.49 9,800.00 60.24 48.41 9,375.57 9,204.57 740.07 863.24 2,458,638.33 342,617.57 0.00 1,135.23 9,840.68 60.24 48.41 9,395.76 9,224.76 763.51 889.65 2,458,661.42 342,644.29 0.00 1,170.52 Start Dir 1°/100':9840.68'MD,9395.76'TVD 9,900.00 59.68 48.18 9,425.45 9,254.45 797.68 927.99 2,458,695.06 342,683.09 1.00 1,221.83 10,000.00 58.74 47.78 9,476.64 9,305.64 855.18 991.81 2,458,751.70 342,747.67 1.00 1,307.69 10,100.00 57.80 47.38 9,529.23 9,358.23 912.56 1,054.59 2,458,808.23 342,811.23 1.00 1,392.72 10,200.00 56.86 46.96 9,583.21 9,412.21 969.78 1,116.33 2,458,864.62 342,873.73 1.00 1,476.89 10,300.00 55.93 46.54 9,638.55 9,467.55 1,026.85 1,177.00 2,458,920.86 342,935.16 1.00 1,560.17 10,400.00 54.99 46.11 9,695.25 9,524.25 1,083.73 1,236.57 2,458,976.94 342,995.49 1.00 1,642.54 10,500.00 54.06 45.67 9,753.28 9,582.28 1,140.42 1,295.04 2,459,032.84 343,054.72 1.00 1,723.98 10,600.00 53.13 45.21 9,812.63 9,641.63 1,196.89 1,352.39 2,459,088.53 343,112.82 1.00 1,804.45 10,700.00 52.20 44.75 9,873.28 9,702.28 1,253.13 1,408.59 2,459,144.00 343,169.78 1.00 1,883.95 10,800.00 51.27 44.27 9,935.20 9,764.20 1,309.12 1,463.64 2,459,199.25 343,225.57 1.00 1,962.43 10,900.00 50.35 43.79 9,998.39 9,827.39 1,364.84 1,517.51 2,459,254.24 343,280.19 1.00 2,039.88 11,000.00 49.42 43.29 10,062.83 9,891.83 1,420.27 1,570.19 2,459,308.96 343,333.61 1.00 2,116.27 11,100.00 48.50 42.77 10,128.48 9,95748 1,475.41 1,621.66 2,459,363.40 343,385.81 1.00 2,191.59 9/19/2014 12:40:49PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Company: Hilcorp Energy Company TVD Reference: SCU 21 C-04 Prelim @ 171.00usft Project: Soldotna CK Unit MD Reference: SCU 21 C-04 Prelim @ 171.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 33-05 Survey Calculation Method: Minimum Curvature Wellbore: SCU 21C-04 Design: SCU 21C-04 WP1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 10,024.34 11,200.00 47.58 42.24 10,195.34 10,024.34 1,530.23 1,671.90 2,459,417.53 343,436.79 1.00 2,265.80 11,300.00 46.67 41.70 10,263.38 10,092.38 1,584.71 1,720.91 2,459,471.35 343,486.53 1.00 2,338.89 11,391.22 45.83 41.18 10,326.47 10,155.47 1,634.11 1,764.52 2,459,520.16 343,530.80 1.00 2,404.56 Bse HP H2O Sand-SR_H1ST 11,400.00 45.75 41.13 10,332.59 10,161.59 1,638.84 1,768.66 2,459,524.84 343,535.00 1.00 2,410.82 11,500.00 44.84 40.55 10,402.93 10,231.93 1,692.61 1,815.14 2,459,577.97 343,582.21 1.00 2,481.59 11,592.50 44.00 40.00 10,469.00 10,298.00 1,742.00 1,857.00 2,459,626.80 343,624.72 1.00 2,545.99 End Dir :11592.5'MD,10469'TVD 11,592.99 44.00 40.00 10,469.35 10,298.35 1,742.26 1,857.22 2,459,627.05 343,624.94 0.00 2,546.33 SR_H5ST 11,600.00 44.00 40.00 10,474.39 10,303.39 1,745.99 1,860.35 2,459,630.74 343,628.12 0.00 2,551.17 11,700.00 44.00 40.00 10,546.33 10,375.33 1,799.20 1,905.00 2,459,683.35 343,673.49 0.00 2,620.24 11,758.69 44.00 40.00 10,588.55 10,417.55 1,830.44 1,931.21 2,459,714.23 343,700.11 0.00 2,660.78 SR_H7ST 11,759.32 44.00 40.00 10,589.00 10,418.00 1,830.77 1,931.49 2,459,714.56 343,700.40 0.00 2,661.21 11,800.00 44.00 40.00 10,618.26 10,447.26 1,852.42 1,949.65 2,459,735.96 343,718.85 0.00 2,689.31 11,900.00 44.00 40.00 10,690.20. 10,519.20 1,905.63 1,994.30 2,459,788.57 343,764.22 0.00 2,758.37 11,936.99 44.00 40.00 10,716.80 10,545.80 1,925.31 2,010.82 2,459,808.03 343,780.99 0.00 2,783.92 SR_H10ST 11,999.99 44.00 40.00 10,762.12 10,591.12 1,958.84 2,038.95 2,459,841.17 343,809.57 0.00 2,827.43 Total Depth:12000'MD,10766.02'TVD-4 1/2" 12,000.00 44.00 40.00 10,762.13 10,591.13 1,958.85 2,038.96 2,459,841.18 343,809.58 0.00 2,827.44 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) SCU 21C-04 SR H5STtgt 0.00 0.00 10,469.00 1,784.59 1,811.30 2,459,670.00 343,579.60 -plan misses target center by 62.43usft at 11594.76usft MD(10470.62 TVD, 1743.20 N, 1858.01 E) -Circle(radius 100.00) SCU 21C-04 SR_H7ST tot 0.00 0.00 10,589.00 1,892.55 1,919.06 2,459,776.50 343,688.80 -plan misses target center by 56.79usft at 11786.65usft MD(10608.66 TVD, 1845.31 N, 1943.69 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 8,035.10 8,032.36 7 5/8"TOW 7-5/8 9-7/8 11,999.99 10,762.12 4 1/2" 4-1/2 6-1/8 9/19/2014 12:40:49PM Page 4 COMPASS 5000.1 Build 70 Halliburton M LL BURTD,, Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Company: Hilcorp Energy Company TVD Reference: SCU 21C-04 Prelim @ 171.O0usft Project: Soldotna CK Unit MD Reference: SCU 21C-04 Prelim @ 171.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 33-05 Survey Calculation Method: Minimum Curvature Wellbore: SCU 21C-04 Design: SCU 21 C-04 WP1.0 Formations viii*rtiripith. 'n ,,-,fir, .... ..,,., "eta MAe s fia";raAW:4490it 2 ns a mtama ,.a st a vog+ m,�« t.6, Measured Vertical Vertical ' Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (°) 11,592.99 10,469.35 SR_H5ST 11,391.22 10,326.47 SR_HIST 9,048.06 8,948.51 SR_TYNK_HP_H20 11,391.22 10,326.47 Bse HP H2O Sand 11,936.99 10,716.80 SR_H 10ST 11,758.69 10,588.55 SR_H7ST Plan Annotations 4' ' ---''''''''-- Measured Vertical Local Coordinates 4 „ 7- Depth Depth +N/-S +E/-W ; ",43:40,4°°11,4''1,. (usft) (usft) (usft) (usft) Comment :iiNt ata 8,035.00 8,032.26 83.24 115.71 KOP:Start Dir 12°/100':8035'MD,8032.26'TVD:45°RT TF 8,055.00 8,052.23 84.03 116.50 End Dir :8055'MD,8052.23'TVD 8,085.00 8,082.15 85.37 118.30 Start Dir 4°/100':8085'MD,8082.15'TVD 9,483.97 9,218.69 557.96 658.06 End Dir :9483.97'MD,9218.69'TVD 9,840.68 9,395.76 763.51 889.65 Start Dir 1°/100':9840.68'MD,9395.76'TVD 11,592.50 10,469.00 1,742.00 1,857.00 End Dir : 11592.5'MD, 10469'TVD 11,999.99 10,762.12 1,958.84 2,038.95 Total Depth: 12000'MD, 10766.02'TVD 9/19/2014 12:40:49PM Page 5 COMPASS 5000.1 Build 70 Z11 m o5 L m EC a1 M3 C M 0 J • .1 > L L m J. 3 Em o toa w a o 0 _ ra � N Q U d m N a •> U 1 • N CD d W 0 C °' N o Dcc N m in O .c U mi o a. OJ . N Z .. w O N O = N R M Qj = C p w N . N Y O O p v y = Y o p 3 y ■M U m = lC t TS Q- NM MOo O NN>Il 1111115 E NUM U O � tLL Q I ; k D a U QO � H t : flH M LT_i Icil Qmm OO M O O N N O O O V U MN N ._-. C 2 2 y c c fnU) U) tn U) •Ctc.) w3oinin > u) in Ni C. k) co '. a o c U �� 0 U c ....ir" 01 C i o 0 co m = O as L Vl a) 11111 . 1 1 111111 11111 CO CO V) V) (O Vi U) U) U) U) IO CO CO (0 (0 CO CO CO V) V) (/) V) (0 V) (0 N C. V) V) N V) (f) (/) CO N (f) V) V) (0 (0 V) (0 (n V) CO N N V) V) V) V) V) C"' (l0 0 0 Cl n. 0 CL CZ CL O O CO COLa aaaa0_ CL aCIS O aaa 0 C..) r..i C •,-. 0 1•+•1 -Oc c c c c c c y E Q) `o `o `o 8 0 9_ 0 0 2 8 0 g `o 0 5 0 0 0 `o 8 0 4 0 0 8 v 8 ti o m o 0 s v -i! y v is v v m v 0 co 7 C as co (o as C (o C co as (o fo co m () C (o (o m mu_ u_ u. u. aW m vu. u au 0_ LL aW aLL u. ,0 vu. LL C N 0 0 0 a) w 0) 0 N Q) 0 0 a) a) O a) a) a) a) a) O N a) a) 0 m p 0 cC 0 0 p U u p cn 0 0 co 0 U 0 N C co 0 u 0 U u u C C C C C C C C C C C C C C E a) (0 m m ca `) m (0 0)) a) 10 (0 a) as a) m a) as a) as as a) a) (a as Ec a) (o a) a) c p_ c0 c p_ (o (0 p• co 0- c0 Q N Q a) (0 C p_ cO co 3 o a) CD _0 CD 0 _ N CD = a) a) = a) = _0 = CD _ 0 CD CD _ a) a) Cr) U U U U U U W O O W O U U U W U W O W O W O U U W U U O N- co to V' M 0 O O CO V' V CD 6 W M CD CO N CO r (n N N oL O 0) N O LC) Co CO O N r 0) 0) N- O M CO 00 c0 6C) M O N- r 00 co M CD N- N W 00 r r 0 CO N d' V0 O (O O MCO r 0 0) CO (f) V r r N <- 00 O) 0) O M O IC) (O Co CO CO CO CO a0 V V Co O a) a1 Co m r r r r r r r r r r r r r (0• U.. U 9 LO N O O O Mr.- 1- 000 Cr) "Q'"if C` IC) V CO V CO O O O N- CO CO O N m 0) r o ta 0) M r O O O LU O M V cc) LC) V LC) V' O O O O O V O N- O W (O N- 6 O O O V vi N 0) V 4 6 7 u') u) 6 O V M M 6 .8.' .r N- N. 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O o 'tI MN - -- - _ o I I Irs _ 0 _ 0 0 Lo-t-- ----------- ----------- -- —oo N L ittil _ rn o 0 i 0 o u_ - o o OD CD _ m 0 as — T-.-__ —- o M • M 1 C 0 - g„ 4., o I _ ,.;I — -— [ d al 0. - 1 - o U _oo ma L. CU _ C C L 1 - O ; O _ ... ... �... .. - _O o ri— r _ v 0 a N - V) o - o L73o - CO ZL4 , CDN _ VS V OCI0 d —O OC NF. N N- a) IL O - o Io DY O iU O \ - ONiN CCI J — LI- ri � rr11Un1111 ( J11 U�n 111I � riiiU�) iiii � ill + E Nowl 0 V oo r` o CO 0 0 a 0 0. Qv) L 0 co r•-: c0 ,0 co N O cu CO CD (u!/oc z) io�oe j uoijeaedag o_ Q (� Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday, October 30, 2014 10:57 AM To: Davies, Stephen F(DOA) Subject: RE: SCU 21C-04 (PTD#214-169): Tyonek Water Sands Attachments: SCU 21C-04 aka 44-05ST Geoprog 9-22-14.xlsx You bet Steve! I thought I had replied back to you with the corrected GeoProg. The pressures are more realistically 10.5 ppg equivalent. Or around 4900 psi. My apologies. After Serbeck gave me the new numbers, I thought I had sent this to you. Keep in mind this is 4900 psi water. No gas associated with the pressure. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, October 30, 2014 10:45 AM To: Monty Myers Subject: SCU 21C-04 (PTD #214-169): Tyonek Water Sands Monty, In the Permit to Drill application for SCU 21C-04,Section 27.0, 6-1/8" Hole Section MASP,the calculation sheet on page 38 lists the estimated pressure for the Tyonek water sands as 2800 psi,or about 6.0 ppg EMW. This seems abnormally low for these sands. The accompanying geologic prognosis on page 32 does not list estimated pressures for the water sands. In the Permit to Drill application for SCU41B-04,the geologic prognosis on page 32 lists estimated pressure for the Tyonek water sands as 4300 to 4900 psi,which is about 9.1 to 10.5 ppg EMW. The MASP calculation sheet on page 38 lists pressure for these sands as 4850 to 4900 psi, or about 10.3 to 10.5 ppg EMW. Could Hilcorp please review the pressures anticipated in SCU 21C-04 and provide corrected values to AOGCC? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 1 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. 2 l I € WLA � SCU 21C aka 44 05ST Swanson River SCU 42-05 Pad SU ACEX 341744.38 Alaska I SURFACE'Y4 i 2457914.03.: 'BOTTOA4 HOLE X: 343809.58 KB -� __ BOTTOM HOLE Y ' 2459841.18 �,, 171 18'KB(Saxon 169) COQRD'REF SYSTEM INAD27 I 0=~w rve -e 152.4 WUSED TD:' i 12000.00 MD ,Pf OFOSED TD: i 10762.13,; TVD A sidetrack well out of the SCU 44-05 to the H1-8 benches. The well will offest the successful Objective: SCU 22-04 and SCU 31-04 wells. I I Geo Summary/ ^ Based on subsurface evaluation !Justification: i j _ to= 74;7.e,..z a. a 1eS�; t+i�, Ile�a .n unr� a �. atN�aumWh" _ -_ EXPECTED TOP Formation FORMATION FLUID MD i TVD Est Pressure X Y +/- SSTVD KOP 8034 8031 341866.2 2457997.1 -7860 HP-H20_SAND Wet Sand Water 9050 8950 4300-4900# 342158.3 2458244.0 20 -8779 3SE_HP-H20_KRE_GRIC Wet Sand Water 9271 9099 4300-4900# 342281.1 2458349.7 20 -8928 SR_G1ST Tyonek Oil Oil 11050 10096 2000-2600# 343363.8 2459343.0 20 -9925 SR_G25T Tyonek Oil Oil 11231 10217 2000-2600# 343456.1 2459441.1 20 -10046 SR HIST Hemlock Oil Oil 11384 10322 1000-1400# 343531.3 2459523.3 20 -10151 SR_H5ST Hemlock Oil Oil 1158610464 ,-, 1200-2800# 343625.4 2459630.3 20 -10293 SR_H7ST Hemlock Oil Oil 11758 10588 1200-2800# 343703.3 2459720.8 20 -10417 SR_H 1OST Hemlock Oil [ Oil 11936 10716 1200-2800# ,343784.1,2459814.6 20 -10545 _ .... 12000 10762 ########1######11# %r,,,;, , .1 ,04,1 ,1150 FT @ the Hemlock level I DATA Cot ...9 ` ,a ' S e _°°, Mud Logging• Full crew of 4 from KOP. LWD Data, Triple Combo LWD on Production hole section E-Line Lo. Data: COMPLETION TYPE Gas lift completion ANTICIPATED RATES 2000 bpd gross fluid ARTIFICIAL LIFT EQUIPMENT OD 1 TUBING SIZE 2 7/8"or 3.5" IIII OTHER COMMENTS •I I IIIIIII Offset wells have seen water flows and lost circulation in the lower Tyonek! We be be kicking off above the high pressured water sand and will encounter it in the well A ......,...�...«. ...»»».....« »»»..».».».«.... n.®�....m - a............... ...,eds.a,e m.m. ._......,...,.�,.m.n..:... .�.em.... »... ... e.®.md Davies, Stephen F (DOA) 71 1 From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, October 27, 2014 8:58 AM To: Davies, Stephen F (DOA) Subject: FW: SRU 21C-04 (PTD #214-169) Good morning Steve! Please see John's note below in reference to the logging we will be performing on the 21C-04. If you have any more questions, please let me know. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: John Serbeck Sent: Monday, October 27, 2014 8:54 AM To: Monty Myers Subject: RE: SRU 21C-04 (PTD #214-169) Monty, Is this what you are looking for? We will be kicking off in the Tyonek and drilling through the Hemlock 10 sand. Logging will consist of LWD triple combo (GR, Resistivity, neutron and density) john From: Monty Myers Sent: Friday, October 24, 2014 9:25 AM To: John Serbeck Subject: Fwd: SRU 21C-04 (PTD #214-169) Hey John. See Steves note below. Can you give him a list of what we will run for LWD.Thanks man! Monty M Myers 907.538.1168 Begin forwarded message: 1 Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, October 27, 2014 8:58 AM To: Davies, Stephen F (DOA) Subject: FW: SRU 21C-04 (PTD#214-169) Good morning Steve! Please see John's note below in reference to the logging we will be performing on the 21C-04. If you have any more questions, please let me know. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: John Serbeck Sent: Monday, October 27, 2014 8:54 AM To: Monty Myers Subject: RE: SRU 21C-04 (PTD #214-169) Monty, Is this what you are looking for? We will be kicking off in the Tyonek and drilling through the Hemlock 10 sand. Logging will consist of LWD triple combo (GR, Resistivity, neutron and density) john From: Monty Myers Sent: Friday, October 24, 2014 9:25 AM To: John Serbeck Subject: Fwd: SRU 21C-04 (PTD #214-169) Hey John. See Steves note below. Can you give him a list of what we will run for LWD.Thanks man! Monty M Myers 907.538.1168 Begin forwarded message: 1 From: "Davies,Stephen F (Dh.,.,)" <steve.davies@alaska.gov> Date: October 24, 2014 at 8:48:39 AM AKDT To: Monty Myers<mmyers@hilcorp.com> Subject: RE: SRU 21C-04(PTD#214-169) Monty, AOGCC just needs a list of logs that will be run in SRU 21C-04, and the intervals that will be logged. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Monday, October 20, 2014 1:46 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 21C-04 (PTD #214-169) Yes we will more than likely have LWD picked up for the logs on this well. We are currently looking into utilizing thru bit logging technology on some of our wells because of our recent stuck pipe incidents between both rigs. I am not sure if that technology will be available in time so LWD will be our primary method of logging. Let me know what info/schematics you would like to see for this and I can get it shipped over. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, October 20, 2014 12:15 PM To: Monty Myers Subject: RE: SRU 21C-04 (PTD #214-169) Monty, The reason I asked about the list of component parts for the BHA is because that's where I typically look to see if the LWD tools are scheduled to be run if LWD acquisition isn't specifically mentioned in the proposed drilling program. 2 I'm still unclear about this w,.. though. Does Hilcorp plan to record LWD ...easurements from the whipstock to the TD of the SRU 21C-04 well? If not, what downhole logs are planned? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Monday, October 20, 2014 10:49 AM To: Davies, Stephen F (DOA) Subject: RE: SRU 21C-04 (PTD #214-169) Sorry Steve, I missed this email on Friday. You are not missing anything. Up until recently we weren't running LWD on every well. We have been running them every well for probably the last 5 or 6 wells now though. All of the past approved PTD's haven't had any sort of BHA attached to them. If that is something that needs to be attached I am sure I can get one from Halliburton. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, October 17, 2014 11:01 AM To: Monty Myers Subject: FW: SRU 21C-04 (PTD #214-169) Monty, In addition to the question below, I didn't see LWD tools mentioned in the "14.0, Drill 6-1/8" Hole Section" portion of the application, only"14.1 P/U 6-1/8" directional drilling assy" and then "14.8 TIH to window.Shallow test MWD on trip in." Hilcorp also typically provides a list of component parts for the BHA, but I don't see that either. Am I missing something? 3 Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Friday, October 17, 2014 10:53 AM To: 'Monty Myers' Subject: RE: SRU 21C-04 (PTD #214-169) Monty, Another question: The estimated pressures are not listed on the Geo-Prog for the following horizons: HP-H20 Sand, BSE HP-H20 KRE Grid, GIST, and G2ST. Could Hilcorp please provide them? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Friday, October 17, 2014 10:51 AM To: Davies, Stephen F (DOA) Subject: RE: SRU 21C-04 (PTD #214-169) 4 Great question Steve! The ground elevation should be the 153.34 base on the survey from McLane. The KB should be 172'. Based on using 18.6' for Saxon 169. Great catch, I entered it wrong. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies(aalaska.gov] Sent: Friday, October 17, 2014 10:39 AM To: Monty Myers Subject: SRU 21C-04 (PTD #214-169) Monty, Quick question: on the Permit to Drill application form, the Ground Level elevation is listed as 170' and the KB elevation is listed as 188.6', but on the proposed directional survey,these elevations are listed as 171' and 153.34', respectively. Which values are correct? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 5 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST li WELL NAME: v / -« ` / Y dfxr PTD: '2-/ 7 /b7 i/ Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: C POOL:C/4i Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( 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 Spacing Exception conservation 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. 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CO 0) 0 - N CO) CO (O N- 00 O) 0 - N M V CO CO N. a0 0) I E ,- N co v co C) N. 00 0) N N N N N N N N (N N CO CO CO MC) M CO M M CO) O —_-__.__.._. _.-- - U v d U v O C O N O ca Alcc a, i a) ON ° o ct 0, 0 0 cc t- O O cN 0 cc c O 0 aUJ o c o o y.E (NI w a) >, O E J # •C a c a Cn o C. 0 0 W o E a L a) a � o a L > 0_ a Q W 4:( (-9 0 Qtn Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: Hilcorp Alaska, LLC Field: Soldotna Creek Rig: Saxon 169 Date: December 7, 2014 Surface Data Logging End of Well Report Soldotna Creek Unit 21C-04 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Hilcorp Alaska, LLC Rig: Saxon 169 Well: SCU 21C-04 Field: Soldotna Creek Borough: Kenai Borough State: Alaska Country: United States API Number: 50-133-20276-02-00 Sperry Job Number: AK-AM-0901806586 Job Start Date: 21 November 2014 Spud Date: 8 April 2014 Total Depth: 12,090’ MD, 10,806’ TVD North Reference: True Declination: 16.99° Dip Angle: 73.70° Total Field Strength: 55,477 nT Date of Magnetic Data: 17 September 2014 Wellhead Coordinates N: North 60° 43’ 29.23” Wellhead Coordinates W: West 150° 53’ 2.14“ Drill Floor Elevation 172.0’ Ground Elevation: 153.4’ Permanent Datum: Mean Sea Level SDL Engineers: Jeremy Tiegs, Jane Grundin SDL Sample Catchers: Justin Wiseman, Mario Luescher Company Geologist: John Serbeck Company Representatives: Joe Grubb, Rance Pederson, James Sweetsir, Jimmy Greco SSDS Unit Number: 117 Monitoring Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator Critical Spare Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator HOLE DATA Dates Drilled Hole Section Total Depth Mud Weight (ppg) Inclination (degrees) Casing Shoe Depth MD TVD MD TVD 11/23 – 12/04 6 1/8” 12,000 10,806 10.5 73.7 4.5” 12,089 10,806 DAILY SUMMARY 11/21/2014 SDL arrived on location, powered up unit, rigging up gas equipment. 11/22/2014 Finished running in hole and set whip stock. Displaced well from produced water to 9.5 ppg KCL drilling mud. Milled window- top of whip stock at 7,993’ MD, bottom of whip stock at 8,007’ MD. Dilled to 8,007’ MD and pumped sweep. Rig up for formation integrity test at time of report. Gas: The max gas was 8 units at 8,026’ MD and the average drilling background gas was 3 units. Fluids: There was no gain or loss of fluid in the hole. 11/23/2014 Completed formation integrity test to 12.3 ppg equivalent mud weight. Pumped dry job and tripped out of hole. Laid down milling assembly and picked up smart tools. Ran in hole to 7,777’ MD and slipped and cut drill line. Ran in hole to 8,020’MD, rigging up wire-line at time of report. Gas: The maximum trip gas seen was 26 units. Fluids: There was no gain or loss of fluid in the hole. 11/24/2014 Slid from 8,027' MD to 8,073' MD. Pulled out of hole with wire line side entry sub and rigged down wire line. Run in hole and wash down from 8,022' MD to 8,073' MD. Drill ahead from 8,073' MD to 8,414' MD. Drilling ahead at time of report. Gas: The maximum gas was 901 units at 8,027’ MD, the maximum trip gas was 64 units, and the maximum connection gas was 70 units. Fluids: There was no gain or loss of fluid in the hole. Geology: 70% Sand: loose quartz grains, clear-translucent with occasional orange, very fine to medium grain, sub-round, poorly sorted, loose, very silty; No show, odor, fluorescence, cut; 10% Sandstone; 10% Siltstone; 10% Coal. 11/25/2014 Drilled ahead to 8,415' MD and pumped sweep. Drilled ahead to 8,703' MD and checked flow, 5.2 bbl/hr. Drilled ahead to 8,878' MD and weighted up mud to 9.9 ppg. Drilled ahead to 8,767' MD and checked flow, 12 bbl/hr. Weighted up mud to 10 ppg, drilling ahead at time of report. Gas: The maximum gas was 3,152 units seen at 8,789’ MD and the maximum connection gas was 985 units. Fluids: There was no gain or loss of fluid in the hole. Geology: 80% Siltstone: light brown-grey, soft, fissile, amorphous; No stain, odor, fluorescence, cut; 10% Sandstone; 10% Sand. 11/26/2014 Drilled ahead from 8,968' MD to 9,020' MD; checked flow, 12 bph. Weighted up to 10.1 ppg, drilled ahead to 9,114' MD. Weighted up to 10.3 ppg and drilled ahead to 9,147' MD; checked flow, 9.7 bph. Drilled ahead to 9,209' MD and pumped sweep. Pull out of hole on elevators for wiper trip from 9,209' MD to 7,957' MD. Run in hole on singles, diluted mud to 10.0 ppg. Drilled ahead to 9.316' MD; drilling ahead at time of report. Gas: The maximum gas was 8,971 units seen at 9,209’ MD, the maximum connection gas was 3,704 units seen at 9,143’ MD, and the maximum trip gas was 855 units. Fluids: There was no gain or loss of fluid in the hole. Geology: 60 % Sand: translucent-transparent with occasional opaque, loose, fine-medium grain, moderately sorted, silty, tuffaceous; No stain, odor, fluorescence, cut; 20% Sandstone; 10% Siltstone; 10% Coal. 11/27/2014 Drilled to 9,322' MD and checked flow, 8.9 bph. Drilled to 9,384' MD and checked flow, 9.7 bph. Weight up mud to 10.5 ppg. Drilled to 9,760' MD, checked flow, 8.5 bph. Drilled to 9,886' MD, checked flow, 10.7 bph. Drilled to 9,890' MD and pumped sweep. Drilling ahead at time of report. Gas: The maximum formation gas was 990 units seen at 9,727’ MD and the maximum connection gas was 4,965 units seen at 9,448’ MD. Fluids: There was no gain or loss of fluid in the hole. Geology: 40% Siltstone : medium grey-brown, soft with occasional hard, blocky, homogenous- heterogeneous; No stain, odor, fluorescence, cut; 40% Sand : translucent-transparent, fine- medium grain, sub round, moderately sorted, silty; 10% Sandstone; 10% Coal. 11/28/2014 Drilled ahead to 10,200' MD checking flow at: 10,011' MD - 10 bph, 10,074' MD - 11 bph, 10,138' MD - 11bph. Pull out of hole for wiper trip at 10,200' MD. Run in hole on singles, once on bottom pumped sweep. Drilled ahead to 10,252' MD and checked flow, 10.7 bph. Drilling ahead at time of report. Gas: The maximum formation gas was 558 units seen at 9,931’ MD, the maximum connection gas was 6,114 units seen at 10,198’ MD, and the maximum trip gas was 178 units. Fluids: There was no gain or loss of fluid in the hole. Geology: 80% Sand: transparent-opaque, very fine-medium grain, sub-round, moderately sorted, silty, tuffaceous; No stain, odor, fluorescence, cut; 10% Siltstone, 10% Coal. 11/29/2014 Drilled ahead to 10,400' MD and checked flow, 10.7 bph. Drilled ahead to 10,504' MD and checked flow, 11 bph. Drilled ahead to 10,528' MD and pumped sweep, saw cuttings increase of 20%. Drilled ahead to 10,691' MD and checked flow, 11.2 bph. Drilling ahead at time of report. Gas: The maximum formation gas was 1,116 units seen at 10,514’ MD, and the maximum connection gas was 6,007 units seen at 10,567’ MD. Fluids: There was no gain or loss of fluid in the hole. Geology: 60% Siltstone: medium brown-grey, soft, blocky, heterogeneous, sandy; No stain, odor, fluorescence, cut; 20% Sandstone; 10% Sand; 10% Coal. 11/30/2014 Drilled ahead from 10,879' MD to 11,068' MD and checked flow, 11.6 bph. Drilled to 11,132' and circulated bottoms up 1,147 units of gas. Tripped out of hole on elevators to 10,151' MD and checked flow, 11.2 bph. Run in hole to 10,940' MD, washed down to 11,132’ MD and circulated bottoms up 7,378 units of gas. Drilling ahead at time of report. Gas: The maximum formation gas was 550 units seen at 10,758’ MD, the maximum connection gas was 4,267 units seen at 11,132’ MD, and the maximum trip gas seen was 7,378 units. Fluids: There was no gain or loss of fluid in the hole. Geology: 70% Sandstone: light grey, friable, amorphous, very fine-medium grain, sub round, moderately sorted, poorly cemented; No stain, odor, fluorescence, cut; 20% Sand; 10% Siltstone. 12/01/2014 Drilled ahead to 11,143' MD and pumped sweep. Drilled to 11,318' MD and checked flow, 12 bph. Drilled to 11,442 and checked flow, 11.5 bph. Drilling ahead at time of report. Gas: The maximum formation gas was 743 units seen at 11,393’ MD, and the maximum connection gas was 6,259 units seen at 11,318’ MD. Fluids: There was no gain or loss of fluid in the hole. Geology: 40% Siltstone: medium grey-brown, soft-firm, amorphous, homogenous, sand; No stain, odor, fluorescence, cut; 30% Sand: transparent-translucent, very fine-medium grain, sub round, poorly sorted; 20% Coal, 10% Sandstone. 12/02/2014 Drilled from 11,460' MD to 11,570' MD and pumped sweep. Drilled to 11,817' MD and checked flow, 11.7 bph. Increased mud weight to 10.6 ppg and drilled ahead to 11,941' MD. Checked flow, 11.5 bph. Drilling ahead at time of report. Total depth extended past 12,000' MD. Gas: The maximum formation gas was 1,027 units seen at 11,836’ MD, and the maximum connection gas was 4,986 units seen at 11,880’ MD. Fluids: There was no gain or loss of fluid in the hole. Geology: 70% Sand: translucent-transparent, very fine-medium grain with common very coarse Quartz grains, sub-round, poorly sorted, silty, common Tuff; SHOW: 20% spotty moderate yellow-orange fluorescence, no cut, faint white crush cut, no residual ring; 20% Sandstone; 10% Siltstone. 12/03/2014 Drilled from 11,967' MD to 12,003' MD and checked flow, 9.0 bph. Drilled to 12,090' MD and called total depth. Circulated bottoms up and short tripped to 11,102' MD. Ran in hole and tagged bottom, circulated bottoms up, and pumped sweep. Tripped out of hole to 7,944' MD and checked flow, 6 bph. Circulated bottoms up, spotted mud cap, pulled 17 stands and pumped dry job. Checked flow, 4.3 bph. Tripped out of hole to test blow out preventer, checked flow, 6.8 bph. Downloading bottom hole assembly at time of report. Gas: The maximum formation gas was 318 units seen at 12,020’ MD, the maximum connection gas was 4,256 units seen at 12,004’ MD, and the maximum trip gas was 8,465 units. Fluids: There was no gain or loss of fluid in the hole. Geology: 70% Sand: translucent – transparent, very fine-medium grain, sub round, moderately sorted, silty, trace Tuff; SHOW: no stain, slight odor, no cut, bright white crush cut, no residual ring; 20% Siltstone; 10% Coal. 12/04/2014 Tripped out of hole to surface, rig up and test blow out preventer. Serviced rig, picked up clean out assembly, and run in hole filling pipe every 3,000'. Circulated bottoms up at 6,278' MD, seeing 9,517 units of gas. Ran in hole to 7,9036' MD and circulated bottoms up, seeing 9,518 units of gas. Running in hole, 8,849' MD at time of report. Gas: There was no formation or connection gas, and the maximum trip gas seen was 9,518 units. Fluids: There was no gain or loss of fluid in the hole. 12/05/2014 Continued running in hole with tight spots at 8,455' MD, 8,608' MD, 8,695' MD, 8,763' MD. Circulated bottoms up at 8,763' MD seeing 8,946 units of gas. Water transitioned back to mud and circulated out sand and coal. Run in hole to 9,995' MD, circulated bottoms up 8,395 units of gas. Run in hole to 12,090’ MD, circulate bottoms up 5,976 units of gas. Spotted sweep on bottom, well flowing 3.6 bph. Tripped out of hole to 7,915' MD, slip and cut drill line, serviced rig. Circulated bottoms up and spotted mud cap pill, well flowing 3 bph while tripping out of hole. Tripping out of hole at 2,241' MD at time of report. Gas: There was no formation or connection gas, and the maximum trip gas seen was 8,946 units. Fluids: There was no gain or loss of fluid in the hole. 12/06/2014 Continued to trip out of hole to surface. Lay down clean out assembly, well flowing at 5.3 bph. Rig up Weatherford and run in hole w/ 4.5" production liner to 7,943' MD and circulate surface to surface seeing 7,986 units of gas with well flowing at 7 bph. Continued running in hole to 8,529' MD and circulate bottoms up 9,108 units of gas. Running in hole at 8,968' MD at time of report. Gas: There was no formation or connection gas, and the maximum trip gas seen was 9,108 units. Fluids: There was no gain or loss of fluid in the hole. 12/07/2014 Made up the cement head and circulated while building the mud push. Pressure tested lines and commenced cementing in the 4.5” casing. SDL team was released shortly after and began rigging down. Gas: There was no formation or connection gas, and the maximum bottoms up gas was 5590 units. Fluids: There was no gain or loss of fluid in the hole. 8000 9000 10000 11000 12000 0 5 10 15 20 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: Soldotna Creek Unit 21C-04 OPERATOR: Hilcorp Alaska, LLC MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: AK-XX-0901806586 Days vs. Depth 21 November 2014 Sperry SDL Arrived on Location LOCATION: Soldotna Creek AREA: Kenai Peninsula Borough STATE: Alaska SPUD: 8-April-2014 TD: 3-Dec-2014 Wiper Trip to Shoe 28 November 2014 Commenced 6.125" Production Hole Section On Bot: 00:52 24 Nov 2014 TD Production Hole Section 12090' MD, 10806' TVD Off Bot: 05:12 03 Dec 2014 Wiper Trip to Shoe 26 November 2014 Wiper Trip to Shoe 30 November 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: We had a chromatograph and an analyzer fail on us. The analyzer failed due to normal usage and just needs to be flow and gas calibrated. Gas lag was also affected by incorrect geometry for a significant part of the well. Recommendations: Additionally the geometry will be double checked by both data engineers and bottoms-up strokes will be confirmed across multiple PSL's. Innovations and/or cost savings: N/A Saxon 169 Jeremy Tiegs Soldotna Creek Kenai Peninsula Borough Alaska Production 4-Dec-2014 What went as, or better than, planned: We were able track fluids much better now that the fluid loss sheet is better understood by all personnel on site. We now have to gain a better understanding of how much the centrifuge takes out at certain levels in order to track volumes perfectly. Soldotna Creek Unit 21C-04 Hilcorp Alaska, LLC AK-XX-0901806586 Surface Data Logging After Action Review Surface Data Logging WELL NAME:Soldotna Creek Unit 21C-04 LOCATION:Soldotna Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:8-Apr-14 SPERRY JOB:AK-XX-0901806586 TD:3-Dec-2014 Marker MD INC AZ TVD TVDSS SR_73-5CT 7,084.6 3.0 39.0 7,070.0 -6,916.7 SR_74-5CT 7,190.8 3.0 39.0 7,177.0 -7,023.7 SR_75-3CT 7,251.5 3.0 39.0 7,236.0 -7,082.7 SR_TYNK_HP_H20 9,015.2 39.6 53.0 8,909.0 -8,755.7 HP-H20_SAND 9,055.0 43.1 53.2 8,939.0 -8,785.7 BSE_HP-H20_KRE_GRID 9,304.0 54.8 48.8 9,102.0 -8,948.7 SR_TYNK_CT14 9,388.3 57.8 48.7 9,148.0 -8,994.7 SR_TYNK_CT15 9,986.1 57.0 47.1 9,468.0 -9,314.7 SR_TYNK_CT16A 10,207.1 57.7 46.9 9,593.0 -9,439.7 SR_TYNK_CT16B 10,603.1 55.3 46.6 9,808.0 -9,654.7 SR_G1ST 11,071.0 50.3 43.8 10,098.0 -9,944.7 SR_G2ST 11,243.1 47.7 39.1 10,211.0 -10,057.7 Hemlock SR_H1ST 11,353.1 47.9 39.4 10,285.0 -10,131.7 SR_H1SB 11,414.0 48.0 39.4 10,326.0 -10,172.7 SR_H2ST 11,424.5 48.0 39.4 10,334.0 -10,180.7 SR_H2SB 11,455.3 47.9 39.2 10,354.0 -10,200.7 SR_H3ST 11,475.6 47.9 39.2 10,368.0 -10,214.7 SR_H3SB 11,590.4 47.5 38.8 10,443.0 -10,289.7 SR_H4ST 11,602.4 47.5 38.8 10,453.0 -10,299.7 SR_H4SB 11,623.1 47.5 38.8 10,467.0 -10,313.7 SR_H5ST 11,632.7 47.1 38.6 10,474.0 -10,320.7 SR_H5SB 11,744.0 47.0 38.8 10,549.0 -10,395.7 SR_H6ST 11,759.1 46.7 39.2 10,560.0 -10,406.7 SR_H6SB 11,802.7 46.7 39.2 10,590.0 -10,436.7 SR_H7ST 11,809.9 46.6 39.2 10,594.0 -10,440.7 SR_H8ST 11,891.7 46.2 39.0 10,651.0 -10,497.7 SR_H8SB 11,945.6 45.8 38.3 10,688.0 -10,534.7 Formation Tops Soldotna Creek Unit 21C-04 Hilcorp Alaska, LLC Baroid Saxon 169 AK-XX-0901806586 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 22-Nov 8018 9.50 45 10 17 6/7/8 5.2 37/27/23/16/6/4 1/2 4.1 0.0/93.2 -0.40 10.8 -0.20/0.80 33000 60 Drilling 4.5" Rathole 23-Nov 8027 9.55 50 9 18 6/8/9 4.6 36/27/22/17/6/5 1/2 4.3 0.0/93.0 -0.30 10.9 -0.10/0.80 33000 80 R/U Wireline 24-Nov 8414 9.53 50 12 17 5/6/7 4.6 41/29/24/17/5/4 1/2 4.4 0.0/93.0 -0.50 10.8 0.5 0.20/1.20 32500 40 Drilling 6 1/8" Production Hole 25-Nov 8951 9.92 53 14 18 5/6/7 4.3 46/32/25/18/5/4 1/2 6.1 0.0/91.5 0.10 0.50 10.7 1.3 0.70/2.50 29500 40 Drilling 6 1/8" Production Hole 26-Nov 9314 10.30 47 13 20 6/7/8 3.8 46/33/27/20/6/4 1/2 8.3 0.0/89.3 0.15 0.65 10.3 1.7 0.25/2.30 31000 40 Drilling 6 1/8" Production Hole 27-Nov 9930 10.50 58 15 21 6/8/11 3.8 51/36/29/21/6/4 1/2 9.5 0.0/88.0 0.15 0.90 10.7 3.0 0.30/2.30 33000 40 Drilling 6 1/8" Production Hole 28-Nov 10331 10.50 46 12 19 5/6/7 4.2 43/31/26/20/6/4 1/2 9.7 0.0/87.9 0.15 0.50 10.4 3.0 0.40/2.20 31000 40 Drilling 6 1/8" Production Hole 29-Nov 10693 10.50 47 14 19 5/7/9 4.1 47/33/28/20/6/4 1/2 9.4 0.0/88.2 0.10 0.55 10.5 3.3 0.45/2.40 31000 60 Drilling 6 1/8" Production Hole 30-Nov 11140 10.50 48 13 19 5/6/8 4.2 45/32/27/19/5/4 1/2 9.4 0.0/88.2 0.10 0.80 10.7 3.2 0.30/2.70 31000 40 Drilling 6 1/8" Production Hole 1-Dec 11461 10.55 53 15 20 5/6/8 4.4 50/35/29/21/6/4 1/2 9.6 0.0/88.0 0.10 0.70 10.7 3.0 0.40/2.60 31000 40 Drilling 6 1/8" Production Hole 2-Dec 11967 10.60 47 14 19 4/6/8 4.0 47/33/27/19/5/4 1/2 9.6 0.0/87.9 0.10 0.60 10.3 2.8 0.25/2.5 32000 40 Drilling 6 1/8" Production Hole 3-Dec 12090 10.62 49 13 19 5/8/10 4.6 45/32/27/19/6/5 1/2 9.7 0.0/87.8 0.10 0.60 10.2 3.0 0.50/3.00 32500 40 TD Production, Downloading BHA 4-Dec 12090 10.60 46 11 19 4/7/9 5.0 41/30/25/18/6/4 1/2 9.7 0.0/87.9 0.10 0.40 9.6 2.8 0.30/3.30 31500 40 RIH w/clean out assembly 5-Dec 12090 10.7 50 13 23 5/11/14 5.6 49/36/30/23/8/6 1/2 10.2 0.0/87.4 0.10 0.45 9.5 3 0.40/4.00 31000 40 Prep to run 4.5" Production liner 6-Dec 12090 10.7 49 12 21 6/10/13 5.5 45/33/27/20/7/5 1/2 10.3 0.0/87.3 0.10 0.70 10.1 3 0.50/4.40 31000 40 RIH W/4.5" production liner Casing Record Remarks 7.625" Casing @ 3798' MD, 3796' TVD 7.625" Casing @ 5733' MD, 5725'TVD 7.625" Casing @ 8007' MD, 7987'TVD 4.5" Casing @ 12089' MD, 10805'TVD WELL NAME:LOCATION:Soldotna Creek OPERATOR:AREA:Kenai Peninsula Borough MUD CO:STATE:Alaska RIG:SPUD:8-Apr-14 SPERRY JOB:TD:3-Dec-2014 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 3 300 1 HDBS MM55 6.125 8027 12090 4063 206.10 0.552 25.0 14 90 2080 280 1-5-BT-G-X-2-CT-TD 6.125" Production Hole Section Alaska RIG:Saxon 169 SPUD:8-Apr-14 WELL NAME:Soldotna Creek Unit 21C-04 LOCATION:Soldotna Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO: SPERRY JOB:AK-XX-0901806586 TD:3-Dec-2014 Baroid STATE: B i t R e c o r d . . * 24 hr Recap: (max)(current) Cly Set AtSize Grade 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5nC-2 in Minimum Depth Time: Geology: N/A N/A 11200' Max @ ft Current Date: Avg Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) J. Grubb/ J. Sweetsir ShClyst TuffGvlCoal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901806586 PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) Depth in / out Mud Type Lst Type Average -Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 Units-Connection Fluids: N/A Max Gas: N/A ConditionBit #Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River ROP ROP (ft/hr) 3.07 @ Mud Data Depth 21-Nov-2014 23:59 Current Pump & Flow Data: Max Chlorides mg/l Personnel on location, powered up unit, rigging up gas equipment. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Finished RIH and set whipstock. Displaced well from produced water to 9.5 ppg KCL drilling mud. Milled window- TOW@ 7,993'MD, Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 60 22-Nov-2014 23:59 Current Pump & Flow Data: 1449 Max ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 4.1 6.625BHC/ Mill Bit 2.00 Size Fluids: 0 bbls Max Gas: 8 units 100% Gas In Air=10,000 Units-Connection Tools API FL Chromatograph (ppm) WOB N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 1Background (max)Trip Average - Mud Type Lst Type KCL/Polymer 5.28018'17 Depth in / out YP (lb/100ft2) 10.80 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6.5" Rathole PV Footage J. Grubb/ J. Sweetsir ShClyst TuffGvlCoal cP 10 Gas Summary (current) Avg Yesterday's Depth: Current Depth: 24 Hour Progress: 12.0 Flow In (gpm) Flow In (spm) 8012' 8026' 14' Max @ ft Current 8015'8.1 Date: Time: Geology: N/A BOW@ 8,007'MD. Drilled T/8,007'MD and pumped sweep. Drilled T/8,207'MD and pumped sweep. R/U for FIT test at time of report. 3 in 0Minimum Depth C-5n 0.0 C-2 8 SPP (psi) Gallons/stroke TFABit Type Depth 45 MBT pH 0.633 Siltst 394 1209 Units* Casing Summary Lithology (%) 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize Grade (max)(current) Cly . . * 24 hr Recap: Completed FIT test to 12.3 ppg EMW. Pumped dry job and TOOH. L/D milling assembly and P/U smart tools. RIH T/7,777'MD and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 33000 23-Nov-2014 23:59 Current Pump & Flow Data: 0 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 4.3 6.625BHC/ Mill Bit 9.55 Size 1 Fluids: 0 bbls Max Gas: 0 units 100% Gas In Air=10,000 Units-Connection Tools API FL Chromatograph (ppm) 8026' WOB N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 26 Mud Type Lst Type HDBS MM55 KCL/Polymer 4.6 8026' 8027'18 Depth in / out YP (lb/100ft2) 10.90 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901806586 R/U Wireline PV 6.125 0.552 Footage J. Grubb/ J. Sweetsir ShClyst TuffGvlCoal cP 9 Gas Summary (current) Avg Yesterday's Depth: Current Depth: 24 Hour Progress: 12.0 Flow In (gpm) Flow In (spm) 8026' 8026' 0' Max @ ft Current 8015'0.0 Date: Time: Geology: N/A slip and cut. RIH T/8,020'MD, R/U wireline at time of report. 0 in 0Minimum Depth C-5n 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 50 MBT pH 0.633 Siltst 0 0 Units* Casing Summary Lithology (%) 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize Grade (max)(current) Cly . . * 24 hr Recap:Slid F/8,027'MD T/8,073'MD. POOH w/wire line side entry sub and R/D wire line. RIH and wash down F/8,022'MD Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32500 0 24-Nov-2014 23:59 Current Pump & Flow Data: 1404 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 4.4 6.625BHC/ Mill Bit 9.53 Size 1 Fluids: 0 bbls Max Gas: 901 units 3372' 44' 100% Gas In Air=10,000 Units70Connection 1 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Conductor N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 6Background (max)Trip Average 64 Mud Type Lst 10 Type HDBS MM55 KCL/Polymer 4.6 8026' 8414'17 Depth in / out YP (lb/100ft2) 10.80 000 00 CementChtSd C-4i C-4n 24 hr Max 40.5 Weight 0 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage J. Grubb/ J. Sweetsir ShClyst 10 TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 229.8 Flow In (gpm) Flow In (spm) 8026' 8415' 389' Max @ ft Current 8381'42.1 Date: Time: Geology: 70% Sand: lse qtz gns, clr-transl w/occ or, vf-med gr, sbrnd, pr srt, lse, v slt; NSOFC ; 10% Sst ; 10% Siltst; 10% C. T/8,073'MD. Drill ahead F/8,073'MD T/8,414'MD. Drilling ahead at time of report. 35 in 6 8402'Minimum Depth C-5n 8027' 10.4 C-2 901 SPP (psi) Gallons/stroke TFABit Type Depth 50 MBT pH 0.633 0 0 0 Siltst 10.75" 252 84 Units* Casing Summary Lithology (%) 0 10 4560 129 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize Grade 20.00'' (max)(current) Surface 0 0 Cly 8776 70 . . * 24 hr Recap:Drilled ahead T/8,415'MD and pumped sweep. Drilled ahead T/8,703'MD and checked flow, 5.2 bbl/hr. Drilled Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29500 8 25-Nov-2014 23:59 Current Pump & Flow Data: 1647 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 6.1 6.625BHC/ Mill Bit 9.92 Size 1 Fluids: 0 bbls Max Gas: 3152 units to 10 ppg, drilling ahead at time of report. 3372' 44' 100% Gas In Air=10,000 Units985Connection 28 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Conductor N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 145Background (max)Trip Average N/A Mud Type Lst 10 Type HDBS MM55 KCL/Polymer 4.3 8026' 8951'18 Depth in / out YP (lb/100ft2) 10.70 000 00 CementChtSd C-4i C-4n 24 hr Max 40.5 Weight 0 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage J. Grubb/ J. Sweetsir ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 90.8 Flow In (gpm) Flow In (spm) 8415' 8969' 554' Max @ ft Current 8726'47.3 Date: Time: Geology: 80% Silt : lt bn-gry, sft, fis, amor; NSOFC; 10% Sst; 10% Sd. ahead T/8,878'MD and weighted up mud to 9.9 ppg. Drilled ahead T/8,767'MD and checked flow, 12 bbl/hr. Weighted up mud 274 in 2 8929'Minimum Depth C-5n 8789' 11.5 C-2 3152 SPP (psi) Gallons/stroke TFABit Type Depth 1.353 MBT pH 0.633 0 0 0 Siltst 10.75" 252 87 Units* Casing Summary Lithology (%) 0 80 39660 21062 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize Grade 20.00'' (max)(current) Surface 0 0 Cly 99180 10 . . * 24 hr Recap:Drilled ahead F/8,968' MD T/9,020' MD; checked flow, 12 bph. Weighted up to 10.1 ppg, drilled ahead T/9,114' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 13 26-Nov-2014 23:59 Current Pump & Flow Data: 1657 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 8.3 6.625BHC/ Mill Bit 10.30 Size 1 Fluids: 0 bbls Max Gas: 8971 units ahead at time of report. POOH on elevators for wiper trip F/9,209' MD T/7,957' MD. RIH on singles, diluted mud to 10.0. Drilled ahead T/9.316' MD; drilling 3372' 44' 100% Gas In Air=10,000 Units3704Connection 29 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Conductor N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 407Background (max)Trip Average 855 Mud Type Lst 20 Type HDBS MM55 KCL/Polymer 3.8 8026' 9314'20 Depth in / out YP (lb/100ft2) 10.30 000 00 CementChtSd C-4i C-4n 24 hr Max 40.5 Weight 3 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage R. Pederson/ J. Sweetsir ShClyst 10 TuffGvlCoal cP 13 Gas Summary 0 0 0 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 95.0 Flow In (gpm) Flow In (spm) 8969' 9316' 347' Max @ ft Current 9288'42.8 Date: Time: Geology: 60 % Sand: trans-transp w/occ opq, lse, f-med gr, mod srt, slt, tf; NSOFC; 20% Sandstone; 10% Siltstone; 10% Coal. Weighted up to 10.3 ppg and drilled ahead T/9,147' MD; checked flow, 9.7 bph. Drilled ahead T/9,209' MD and pumped sweep. 429 in 5 8983'Minimum Depth C-5n 9209' 11.0 C-2 8971 SPP (psi) Gallons/stroke TFABit Type Depth 1.747 MBT pH 0.633 0 1 0 Siltst 10.75" 252 86 Units* Casing Summary Lithology (%) 0 10 33442 24780 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize Grade 20.00'' (max)(current) Surface 97 0 Cly 87863 60 . . * 24 hr Recap: Drilled T/9322'MD and checked flow, 8.9 bph. Drilled T/9384'MD and checked flow, 9.7 bph. Weight up mud to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 33000 17 27-Nov-2014 23:59 Current Pump & Flow Data: 1858 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 9.5 6.625BHC/ Mill Bit 10.50 Size 1 srt, slt; 10% Sandstone; 10% Coal. Geology: 40% Siltstone : med gry-bn, sft w/occ hrd, blky, homog-heterog; NSOFC; 40% Sand : trans-transp, f-med gr, sb rnd, mod Fluids: 0 bbls Max Gas: 990 units pumped sweep. Drilling ahead at time of report. 3372' 44' 100% Gas In Air=10,000 Units4965Connection 19 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Conductor N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 312Background (max)Trip Average N/A Mud Type Lst 10 Type HDBS MM55 KCL/Polymer 3.8 8026' 9930'21 Depth in / out YP (lb/100ft2) 10.70 000 00 CementChtSd C-4i C-4n 24 hr Max 40.5 Weight 53 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage R. Pederson/ J. Sweetsir ShClyst 10 TuffGvlCoal cP 15 Gas Summary 0 0 0 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 102.0 Flow In (gpm) Flow In (spm) 9316' 9930' 614' Max @ ft Current 9577'56.3 Date: Time: 10.5 ppg. Drilled T/9760'MD, checked flow, 8.5 bph. Drilled T/9886'MD, checked flow, 10.7 bph. Drilled T/9890'MD and 468 in 22 9428'Minimum Depth C-5n 9727' 5.3 C-2 990 SPP (psi) Gallons/stroke TFABit Type Depth 3.058 MBT pH 0.633 0 0 0 Siltst 10.75" 246 85 Units* Casing Summary Lithology (%) 0 40 51307 1543 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize Grade 20.00'' (max)(current) Surface 73 0 Cly 82677 40 . . * 24 hr Recap: (max)(current) Surface 48 21 Cly 41605 80 Set AtSize Grade 20.00'' 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 10 69065 25453 10.75" 249 87 Units* Casing Summary Lithology (%) 6 MBT pH 0.633 4 16 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.046 C-5n 9931' 64.7 C-2 558 in 102 10175'Minimum Depth Time: wiper trip at 10,200' MD. RIH on singles, once on bottom pumped sweep. Drilled ahead T/10,252'MD and checked flow, 10.7 bph. 520 9930' 10315' 385' Max @ ft Current 10206'39.2 Date: Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 105.9 Flow In (gpm) Flow In (spm) Gas Summary 0 1 0 (current) R. Pederson/ J. Sweetsir ShClyst 10 TuffGvlCoal cP 12 6.125 0.552 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 24 hr Max 40.5 Weight 102 Hours C-3 00 CementChtSd C-4i C-4n YP (lb/100ft2) 10.40 000 HDBS MM55 KCL/Polymer 4.2 8026' 10331'19 Depth in / out Mud Type Lst Type Average 178249Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Conductor 100% Gas In Air=10,000 Units6114Connection 19 1 Geology: 80% Sand : trans-opq, vf-med gr, subrnd, mod srt, slt, tf; NSOFC; 10% Siltstone, 10% Coal. Fluids: 0 bbls Max Gas: 558 units Drilling ahead at time of report. 3372' 44' ConditionBit # 9.7 6.625BHC/ Mill Bit 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River New ROP ROP (ft/hr) 3.07 @ Mud Data Depth 28-Nov-2014 23:59 Current Pump & Flow Data: 1650 Max 37 Chlorides mg/l 31000 Drilled ahead T/10,200'MD checking flow at: 10,011'MD-10 bph, 10,074'MD-11 bph, 10,138'MD-11bph. POOH for Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled ahead T/10,400'MD and checked flow, 10.7 bph. Drilled ahead T/10,504' MD and checked flow, 11 bph. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 12 29-Nov-2014 23:59 Current Pump & Flow Data: 1685 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 9.4 6.625 10.50 BHC/ Mill Bit 10.50 Size 1 Geology: 60% Siltstone : med brn-gry, sft, blky, heterog, sd; NSOFC; 20% Sandstone; 10% Sand; 10% Coal. Fluids: 0 bbls Max Gas: 1116 units 11.2 bph. Drilling ahead at time of report. 6906' 5733' 100% Gas In Air=10,000 Units6007Connection 16 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 192Background (max)Trip Average N/A Mud Type Lst 20 Production Type HDBS MM55 KCL/Polymer 4.1 8026' 10692'19 Depth in / out YP (lb/100ft2) 10.50 000 00 CementChtSd C-4i C-4n 24 hr Max 29.7 Weight 49 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage R. Pederson/ J. Sweetsir ShClyst 10 TuffGvlCoal cP 14 33.8 Gas Summary 0 0 0 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 102.8 Flow In (gpm) Flow In (spm) 10315' 10693' 378' Max @ ft Current 10409'36.6 Date: Time: Drilled ahead T/10,528'MD and pumped sweep, saw cuttings increase of 20%. Drilled ahead T/10,691'MD and checked flow, 443 in 5 10391'Minimum Depth C-5n 10514' 0.0 C-2 1116 SPP (psi) Gallons/stroke TFABit Type Depth 3.350 N-80 MBT pH 0.633 0 0 0 Siltst 7 5/8" 252 87 Units* Casing Summary Lithology (%) 0 60 54866 140 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" (max)(current) Production 65 0 Cly 71463 10 . . * 24 hr Recap: Drilled ahead F/10,879' MD - T/11,068' MD and checked flow, 11.6 bph. Drilled T/11,132' and CBU 1147U gas. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 14 30-Nov-2014 23:59 Current Pump & Flow Data: 1578 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 9.4 6.625 10.50 BHC/ Mill Bit 10.50 Size 1 Geology: 70% Sandstone : lt gry, fri, amor, vf-med gr, sb rnd, mod srt, pr cmtd; NSOFC; 20% Sand; 10% Siltstone. Fluids: 0 bbls Max Gas: 550 units Drilling ahead at time of report. 6906' 5733' 100% Gas In Air=10,000 Units4267Connection 11 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 305Background (max)Trip Average 7378 Mud Type Lst 70 Production Type HDBS MM55 KCL/Polymer 4.2 8026' 11140'19 Depth in / out YP (lb/100ft2) 10.70 000 00 CementChtSd C-4i C-4n 24 hr Max 29.7 Weight 67 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage R. Pederson/ J. Sweetsir ShClyst TuffGvlCoal cP 13 33.8 Gas Summary 0 0 0 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 63.5 Flow In (gpm) Flow In (spm) 10693' 11140' 447' Max @ ft Current 10840'44.5 Date: Time: TOOH on elevators T/10,151' MD and checked flow, 11.2 bph. RIH T/10,940' MD, washed down T/11,132 and CBU 7378U gas. 320 in 8 10912'Minimum Depth C-5n 10758' 2.8 C-2 550 SPP (psi) Gallons/stroke TFABit Type Depth 3.248 N-80 MBT pH 0.633 5 0 0 Siltst 7 5/8" 249 86 Units* Casing Summary Lithology (%) 0 10 37164 14608 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" (max)(current) Production 48 18 Cly 54633 20 . . * 24 hr Recap: (max)(current) Production 772 34 Cly 56379 30 Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" 907-283-1309Unit Phone: 134 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 40 35627 17610 7 5/8" 252 87 Units* Casing Summary Lithology (%) 94 N-80 MBT pH 0.633 8 238 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.053 C-5n 11393' 31.1 C-2 743 in 134 11155'Minimum Depth Time: Coal, 10% Sandstone. T/11,442 and checked flow, 11.5 bph. Drilling ahead at time of report. 337 11140' 11460' 320' Max @ ft Current 11382'29.4 Date: Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 51.1 Flow In (gpm) Flow In (spm) 33.8 Gas Summary 0 448 126 (current) R. Pederson/ J. Sweetsir ShClyst 20 TuffGvlCoal cP 15 6.125 0.552 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 24 hr Max 29.7 Weight 271 Hours C-3 00 CementChtSd C-4i C-4n YP (lb/100ft2) 10.70 5018146 HDBS MM55 KCL/Polymer 4.4 8026' 11461'20 Depth in / out Mud Type Lst 10 Production Type Average N/A203Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Production 100% Gas In Air=10,000 Units6259Connection 1056 1 Geology: 40% Siltstone : med gry-bn, sft-frm, amor, homog, sd; NSOFC; 30% Sand : trans-transl, vf-med gr, sub rnd, pr srt; 20% Fluids: 0 bbls Max Gas: 743 units 6906' 5733' ConditionBit # 9.6 6.625BHC/ Mill Bit 10.55 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River New ROP ROP (ft/hr) 3.07 @ Mud Data Depth 1-Dec-2014 23:59 Current Pump & Flow Data: 1981 Max 404 Chlorides mg/l 31000 Drilled ahead T/11,143' MD and pumped sweep. Drilled T/11,318' MD and checked flow, 12 bph. Drilled Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled F/11,460' MD T/11,570' MD and pumped sweep. Drilled T/11,817' MD and checked flow, 11.7 bph. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32000 478 2-Dec-2014 23:59 Current Pump & Flow Data: 2074 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 9.6 6.625 10.55 BHC/ Mill Bit 10.60 Size 1 Geology: 70% Sand : trans-transp, vf-med gr w/comm v crs Qtz gr, sub rnd, prly srt, slt, com Tf; SHOW: 20% spty mod yel-or Fluids: 0 bbls Max Gas: 1027 units TD extended past 12,000' MD. 6906' 5733' 100% Gas In Air=10,000 Units4986Connection 1944 Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 207Background (max)Trip Average N/A Mud Type Lst 20 Production Type HDBS MM55 KCL/Polymer 4.0 8026' 11957'19 Depth in / out YP (lb/100ft2) 10.30 6721056 1775 CementChtSd C-4i C-4n 24 hr Max 29.7 Weight 482 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Drilling 6 1/8" Production Hole PV 6.125 0.552 Footage R. Pederson/ J. Greco ShClyst TuffGvlCoal cP 14 33.8 Gas Summary 16 922 288 (current) Avg to8026' Yesterday's Depth: Current Depth: 24 Hour Progress: 57.3 Flow In (gpm) Flow In (spm) 11460' 11967' 507' Max @ ft Current 11900'36.6 Date: Time: fluor, n ct, fnt wh crsh ct, n rr; 20% Sandstone; 10% Siltstone. Increased MW to 10.6 ppg and drilled ahead T11,941' MD. Checked flow, 11.5 bph. Drilling ahead at time of report. 418 in 204 11447'Minimum Depth C-5n 11836' 39.7 C-2 1027 SPP (psi) Gallons/stroke TFABit Type Depth 2.847 N-80 MBT pH 0.633 159 502 37 Siltst 7 5/8" 252 86 Units* Casing Summary Lithology (%) 104 10 49495 23349 907-283-1309Unit Phone: 313 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" (max)(current) Production 1473 115 Cly 95661 70 . . * 24 hr Recap: (max)(current) Production 1473 227 Cly 95661 70 Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" 907-283-1309Unit Phone: 313 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 20 33809 36080 7 5/8" 0 0 Units* Casing Summary Lithology (%) 114 N-80 MBT 12053' pH 0.633 126 502 41 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.049 C-5n 12020' 0.0 C-2 318 in 190 12013'Minimum Depth Time: 20% Siltstone; 10% Coal. short tripped T/11,102' MD. RIH and tagged bottom, CBU, and pumped sweep. TOOH T/7,944' MD and checked flow, 6 bph. 410 11967' 12090' 123' Max @ ft Current 11982'38.1 Date: Avg to8044' Yesterday's Depth: Current Depth: 24 Hour Progress: 45.7 Flow In (gpm) Flow In (spm) 33.8 Gas Summary 0 922 288 (current) R. Pederson/ J. Greco ShClyst 10 TuffGvlCoal cP 13 6.125 0.552 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Downloading BHA PV 24 hr Max 29.7 Weight 142 Hours C-3 962 CementChtSd C-4i C-4n YP (lb/100ft2) 10.20 5711973 HDBS MM55 KCL/Polymer 4.6 8026' 12090'19 Depth in / out Mud Type Lst Production Type Average 84652Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Production 100% Gas In Air=10,000 Units4256Connection 1944 1 Geology: 70% Sand : transl-transp, vf-med gr, sub rnd, mod srt, slt, tr tf; SHOW: no stn, sl od, no ct, brt wh crsh ct, no rr; Fluids: 0 bbls Max Gas: 318 units Downloading BHA at time of report. CBU, spotted mud cap, pulled 17 stands and pumped dry job. Checked flow, 4.3 bph. TOOH to test BOP, checked flow, 6.8 bph. 6906' 5733' ConditionBit # 9.7 6.625BHC/ Mill Bit 10.62 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River New ROP ROP (ft/hr) 3.07 @ Mud Data Depth 3-Dec-2014 23:59 Current Pump & Flow Data: 0 Max 138 Chlorides mg/l 32500 Drilled F/11,967' MD T/12,003' MD and checked flow, 9.0 bph. Drilled T/12,090' MD and called TD. CBU and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:TOOH T/surface, R/U and test BOP. Serviced rig, P/U clean out assembly, and RIH filling pipe every 3,000'. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31500 - 4-Dec-2014 23:59 Current Pump & Flow Data: 0 Max New ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 9.7 6.625BHC/ Mill Bit 10.60 Size 1 Geology: N/A Fluids: 0 bbls Max Gas: N/A 6906' 5733' 100% Gas In Air=10,000 Units-Connection - Tools Gamma/Res API FL Chromatograph (ppm) 8026' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average 9518 Mud Type Lst Production Type HDBS MM55 KCL/Polymer 5.0 8026' 12090'19 Depth in / out YP (lb/100ft2) 9.60 --- -- CementChtSd C-4i C-4n 24 hr Max 29.7 Weight - Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 TIH w/clean out assembly PV 6.125 0.552 Footage R. Pederson/ J. Greco ShClyst TuffGvlCoal cP 11 33.8 Gas Summary - -- (current) Avg to8044' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 12090' 12090' 0' Max @ ft Current -- Date: Time: CBU @ 6,278' MD seeing 9517 units of gas. RIH T/7,9036' MD and CBU seeing 9,518 units. RIH @ 8,849' MD at time of report. - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.846 N-80 MBT 12053' pH 0.633 - - - Siltst 7 5/8" 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" (max)(current) Production - - Cly - . . * 24 hr Recap:Continued RIH w/tight spots @ 8,455'MD, 8,608'MD, 8,695'MD, 8,763'MD. CBU @ 8,763' MD seeing 8,946 units of Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 - 5-Dec-2014 23:59 Current Pump & Flow Data: 0 Max 1-5-BT-G-X-2-CT-TD ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 10.2 6.625BHC/ Mill Bit 10.70 Size 1 Geology: N/A Fluids: 0 bbls Max Gas: N/A and spotted mud cap pill, well flowing 3 bph while TOH. TOH @ 2,241' MD at time of report. CBU 5,976 units of gas. Spotted sweep on bottom, well flowing 3.6 bph. TOOH T/7,915' MD, slip/cut drill line, serviced rig. CBU 6906' 5733' 100% Gas In Air=10,000 Units-Connection - Tools Gamma/Res API FL Chromatograph (ppm) 14 8026' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 1Background (max)Trip Average 8946 Mud Type Lst Production Type 90HDBS MM55 KCL/Polymer 5.6 8026' 12090'23 12090' Depth in / out YP (lb/100ft2) 9.50 --- -- CementChtSd C-4i C-4n 24 hr Max 29.7 Weight - Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Prep to run 4.5" Production Liner PV 6.125 0.552 Footage 206.10 4064' R. Pederson/ J. Greco ShClyst TuffGvlCoal cP 13 33.8 Gas Summary - -- (current) Avg to8044' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 12090' 12090' 0' Max @ ft Current -- Date: Time: gas. Water transitioned back to mud and circulated out sand and coal. RIH T/9,995' MD, CBU 8,395 units of gas. RIH T/12,090, - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 3.050 N-80 MBT 12090' pH 0.633 - - - Siltst 7 5/8" 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" (max)(current) Production - - Cly - . . * 24 hr Recap: (max)(current) Production - - Cly - Set AtSize 26.4 N-80 Grade N-808007' 7 5/8" 7 5/8" 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7 5/8" 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 12090' pH 0.633 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.049 C-5n - - C-2 - in --Minimum Depth Time: 4.5" production liner T/ 7,943' MD and CSS seeing 7,986 units of gas with well flowing @ 7 bph. Continued RIH T. 8,529' MD - 12090' 12090' 0' Max @ ft Current -- Date: Avg to8044' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 33.8 Gas Summary - -- (current) R. Pederson/ J. Greco ShClyst TuffGvlCoal cP 12 6.125 0.552 Footage 206.10 4064' Sst (ppb Eq) C-1 C-5i AK-AM-0901806586 Running 4.5" Production Liner PV 24 hr Max 29.7 Weight - Hours C-3 -- CementChtSd C-4i C-4n YP (lb/100ft2) 10.10 --- 90HDBS MM55 KCL/Polymer 5.5 8026' 12090'21 12090' Depth in / out Mud Type Lst Production Type Average 9108254Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma/Res API FL Chromatograph (ppm) 14 8026' WOB Production 100% Gas In Air=10,000 Units-Connection - 1 Geology: N/A Fluids: 0 bbls Max Gas: N/A and CBU 9,108 units of gas. RIH@ 8,968' MD at time of report. 6906' 5733' ConditionBit # 10.3 6.625BHC/ Mill Bit 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: SCU 21C-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River 1-5-BT-G-X-2-CT-TD ROP ROP (ft/hr) 3.07 @ Mud Data Depth 6-Dec-2014 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 31000 Continued to TOOH T/ surface. L/D clean out assembly, well flowing at 5.3 bph. R/U Weatherford and RIH w/ Density (ppg) out (sec/qt) Viscosity Cor Solids %
