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214-090
Hilcurp Ala.k.. MA: DATE 11/19/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL ISCU 31-04(214-090) CD 1: PRODUCTION PROFILE RELD_DATA ANALY'S[S 11/14/20182:39PN1 Filefolder 11/19/2p,192:51 PM Filefolder Please include current contact information if different from above. 21 4090 3 145 6 RECEIVED NOV 19 2019 AOGCC Please acknowledge receipt by_,�igning and returning one copy of this transmittal or FAX to 907 777.8337 Received By: iJ j A //j STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 i 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Pull Tubing Ll Operabons shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ =_rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Install Cap String Q 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 15. Permit to Drill Number: Name: Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 214-090 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-13-10106-02-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028997 Soldotna Creek Unit (SCU) 31-04 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 11,775 feet Plugs measured N/A feet true vertical 10,636 feet Junk measured N/A feet Effective Depth measured 11,649 feet Packer measured 8,913 feet true vertical 10,573 feet true vertical 8,912 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11-3/4" 1,413' 1,413' 3,070psi 1,510psi Intermediate Production 9,143' 7-5/8" 9,143' 9,142' 6,890psi 4,790psi Liner 2,826' 4-1/2" 11,773' 10,635' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 8,945' MD 8,945' TVD N/A; Packers and SSSV (type, measured and true vertical depth) DLH Hydraul Pkr 8,913' MD 8,912' TVD 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: 194 3 463 860 140 Subsequent to operation: 153 1 512 950 170 14. Attachments (required per 20 MC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory[] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil e Gas L WDSPL LJ 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: 318-221 Authorized Name: Be York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCdhilcoro.cem Authorized Si nature: - Date: 2�1�c6 2019 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 0'0141 -?-7-1 y RBDM93LRB 2 7 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 31-04 50-133-10106-02 214-090 6/9/18 6/9/18 Daily Operations: 06/09/2018-Saturday Pollard rig up on well, perg coil string with DMO and test gwill to 3200psi opening pressure, run cap string in hole to 8900ft, set clamps and rig down lHilcoru Alaska, LLC 0 RKB: 171.1'/ GL: 152.5' AMSL KB—THF: 11.3' (WO Rig) 1 22" 2 1 28' 11-3/4" ,. 1,413' EST TOC 4,220' 'c 6[ 7[ x� 9 10 11 TOL 8,947' EST TOC 8,993' 7-5/8" 9,143' RA Mrk.lt SCU 31-04 Schematic ;, C as in a & T u b in a Size Type Wt Grade ID Top Btm Hole Cmt Cott To 22" Conductor 2.992" 3.500" Pups, 3-1/2" 8RD Surf 28' 2.992" unknown Surf. 11-'G" Surf Cs 47 1-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 7-%" Prod Csg 39 33.7 29.7 33 7 39 N-80 6.625" 6.765" 6.875" 6.765" 6.625" Surf 13P 3,623' 5,654' 6,552' 13P 3 623' 5,654' 6,552' 6,983' 10-'/." 1,000 Sx 4,220' EST 8 8,895' 995.250" 7-'/." 7-%" DV Collar 6,983' 6,986' 8,913' 3.00D" 7-'/." 39 N-80 6.625" 6,986' 9,143' '00'! 8,993' EST 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-'%" 353 sx 9,273' CBL Tubing 10,363' 6 15 60 2.5" CONNEX HC 08/31/14 11,444' CPlg OD 1 3 % ", EUE 8RD 1 9.3 1 480 1 2.992" 1 0' 1 8,945 1 4.500" JEWELRY DETAIL No. Depth ID OD Item 1 11' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x 3-1/2" 8RD Box 2 12' 2.992" 3.500" Pups, 3-1/2" 8RD 3 2,737' 2.992" 5.250" 3-1/2" SFO -1 Mandrel 8RD GLV #5 4 4,808' 2.992" 5.250" 3-1/2" SFDA Mandrel 8RD GLV #4 5 6,596' 2.992" 5.250" 3-1/2" SFO -1 Mandrel 8RD GLV#3 6 7,906' 2.992" 5.250" 3-1/2" SFO -1 Mandrel 8RD GLV #2 7 8,847' 2.992" 5.250" 3-1/2" SFO -1 Mandrel 8RD GLV #1 Orifice 8 8,895' 995.250" 10,355' Chemical Injection Mandrel 9 8,913' 3.00D" 5.875" Olgoonik DLH Hydraulic Packer 30 8,934' 1 2.813" 1 4.500' 1 X -Nipple 11 8,945' 1 2.992" 1 4.500" 1 WL Entry Guide aL 10C 9,273' Short RA Marker Joints Capillary Sting Details: 06/09/18 @ 10'979' -10'974 99' MD MD @ 11,164 11,1 3/8" Cap String set @ 8,900' - @ 11,379'-11,399' MD @ 11,519'-11,529' MD RA Mrk Jt rH-1 PERFORATION DETAIL J 9` Date Zone Top(MD) BLm(MD) I Top(TVD) Btm(TVD) I SPF Ft Phase Comments 02/06/18 11,139' 11,154' 10,399' 10,346' 6 15 60 2.5" CONNEX HC 01/31/18 11,139' 11,159' 10,399' 10,348' 6 20 60 2.5" HC Razor 01/26/18 H-1 11,155' 11,175' 10,346' 10,355' 6 20 60 2.5" HC Razor 01/30/18 11,175' 11,200' 10,355' 10,365' 6 25 60 2.5" HC Razor 02/06/18 11,180 11,195' 10,357' 10,363' 6 15 60 2.5" CONNEX HC 08/31/14 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5" PowerJet Nova 08/31/14 H 5 11,490 11,508' 10,496' 10,505' 6 18 60 2.5" PowerJet Nova aL 10C 9,273' Short RA Marker Joints Capillary Sting Details: 06/09/18 @ 10'979' -10'974 99' MD MD @ 11,164 11,1 3/8" Cap String set @ 8,900' - @ 11,379'-11,399' MD @ 11,519'-11,529' MD RA Mrk Jt rH-1 r�r J 9` RA Mrk Jt ` Ah 11-5 i RA Mrk.lt �! 11-71. 41/2" 11,773' TD = 11,775' PBTD = 11,649' MAX HOLE ANGLE = 66.30 @ 10,451' Updated by DMA 02-22-19 Vof 774, • co&\\\ /,,,:&, THE STA. Alaska Oil and i,as of \ L \.S K d Conservation Commission �l Z # 2 .= 333 West Seventh Avenue/. *ti GOVERNOR BILL WALKER Anchorage, Alaska 99501-5572 OF ALAS�� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations ManagerSCOJUN 1i 201$ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Swanson River Field,Hemlock Oil Pool, SCU 31-04 Permit to Drill Number: 214-090 Sundry Number: 318-221 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 t� J DATED this ` day of June,2018. RB OMS JUN 0 4 2016 • • RECEIVED STATE OF ALASKA MAY 30 20 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS G 7. // 20 AAC 25.280 f`` '1 4:1, ." 'LP , 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutddwn 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other: Install Cap String Q • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development Q. 214-090 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10106-02 • 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)31-04 + Will planned perforations require a spacing exception? Yes 0 No ❑✓ 9. Property Designation(Lease Number): 10. Field/Pool(s): I FEDA028997 Swanson River/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY I Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,775 • 10,636' • 11,649' 10,573' -1,980 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11-3/4" 1,413' 1,413 3,070 psi 1,51017i Intermediate Production 9,143' 7-5/8" 9,143' 9,142' 6,890 psi 4,790 psi Liner 2,826' 4-1/2" 11,773' 10,635' 8,430 psi 7,500 pi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 8,945' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Hydraulic Pkr;N/A 8,913'MD/8,912'TVD; N/A 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service Q 14. Estimated Date for 15.Well Status after proposed work: June 15,2018 ❑ • ❑ WDSPL 0 Suspended CI Operations: OIL WINJ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG El 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: triasse(p�hiICorp.com Contact Phone: 777-8354 Authorized Signature: � Date: 57'30/)'' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I _ 211 ZI El Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 4 II bOCE1-1APPROVED BY J� It Approved by: COMMISSIONER THE COMMISSION Date: ( YQ{�f S -3(`iY RBDM \SJUN 0 4 2018 Submit Form and Attach Form 10-403 Revised 4/2017/ Approved appl a a�a�Io 1 n s rom the date of approval. Attachmentsin Duplicate 17 f 1 V "c -4 .57.rci•I,� • • Well Prognosis Well: SCU 31-04 Hilcory Alaska,LI) Date:5/30/2018 Well Name: SCU 31-04 API Number: 50-133-10106-02 Current Status: Gas Lifted Oil Well Leg: N/A Estimated Start Date: June 15, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-090 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Current Bottom Hole Pressure: —2,200 psi @ 10,365' TVD (Based on offset well SCU 322C-04 on' 5-24-16 Maximum Expected BHP: —2,200 psi @ 10,365' TVD (Based on offset well SCU 322C-04 on 5-24-16 Max. Potential Surface Pressure: — 1,980 psi (Based on 0.1psi/ft gas gradient) Brief Well Summary SCU 31-04 was side tracked from the SCU 22-04 parent well bore in August 2014 and was completed as a Hemlock Bench 5 gas lifted producer. The purpose of this work/sundry is to install a cap string. The SCU 31-04 has an external chemical injection line that was used to inject demulsifier to break an emulsion of the fluid. This line has recently become plugged. Efforts to inject the chemical into the gas lift system were ineffective. The capillary string will be inserted into the tubing and the chemical injected to a point below where the lift gaS is injected. Capstring Procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. Install new wellhead packoff. 3. PU 3/8" capillary string. RIH and set at+/-8,900'. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic SCUll—E. 31-04 Swanson River Unit Well SCU 31-04 • Completion Ran 8/28/14 Schematic Updated 8/31/14 IllilcorpMaska,LLC RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cm Top 1 22" Conductor - Surf 28' - unknown S . 22" , 2 in 11-3/4" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx S 28' 7-%" 39 6.625" Surf 131' 7-%" 33.7 6.765" 131' 3,623' 7-%" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220 EST `r 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-%" ..±1 7-%" 39 6.625" 6,552' 6,983' 7-%" DV Collar 6,983' 6,986' 11-3/4" .: 3 I - ;,' 7-%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993 EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-%" 353 sx 9,273'CBL Tubing Cpl. OD 3'/:",EUE 8RD9.3 L-80 2.992" 0' 8,945' 4.'00" EST TOC 4,220' 4 it i JEWELRY DETAIL L ,rnirz.1No. Depth ID OD Item 1 11' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box I 2 12' 2.992" 3.500" Pups,3-1/2"8RD 3 2,737' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#5 �,,/� 4 4,808' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4 6 I' ill (04/0 5 6,596' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3 (..,?y 6 7,906' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer 7 111 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8 1 iit I iv I PERFORATION DETAIL 9 - - Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 02/06/18 11,139' 11,154' 10,399' 10,346' 6 15 60 2.5"CONNEX HC 10 ' X I 01/31/18 11,139' 11,159' 10,399' 10,348' 6 20 60 2.5"HC Razor 01/26/18 H-1 11,155' 11,175' 10,346' 10,355' 6 20 60 2.5"HC Razor 11 rig 01/30/18 11,175' 11,200' 10,355' 10,365' 6 25 60 2.5"HC Razor TOL 02/06/18 11,180' 11,195' 10,357' 10,363' 6 15 60 2.5"CONNEX HC 8,947' — = 08/31/14 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova :i 08/31/14 H 5 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova EST TOC 8,993' 1`,, `tI, 7-5/8" -!. 9,143' ' CBL TOC 9,273' i RA M rk Jt ♦A Short RA Marker Joints H-1 @ 10,979'-10,999'MD RAMrkJt '1 @ 11,164'-11,174'MD @ 11,379'-11,399'MD @ 11,519'-11,529'MD RAMrkJt`,I GLV Port Temp 0 , # '7 - 4- TCF PSC PSO PIRO Description RAMrkJt 5' H-5 20 93 0.931 1173 1400 1555 IPOR-1/1POC-1/PPOR-1 20 110 0.899 1143 1335 1545 IPOR-1/IPOC-1/PPOR-1 20 133 0.859 1113 1235 1505 IPOR-1/1P0C-1/PPOR-1 4-1/2" 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1/PPOR-1 11,773' i7' ,.:,_ 20 165 0.810 ORIFICE-1 TD=11,775' PBTD=11,649' MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Schematic 02-06-18 Updated by DMA 03-02-18 Swanson River Unit • SCU 31-04 Well SCU 31-04 Completion Ran 8/28/14 Proposed Schematic Updated 8/31/14 icorp Alaska.LLC RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 1« 22" Conductor - - Surf 28' - unknown Surf. 22" d 2 1I 4%1 11-%" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' R7-'/" 39 6.625" Surf 131' h 7-%" 33.7 6.765" 131' 3,623' 7-%" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST rr 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-'/" 9 7-'/s" 39 6.625" 6,552' 6,983' y 7-%" DV Collar 6,983' 6,986' 11-3/4" ..7," 3 il 7-%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-'/s" 353 sx 9,273'CBL Tubing Cp1g OD 3'7",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 8,945' 4.5,00" EST TOC 4,220' 4 11 a � JEWELRY DETAIL ,Y No. Depth ID OD Item 1 11' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box i, I ( ' 2 12' 2.992" 3.500" Pups,3-1/2"8RD 3 2,737' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#5 _ 4 4,808' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4 (, 1 5 6,596' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3 6 7,906' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer I 7 11 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8 1 iis,1 I PERFORATION DETAIL 9 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 02/06/18 11,139' 11,154' 10,399' 10,346' 6 15 60 2.5"CONNEX HC 10 X'' 01/31/18 11,139' 11,159' 10,399' 10,348' 6 20 60 2.5"HC Razor 11 01/26/18 H-1 11,155' 11,175' 10,346' 10,355' 6 20 60 2.5"HC Razor 01/30/18 11,175' 11,200' 10,355' 10,365' 6 25 60 2.5"HC Razor TOL L 02/06/18 11,180' 11,195' 10,357' 10,363' 6 15 60 2.5"CONNEX HC 8,947' Proposed H-5 ±11,277' ±11,382' ±10,230' ±10,275' ±105 TBD 08/31/14 H-5 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova 08/31/14 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova EST TOC Proposed H-7L ±11,607' ±11,640' ±10,382' ±10,399' ±33 TBD 8,993' 4 r , , 7-5/8" .. s **PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-091(appear as"purple"on the schematic PERFORATION 9,143' DETAIL)vet to be shot.05-30-18 o ° G_2\ RA Mrk it ; AA CBL TOC + 9,273' Short RA Marker Joints PROPOSED: @ 10,979'-10,999'MD @ 11,164'-11,174'MD Capillary Sting Details: RAMrkJt'` H-1 3 8"Cap ±8,900' iX @ 11,379'-11,399'MD String set @ J @ 11,519'-11,529'MD 2 . RA Mrk Jt ', AA f 11-5 GLV Port Temp tfei 1 # Size Depth TCF PSC PSO PTRO Description iii RA Mrk Jt 20 93 0.931 1173 1400 1555 IPOR-1/IPOC-1/PPOR-1 H-7L 20 110 0.899 1143 1335 1545 IPOR-1/IPOC-1/PPOR-1 20 133 0.859 1113 1235 1505 IPOR-1/IPOC-1/PPOR-1 4-1/2" ' , - » 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1/PPOR-1 11'773' ,5' -' 20 165 0.810 ORIFICE-1 TD=11,7775' PBTD=11,649' MAX HOLE ANGLE=66.30 @ 10,451' SCU 31-04 Proposed Schematic 05-30-18 Updated by DMA 05-30-18 STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS MAR 0 5 2018 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U A r i rGOi Gn U Performed: Suspend CI Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑.i Exploratory ❑ 214-090 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service 0 6.API Number: AK 99503 50-13-10106-02 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)31-04 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 11,775 feet Plugs measured N/A feet true vertical 10,636 feet Junk measured N/A feet Effective Depth measured 11,649 feet Packer measured 8,913 feet true vertical 10,573 feet true vertical 8,912 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11-3/4" 1,413' 1,413' 3,070psi 1,510psi Intermediate Production 9,143' 7-5/8" 9,143' 9,142' 6,890psi 4,790psi Liner 2,826' 4-1/2" 11,773' 10,635' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic C NED Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 8,945'MD 8,944'TVD N/A; Packers and SSSV(type,measured and true vertical depth) DLH Hydraul Pkr 8,913'MD 8,912'TVD 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: 178 2 451 875 165 Subsequent to operation: 194 3 463 860 140 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 ❑✓ 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: 318-017 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramercr hilcorp.com Authorized Signature: /...// � Date: 5)5-Ar Contact Phone: 777-8420 00 —ct —�Form 10-404 Revised 4/2017 )/te /` �RBDEIS 1,1i �A0 - 7 2015 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 31-04 E-Line 50-133-10106-02 214-090 1/25/18 2/6/18 Daily Operations: 01/25/2017-Thursday Meet at office. PTW and JSA. Mobe location. MU 2-1/2" x 20' HC Razor. 6 spf. 60 deg phase. PT to 250 psi low and 3,000 psi high. RIH with gun and set down at 10,110'. Worked tools to down to 10,185'. Couldn't go deeper. POOH. Nothing on tools and was not sticky at all either.TP- 650 psi. Nothing on tools that would cause them to not go down beside angle. RIH with gun and set down at 10,110' with 2-1/2 x 10' 6spf. Worked tools to down to 10,185'. Couldn't go deeper. POOH. Nothing on tools and was not sticky at all either. TP - 650 psi. Nothing on tools that would cause them to not go down beside angle. Could not run below 10,185'. Couldn't run tools any deeper. POOH. Tools clean. Rig down lubricator and secure the well. 01/26/2017- Friday Meet at office. PTW and JSA. Mobe location. PT to 250 psi low and 3,000 psi high. Shut well in. RIH w/2" GR and tools stopped at 10,827'. Worked tools to 10,941'. Found out roller bogies are close so POOH.Tools never were sticky and pretty clean. TP 600 psi Roller Bogie's arrive on location. RIH with 1-11/16" roller bogie, 1-11/16" x 5' wt., 1-11/16" CCL/GR, 2.70" Roller Bogie, 2.50" x 10' HC Razor, 6 spf, 60 degree perf gun, 2.70" Roller Bogie, tie into OHL and tag at 11,495'. Run correlation log and send to town. Get ok to perf from 11,165' to 11,175'. Spotted and fired gun with 653.3 psi on tubing. After 5 min - 653.8 psi, 10 min - 653.9 psi and 15 min - 654.8 psi. After we put the roller bogies on we didn't have any trouble getting down hole. POOH and there was small amount of paraffin on roller bogies. RIH with 1-11/16" roller bogie, 1-11/16" x 5' wt., 1-11/16" CCL/GR, 2.70" Roller Bo2.50" x 10' HC Razor, 6 spf, 60 Bogie, p , degree perf gun, 2.70" Roller Bogie, tie into OHL and tag at 11,495'. Run correlation log and send to town. Get ok to perf from 11,155' to 11,165'. Spotted and fired gun with 656.2 psi on tubing. After 5 min - 656.8 psi, 10 min - 656.7 psi and 15 min - 657.8 psi. Rig down lubricator and turn well over to production. 01/30/2018-Tuesday Meet at office. PTW and JSA. Mobe location. PT to 250 psi low and 3,000 psi high. 01/31/2017 -Wednesday Meet at office. PTW and JSA. Mobe location. PT to 250 psi low and 3,000 psi high. RIH with 1-11/16" roller bogie, 1- 11/16" x 5' wt., 1-11/16" CCL/GR, 2.70" roller bogie, 2.5" x 15' HC Razor, 6 spf, 60 degree perf gun, 2.70" roller bogie and tie into OHL. Run correlation log. Get ok from town to perf from 11,185'to 11,200'. Spotted and fired gun with 717.3 psi on tubing. After 5 min TP-717.7 psi, 10 min -717.9 psi and 15 min - 717.9 psi. POOH. All shots fired. RIH w/same wt, roller bogies, 2.5" x 10' Razor HC, 6 spf, 60 deg phase perf gun and tie into OHL. Ran correlation log and send to town. Get ok to perf from 11,175'to 11,185'. Spot and fire gun with 716.4 psi on tubing. After 5 min TP - 716.2 psi, 10 min - 716.3 psi and 15 min -717.9 psi. POOH. All shots fired. RIH w/same wt, roller bogies, 2.5" x 10' Razor HC, 6 spf, 60 deg phase perf gun and tie into OHL. Ran correlation log and send to town. Get ok to perf from 11,149'to 11,159'. Spot and fire gun with 714.7 psi on tubing. After 5 min TP - 714.9 psi, 10 min -715.0 psi and 15 min -716.7 psi. POOH. All shots fired. RIH w/same wt, roller bogies, 2.5" x 10' Razor HC, 6 spf, 60 deg phase perf gun and tie into OHL. Ran correlation log and send to town. Get ok to perf from 11,139' to 11,149'. Spot and fire gun with 713.2 psi on tubing. After 5 min TP -713.8 psi, 10 min - 714.2 psi and 15 min-715.0 psi. POOH. All shots fired. Rig down lubricator, secure well and turn well over to production. • , Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 31-04 E-Line 50-133-10106-02 214-090 1/25/18 2/6/18 Daily Operations: 02/06/2018 -Tuesday We have heavy snowfall this morning making it longer to get rigged up. Sign in and mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT lubricator to 250 psi low and 3,000 psi high. Shut well in. RIH w/2.5" x 15' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into OHL. Run correlation log and send to town. Get ok to perf from 11,180'to 11,195'. Spotted and attempted to fire gun with 649 psi on tubing. Didn't show indication of firing. POOH and found shock sub and roller bogie had leaked out. Fixed problem. Gun did not fire. RIH w/2.5" x 15' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into OHL. Had some trouble from 10,400'to 10,600'. Run correlation log and send to town. Get ok to perf from 11,180' to 11,195'. Spot and fire gun with 644.5 psi. After 5 min - 644.0 psi, 10 min - 645.2 psi and 15 min -645.3 psi. POOH. All shots fired. Had some paraffin on roller bogies but not a lot. RIH w/2.5" x 15' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into OHL. Had some trouble from 10,400' to 10,700'. Run correlation log. Spot and fire gun from 11,139' to 11,154' with 635.6 psi on tubing. After 5 min -635.5 psi, 10 min - 636.2 psi and 15 min - 636.7 psi. POOH. All shots fired. Had some paraffin on roller bogies but not a lot. Rig down lubricator and turn well over to field. TP - 634 psi. Send gun correlation to town for gun 2. Swanson River Unit SCU 31-04 Well SCU 31-04 _a_iii Schematic Completion Ran 8/28/14 IHilcorpAlaka,LLC Updated 8/31/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top t 1 r 22" Conductor - - Surf 28' - unknown Surf. 22" �z 2 '• 11-3/4" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' '.'4 7-%" 39 6.625" Surf 131' 7-'/" 33.7 6.765" 131' 3,623' II 7-%" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST Y 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-%" 7-'/" 39 6.625" 6,552' 6,983' 7-%" DV Collar 6,983' 6,986' "'` 7-%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 11-3/4" . 3 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-1/4" 353 sx 9,273'CBL Tubing Cplg OD 3%",EUE 8RD j 93 I L-80 I 2.992" I 0' I 8,945' a., ; 4.500" EST TOC. 4,220' 4 110 i JEWELRY DETAIL 5 1 PT` . 0.= No. Depth ID OD Item + 1 11' 2.992" Tubing Hanger,3-1/2"8RD Box x 3 1/2"8RD Box 2 12' 2.992" 3.500" Pups,3 1/2"8RD > 3 2,737' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#5 4 4,808' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4 6 all i 5 6,596' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3 6 7,906' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer _ 7 T 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8 1 1 1 PERFORATION DETAIL 9 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 02/06/18 11,139' 11,154' 10,399' 10,346' 6 15 60 2.5"CONNEX HC 10 ;X 01/31/18 11,139' 11,159' 10,399' 10,348' 6 20 60 2.5"HC Razor 01/26/18 H-1 11,155' 11,175' 10,346' 10,355' 6 20 60 2.5"HC Razor 11 01/30/18 11,175' 11,200' 10,355' 10,365' 6 25 60 2.5"HC Razor TOL 02/06/18 11,180' 11,195' 10,357' 10,363' 6 15 60 2.5"CONNEX HC 8,947' '41.:!:: 08/31/14 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova 08/31/14 H-5 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova EST TOC "*; 8,993' 'a 7-5/8" A P' ' 9,143' • CBL TOC j ItA;. 9,273' RA Mrk Jt j Short RA Marker Joints I.� —4".�i.- H-1 @ 10,979'-10,999'MD RA Mrk Jt 1 r,' @ 11,164'-11,174'MD rd. @ 11,379'-11,399'MD l:i , 5111, ,0'-11,529'MD RA Mrk Jt tr GLV Port Temp Via. fib' # Sze Death TCF PSC PSC PTRO Description t,. i H-5 5 20 93 0.931 1173 1400 1555 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt . 4 20 110 0.899 1143 1335 1545 IPOR-1/1P0C-1/PPOR-1 3 20 133 0.859 1113 1235 1505 IPOR-1/IPOC-1/PPOR-1 4-1/2" 2 20 155 0.825 1083 1158 146011IPOR-1/IPOC-1/PPOR-1 11,773' A `..{, ,...:s : .' TD=11,775' PBTD=11,649' 1 20 165 0.810 ORIFICE-1 MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Schematic 02-06-18 Updated by DMA 03-02-18 OF rit • • s THE STATE Alaska Oil and Gas Asw OCA T A K Conservation COnlIMlsSlOn 333 West Seventh Avenue OF ah,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS'- Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager " ` Hilcorp Alaska, LLC s 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-04 Permit to Drill Number: 214-090 Sundry Number: 318-091 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, 47DIY Hollis S. French Chair DATED this day of March, 2018. Rems t✓r , 2018 • SEE1�IE STATE OF ALASKA MAR 0 5 018 ALASKA OIL AND GAS CONSERVATION COMMISSION 37 r? le APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 2• Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development Q. 214-090 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-133-10106-02 • 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)31-04 • ❑ Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): 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): 11,775' . 10,636' • 11,649' 10,573' 1,400 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11-3/4" 1,413' 1,413 3,070 psi 1,510 psi Intermediate Production 9,143' 7-5/8" 9,143' 9,142' 6,890 psi 4,790 psi Liner 2,826' 4-1/2" 11,773' 10,635' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 8,945' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Hydraulic Pkr;N/A 8,913'MD/8,912'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development❑✓ R Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: March 19,2018 OIL ❑ WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG El 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: Chadel H geson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnassea,,hilcorp.com /�/� / Contact Phone: 777-8354 Authorized Signature: � ��" '�/oj Date: 3Is I�T COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 -0( tl Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 L ``+ '; Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 0 „ Li 3 y RP r• t I •,,+ a 2018 APPROVED BY / d Approved by: COMMI I NExtISSION1 Date: P,) RI G ,//moi (Q�� Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • • Well Prognosis Well: SCU 31-04 Hilcura Alaska,Lb Date:3/5/2018 Well Name: SCU 31-04 API Number: 50-133-10106-02 Current Status: Gas lifted Oil Well Leg: N/A Estimated Start Date: March 19, 2018 Rig: E-line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-090 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: —2,200 psi @ 10,365' TVD (Based on offset well SCU 322C-04 on 5-24-16) Maximum Expected BHP: —2,200 psi @ 10,365' TVD (Based on offset well SCU 322C-04 on 5-24-16) Max. Anticipated Surface Pressure: — 1,400 psi (Based on gas lift pressure) Brief Well Summary SCU 31-04 was side tracked from the SCU 22-04 parent well bore in August 2014 and was completed as a Hemlock Bench 5 gas lifted producer. It was also perforated in the H-1 interval in January and February 2018, looking for a response from the gas flood in the H1 to H3.There was no change in production from the H1 perf add. The purpose of this work/sundry is to add perforations via through tubing perforating to access the Hemlock H5 bench that is being gas flooded. E- Line Procedure 1. MIRU e-line andpressure control equipment. PT lubricator to 3 000 psi Hi 250 Low. 2. Perforate and test the following intervals, using 2-1/2" perf guns, 6 SPF, 60 degree phasing or 2- 3/8" perf guns, 5 SPF, 60 degree phasing: Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt H-5 11,277 11,382 10,230 10,275 105 - H-7L 11,607 11,640 10,382 10,399 33 a. Proposed perfs also 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 Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges(or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. No Spacing allowance required, per CO 123B, no spacing limits in Hemlock/Tyonek G. • 3. POOH. RD E-line. 4. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • 0 llSCU 31_04Swanson RiverUnit Well SCU 31-04 Schematic Completion Ran 8/28/14 Ha wrp Alaska,LLC Updated 8/31/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:113'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top .s 1 22" Conductor - - - Surf 28' - unknown Surf 22" '1y 'T 2il 11'/I' Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' 7-'/" 39 6.625" Surf 131' 7-'/°' 33.7 6.765" 131' 3,623' ' - 7-'/s" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST s 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-%" 7-%" 39 6.625" 6,552' 6,983' 7-%" DV Collar 6,983' 6,986' 11-3/4" 3 1 7-%s" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-1/4" 353 sx 9,273'CBL Tubing Cplg OD 3%n",EUE 8RD 19.3 I L-80 I 2.992" I 0' 1 8,945' 4.500" EST TOC 4,220' _ 4 I_______711 e JEWELRY DETAIL No. Depth ID OD Item % , ;, 1 11' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 2 12' 2.992" 3.500" Pups,3-1/2"8RD 3 2,737' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#5 4 4,808' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4 6 I 5 6,596' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3 6 7,906' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer 7 ' ill 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8 I n ' i PERFORATION DETAIL 9 - Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments • 02/06/18 11,139' 11,154' 10,399' 10,346' 6 15 60 2.5"CONNEX HC 10 E 01/31/18 11,139' 11,159' 10,399' 10,348' 6 20 60 2.5"HC Razor IR 01/26/18 H-1 11,155' 11,175' 10,346' 10,355' 6 20 60 2.5"HC Razor 11 01/30/18 11,175' 11,200' 10,355' 10,365' 6 25 60 2.5"HC Razor TOL 02/06/18 11,180' 11,195' 10,357' 10,363' 6 15 60 2.5"CONNEX HC 8'947 , rl 08/31/14 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"Power-Jet Nova H-5 5 08/31/14 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova , EST TOC 8,993' 1 7-5/8" ' , 9,143' 4 , CBL TOC 9,273' Y RAMrkJt' Et: .,4, Short RA Marker Joints 4"4, = H-1 @ 10,979'-10,999'MD RAMrkJt '° @ 11,164'-11,174'MD @ 11,379'-11,399'MD @ 11,519'-11,529'MD RA Mrk Jt • GL's` Port Temp fa # Size Depth TCF PSC P50 PTRO Description H-5 20 93 0-931 1173 1400 1555 IPOR-1IIPOC-1/PPOR-1 RA Mrk Jt :. 20 110 0.899 1143 1335 1545 IPOR-1/IPOC-1/PPOR-1 20 133 0.859 1113 1235 1505 IPOR-1/IPOC-1/PPOR-1 4-1/2" 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1/PPOR-1 11,773' TD=11,775' PBTD=11,649' 20 165 0.810 ORIFICE-1 MAX HOLE ANGLE=663°@ 10,451' SCU 31-04 Schematic 02-06-18 Updated by DMA 03-02-18 • j SCU31_04 Swanson River Unit lJ Well SCU 31 04 r:4;4-4:14 Pro osed Schematic Completion Ran 8/28/14 IHikorpAlaka,LLC Updated 8/31/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top s:. �, 1 22" Conductor - - - Surf 28' - unknown Surf. ;rre 22" 2 11-%" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf 28' '�4� 7-%" 39 6.625" Surf 131' _ p 7-%" 33.7 6.765" 131' 3,623' 7-'/e" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST or , 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-'/a" `1m 7-3'," 39 6.625" 6,552' 6,983' 4 7-%" DV Collar 6,983' 6,986' 11-3/4" 3 19) �`�+ 7'/" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-/," 353 sx 9,273'CBL Tubing Cplg OD 3/",EUE 8RD I 93 I L-80 2.992" I 0' 8,945 _ ' `< EST TOC. 4.500" 4,220' 'L; 4 e 44.4 I 14 J r ' Is! JEWELRY DETAIL ,,,14 5 No. Depth ID OD Item 1 11' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box C ,; 2 12' 2.992" 3.500" Pups,3-1/2"8RD o 3 2,737' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#5 4 4,808' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4 6 ie 1 5 6,596' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3 I 6 7,906' 2.992" 5.250" 3-1/2"SFO1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer 7 MIS i 10 8,934' 2.813" 4.500" X-Nipple 11 11 8,945' 2.992" 4.500" WL Entry Guide 8 al I I PERFORATION DETAIL 9 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments an 02/06/18 11,139' 11,154' 10,399' 10,346' 6 15 60 2.5"CONNEX HC 10 i 01/31/18 _ 11,139' 11,159' 10,399' 10,348' 6 20 60 2.5"HC Razor IM 01/26/18 H-1 11,155' 11,175' 10,346' 10,355' 6 20 60 2.5"HC Razor 11 01/30/18 11,175' 11,200' 10,355' 10,365' 6 25 60 2.5"HC Razor TOL02/06/18 11,180' 11,195' 10,357' 10,363' 6 15 60 2.5"CONNEX HC 8,947' = Proposed H-5 ±11,277' ±11,382' ±10,230' ±10,275' ±105 TBD '° 08/31/14 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova 08/31/14 H 5 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova EST TOC .74 Proposed H-7L ±11,607' ±11,640' ±10,382' ±10,399' ±33 TBD • 8,993' +• ►* - ' ', +i d 7-5/8" `%f 'r.4 9,143' 7;g ',1",, CBL TOC ;;: 9,273' RA Mrk Jt . P J ` Short RA Marker Joints I 1 @ 10,979'-10,999'MD RAMrkJt rH-1 @ 11,164'-11,174'MD ,'a J @ 11,379'-11,399'MD )(' t @ 11,519'-11,529'MD t I' RA Mrk Jt . ' H-5 G1_V Port Temp `a, ' 'I # Size Depth TCF PSC PSO PTRO Description is RA Mrk Jt .S. 20 93 0.931 1173 1400 1555 IPOR-1/IPOC-1/PPOR-1 fe 20 110 0.899 1143 1335 1545 IPOR 111POC 1/PPOR-1 ru 1-1-7L 20 133 0.859 1113 1235 1505 IPOR-1/1130C-1/PPOR-1 4-1/2" 1" 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1/PPOR-1 11,773' sy -<, TD=11,775' PBTD=11,649' 20 165 0-810 ORIFICE-1 MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Proposed Schematic 03-02-18.doc Updated by DMA 03-02-18 ti of Tit • • �w 1//jy sA THE STATE Alaska Oil and Gas 4v 7.4, of® TLTA Conservation Commission 4 ____ ` AAS < Litt = 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 Operations Manager ;�; Hilcorp Alaska, LLC SCANNED 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Soldotna Creek Field, Hemlock Oil Pool, SCU 31-04 Permit to Drill Number: 214-090 Sundry Number: 318-017 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, 9 r Daniel T. Seamount, Jr. Commissioner DATED thisZ/dday of January, 2018. 7r? RE' -�11A� u a�: r- L J...: .- � L�18 • IIRECEIVED STATE OF ALASKA JAN 1 6 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION 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 ❑ Perforate ❑✓ • Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • 214-090 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10106-02 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)31-04 • Will planned perforations require a spacing exception? Yes 1:1 No 9. Property Designation(Lease Number): 10. Field/Pool(s): FEDA028997 • Swanson River I Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY I Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,775 • 10,636' • 11,649' 10,573' -1,980 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11-3/4" 1,413' 1,413 3,070 psi 1,510 psi Intermediate Production 9,143' 7-5/8" 9,143' 9,142' 6,890 psi 4,790 psi Liner 2,826' 4-1/2" 11,773' 10,635' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 8,945' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): DLH Hydraul Pkr;N/A 8,913'MD/8,912'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: January 20,2018 OIL Q • WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 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@hilcoro.com /� Contact Phone: 777-8420 Authorized Signature: 4 -. 1 ,-• Date: //gee COMMISSIO USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 6 ' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? Yes 0 No Er Subsequent Form Required: L REBDcw 3 o ;:, : 2u18 / APPROVED BY Approved by: r/ COMMISSIONER THE COMMISSION Date: J (Z 4,' ` V'— ( f pt4is OrRisO NA G Submit Form and Form 10-403 Revised 4/2017 Approve a lication is valid fom ddaa o royal. Attachments in Duplicate 41/ Z3fVi-µ-/p` .. 1g- (./7./t • • Well Prognosis Well: SCU 31-04 Hilcora Alaska,LLI Date: 1/5/2018 Well Name: SCU 31-04 API Number: 50-133-10106-02 Current Status: Gas lifted Oil Well Leg: N/A Estimated Start Date: January 20, 2018 Rig: E-line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-090 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: 1820155 Current Bottom Hole Pressure: —2,200 psi © 10,365' TVD (Based on offset well SCU 322C-04 on 5-24-16 Maximum Expected BHP: —2,200 psi © 10,365' TVD (Based on offset well SCU 322C-04 on 5-24-16 Max. Potential Surface Pressure: — 1,980 psi (Based on 0.lpsi/ft gas gradient) Brief Well Summary SCU 31-04 was side tracked from the SCU 22-04 parent well bore in August 2014 and was completed as a Hemlock Bench 5 gas lifted producer. The purpose of this work/sundry is to add the H-1 bench in this well which should be supported by the gas flood gas currently being injected into offset injector SCU 322C-04. E- Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 3,000 psi Hi 250 Low. 2. Perforate and test the Hemlock Bench 1, using 2-1/2" perf guns, 6 SPF, 60 degree phasing: Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt H-1 11,139 11,200 10,339 10,365 61 a. Proposed perfs also 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 Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. No Spacing allowance required, per CO 123B, no spacing limits in Hemlock/Tyonek G. 3. POOH. RD E-line. 4. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Schematic • Swanson River Unit SCU 31-04 Well SCU 31-04 Actual Schematic Completion Ran 8!28/14 IHikurpAlaska,LLC Updated 8/31!14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 22" Conductor Surf 28' - unknown Surf. 22" ' j 2 11-%" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' rai % 7-/s" 39 6.625" Surf 131' t.111 7-%" 33.7 6.765" 131' 3,623' ligl :et 7-%" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST + 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-3/4" 7-%" 39 6.625" 6,552' 6,983' lii 7-%" DV Collar 6,983' 6,986' 11-3/4" 3 (, C 7%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-1/4" 353 sx 9,273'CBL Tubing Cplg OD 3'/:",EUE 8RD I 9.3 I 1-80 I 2.992" I 0' I 8,945 ? 4.500" EST TOC. 4,220' 4 I 3+* 04' a 10:414- fe'�° 1 JEWELRY DETAIL t1 5 IN i' a No. Depth ID OD Item 1 11' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 4 2 12' 2.992" 3.500" Pups,3-1/2"8RD > 3 2,737' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#5 4 4,808' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4 6 5 6,596' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3 I 6 7,906' 2.992" 5.250" 3-1/2"SF01 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer 7 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8 1 A I - I Short RA Marker Joints 9 - - @ 10,979'-10,999'MD @ 11,164'-11,174'MD 1.1 @ 11,379'-11,399'MD 10 El@ 11,519'-11,529'MD On 11 TOL PERFORATION DETAIL 8,947' _ Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 8/31/14 H-5 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova ;, 8/31/14 H-5 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova ' EST TOC "') °, 8,993' i� a., t '1'' ^ °'# "r: '.1 7-5/8" „o4 r'.,.*: 9,143' is 'a. 9,143' 1"' CDI.T 0 C GLV Port Temp ia> 9,273' # Size Depth TCF FSC PSO PTRO Descriptic.n RA Mrk Jt ; 41. 5 20 93 0.931 1173 1400 1555 IPOR-1/IPOC-1/PPOR-1 I ' ``1 4 20 110 0.899 1143 1335 1545 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt 4 3 20 133 0.859 1113 1235 1505 IPOR-1/IPOC-1/PPOR-1 "4 2 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1/PPOR-1 X.4 1 20 165 0.810 ORIFICE-1 IA RAMrkJt >L 1 ,, H-5 RA Mrk Jt - ' ' 4-1/2" 11,773' - 4 TD=11,775' PBTD=11,649' MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Actual Schematic 8-31-14 Updated by STP 9/24/14 ft ii . SCU 31_04 Swanson River Unit `"Well SCU 31-04 Proposed Schematic Well Ran 8/28/14 Hileoru Alaska,LLC Updated 8/31/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1% 1 22" Conductor Surf 28' unknown Surf. 22" ' 2 11'/1' Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' ", 7-%" 39 6.625" Surf 131' 7-%" 33.7 6.765" 131' 3,623' nj 7-%" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST g •: 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-3'." 7-3'" 39 6.625" 6,552' 6,983' k1-- 7-%" DV Collar 6,983' 6,986' 11-3/4" :ate 3 i, 7-%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-'4," 353 sx 9,273'CBL Tubing Cplg OD 3'/:",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 8,945 ( ;,`, 14., ",i,,.,'2, 4.500" EST TOC.,, 4,220' *>s 41 J JEWELRY DETAIL *,. 5 tea, • No. Depth ID OD Item 1 11' 2.992" Tubing Hanger,3-1/2"8RD Box x 3 1/2"3RD Box N2 12' 2.992" 3.500" Pups,3 1/2"8RD 3 2,737' 2.992" 5.250" 3-1/2"SFO 1 Mandrel 8RD GLV#5 4 4,808' 2.992" 5.250" 3-1/2"SFo-1 Mandrel 8RD GLV#4 6 5 6,596' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3 6 7,906' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel { 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer 7 111 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8 SE Short RA Marker Joints 9 = @ 10,979'-10,999'MD @ 11,164'-11,174'MD 10 @ 11,379'-11,399'MD 11 @ 11,519'-11,529'MD 11 TOL PERFORATION DETAIL 8,947 , _ Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments Proposed H-1 ±11,139' ±11,200' ±10,339' ±10,365' 61 TBD -' 8/31/14 H-5 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova EST TOC 8/31/14 H-5 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova 8,993' 7-5/8" 9,143' CBL TOC i'+ 9,273' RA Mrk Jt 1� 11-1 GLV Port Temp @ RA Mrk Jt .r A•` # Size Depth TCF PSC PSO PTRO Desc'ip'tn 5 20 93 0-931 1173 1400 1555 IPOR-1/IPOC-1/PPOR-1 4 20 110 0-899 1143 1335 1545 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt '` 3 20 133 0.859 1113 1235 1505 IPOR-1/IPOC-1/PPOR-1 2 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1/PPOR-1 , ;rH-5 1 20 165 0.810 ORIFICE-1 RA Mrk Jt , 4-1/2" 11,773' TD=11,775' PBTD=11,649' MAX HOLE ANGLE=663°@ 10,451' SCU 31-04 Proposed Schematic 01-05-18 Updated by DMA 01-05-18 • *anson River II SCU 31-04 12/08/2014 Ilikorp Ala.ka,IJ.t: Swanson River Tubing hanger,Seaboard SC-E- SCU 31-04 CL,7 X 31/2 EUE 8rd Lift and 11%X7 5/8 X 3 1/2 susp,3"Type H BPV profile,3/8 control line prep,dovetail body seals BHTA, Bowen,3 1/8 5M FE X 3"Bowen top W. O Valve,swab,WKM-M, «r �c°� Z 1v- 3 1/8 5M FE,HWO,DD :wort z' `���� "•c< " trim * � ��, tis ,,e,5� ,,* -4'6 IT y\ Ja y�� Valve,Wing,WKM-M, 21/165MFE,HWO, ' _110 ri, t DD trim \a � 1. ! l _r. . - Valve,master,WKM-M $O , 3 1/8 5M FE,HWO,DD c,0�F trim o p 00 k AJ Valve,master,WKM-M, - 0 ,4 3 1/8 5M FE,HWO,DD . O It trim GeeAdapter,Seaboard SM-E-CLN Tbghead,Seaboard,S-8, - ii ' — 7 1/16 5M stdd X 3 1/8 5M stdd 13 5/8 3M X7 1/16"5M, tI q top,w/%npt control line exit w/2-2 1/16 5M SSO,BG bottom prep,bored out for =' 1 7 5/8 casing I. _�1 ..w.,,,,..,4,,,, Valve,WKM-M,2 1/16 5M FE, (ti /Oar ,,-' HWO,AA I Illi I II itteLti) , .. i.,4 1111 1.11-1 ---,''',7-1.-- III _11 . .. I UTI) g...-Casing head,Shaffer KD, if I 13 5/8 3M X11%SOW gyp;,. ' bottom,w/2-2"LPO mi.now(0Af _1.., p Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 112 J 4 - 0/0 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: olor Items: ❑ Maps: _ ayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: aft BY: Date: 71).! 11,5-- /s/ mf Project Proofing I BY: Maria Date: P /s/ u , = .. 15 = f t2 Scanning Preparation V x 30 � I � TOTAL PAGES l (Count does not include cover sheet) BY: 11M Date: 7/a(11/5— /s/ Production Scanning Stage 1 Page Count from Scanned File: I t2 3(Count does include co er sheet) Pa•e Count Matches Number in Scanning Preparation: YES NO se BY: 410 Date: 171 pi 9 /45— Is! 11/1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: NO TOTAL PAGES: \ Digital version appended by: Meredith Michal Date: q.131 ( I. /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES:a I If Scanning is complete at this point unless rescanning is required. 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J_ y 7 w @ c0 V " 0 Ce J J N a co W a Ce a r W 0 J Z Q s N J 7 o CO a141 _o • r N N " n V 17, U ti o o Q acz i""" r) H ~ o M • M Va °° = H a) C 0 c°0 ilk 40 _, Q co0 c0 )1, Q Z 1,.. 0 E p £ U m Z d co co 0 o) H o , V 3 N co d d' u Y C (..) co U Z. C E o o C a 2 v RECEIVED STATE OF ALASKA OCT 14 2014 • 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 Test ❑ 2.Operator Name: 5. Date Comp..Susp.,or 12. Permit to Drill Number:,--, 3HA 4/( A Hilcorp Alaska, LLC Aband.: 8/31/2014• ' - 214-090/314-450 /3,q7.5 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive STE 1400 Anchorage.AK 99503 July 19,2014• 50-133-10106-02-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 2072'FSL,2126'FWL. Sec 4.T7N.R9W, SM,AK • August 14,2014. ('1L) -s A ,>' 1; SCU 31-04 Top of Productive Horizon: 8. KB(ft above MSL): ,..1-887e 15.FieldfQoof(s): 1614'FNL,2431'FEL.Sec 4,T7N. R9W.SM,AK GL(ft above MSL): 178*---. (y Z,7 Swanson River Total Depth: 9. Plug Back Depth(MD+TVD): /P _�- Hemlock - 1344'FNL.2327'FEL.Sec 4.T7N. R9W. SM,AK 11,649'MD/10,573TVD ' -.7' " 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 344442.005- y- 2457991.129 Zone- 4 11,775'MD/10,635TVD •. FEDA028997 TPI: x- 345179.976 y- 2459581.066 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 345287.383 y- 2459849.204 Zone- 4 N/A NA within Swanson River Unit 18. Directional Survey: Yes No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD(TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top,Window MD/TVD: ROP, DGR, EWR-Phase4,ALD,CTN, RST-GR-CCL. MUDLOGS(already submitted) i 9,143'MD/9,142'TVD , 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 4-1/2" 12.6 L-80 8.946.54' 11,773' 8.946' 10,634' 6-1/8" 85bbls/353sx 15.3ppg Class G NA , 24.Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/7' 8,945' 8,913'MD/8.912'TVD Top MD/TVD Btm MD/TVD Size Number Interval 11,444'/10,475' 11,478'/10.491' 2.5" 6spf 34ft 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. 11,490'/10,496' 11,508710,505' 2.5" 6spf 18ft Was hydraulic fracturing used during completion? Yes [] No ❑✓ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 /( 14 27. �'sn.ern, ,,,• PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 8/31/2014 _Gaslift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 9/3/2014 24 Test Period �*407 282 108 64 693 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 175 925 24-Hour Rate 407 282 108 32 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No E - 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. RB€'MS OCT 14 2014 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE ; • Submit original only _. _ _ r^ 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Des Do If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top NA NA needed, and submit detailed test information per 20 AAC 25.071. Permafrost-Base NA NA Tyonek G2 Sand 10543 10746 Tyonek G1 Sand 10867 11114 Hemlock Bench 1 11114 11204 Hemlock Bench 2 11218 11234 Hemlock Bench 3 11239 11390 Hemlock Bench 5 11430 11607 Hemlock Bench 7 11652 11776 Formation at total depth: Hemlock 11,775' 10,635' 31. List of Attachments: Well Schematic, Days vs Depth, MW vs Depth, Final Directional Survey, Daily Composites,Casing and Cement Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Mack Myers Email: mmyers(C�hiIcorp.Com Printed Name: Monty Mack Myers Title: Drilling Engineer Signature: Phone: (907)777-8431 Date: 10/14/2014 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 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 SCU 31_04 Swanson River Unit Well SCU 31-04 Completion Ran 8/28/14 tlileorpAbrkn.1.LI:ill— Actual Schematic Updated 8/31/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB-THF:11.3'(WO Rig) Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top J / 1 _ 22" Conductor Surf 28' unknown Surf. 22" 2 I t-'/<" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' 7-%" 39 6.625" Surf _ 131' 7-%" 33.7 6.765" 131' 3,623' 7-'h" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST 7-'%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-%" 7'%" 39 6.625" 6,552' 6,983' 7-%" DV Collar 6,983' 6,986' 11-3/4" 31 h) 7-%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 1 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-'/" 353 sx 9,273'CBL Tubing Cplg OD 3 Y.",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 8,945' P7; :',4,;1:.0.,41, 4.500" EST TOC 4,220' 41 JEWELRY DETAIL 51 0 No. Depth ID OD Item 1 11' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 2 12' 2.992" 3.500" Pups,3-1/2"8RD 3 2,737' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#5 4 4,808' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4 6 I ti 5 6,596' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3 6 7,906' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2 7 8,847' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1 Orifice 8 8,895' 2.992" 5.250" Chemical Injection Mandrel 9 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer 71 111 10 8,934' 2.813" 4.500" X-Nipple 11 8,945' 2.992" 4.500" WL Entry Guide 8I till Short RA Marker Joints 9@ 10,979'-10,999'MD ; 11. @ 11,164%11,174'MD 10 X @ 11,379'-11,399'MD @ 11,519'-11,529'MD 11 MI TOL , t PERFORATION DETAIL 8,947' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments , 8/31/14-1 8/31/14 H-5 11,444' 11,478' 10,475' 10,491' 6 34 60 2.5"PowerJet Nova 8/31/14 H-5 11,490' 11,508' 10,496' 10,505' 6 18 60 2.5"PowerJet Nova EST TOC 8,993' 7-5/8" 9,143' a,i.. CBL TOC GLV Port Temp 9,273' # Size Depth TCF PSC PSO PTRO Description RAMrk,It 5, 20 93 0.931 1173 1400 1555 IPOR-1/IPOC-1IPPOR-1 • 4 20 110 0-899 1143 1335 1545 IPOR-1,'IPOC-1r'PPOR-1 15 RAMrkJt 3 20 133 0.859 1113 1235 1505 IPOR-1IIPOC-1iPPOR-1 1i 2 20 155 0.825 1083 1158 1460 IPOR-1/IPOC-1iPPOR-1 1 20 165 0.810 ORIFICE-1 RA Mrk It H-5 RA MrkJt ' 4 4-1/2" 11,773' ti,-`'n'_ TD=11,775' PBTD=11,649' MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Actual Schematic 8-31-14 Updated by STP 9/24/14 Q CP-2 2"ALCAP 4928-S N=2458623.288 E=343646.698 ELEV.=212.690 SCU 22-04 ASBUILT SURFACE LOCATION NAD 27 ASP ZONE 4 N:2457991.129 E:344442.005 w a/ LAT: 60°43'30.381"N U 4- LON: 150°52'07.926"W 0 2126' FWL . Oo 2072' FSL • pec: FP.. ELEV: 152.49' NAVD88 O Z LLJ 2126'FWL(NTS) �. 0 Z • J Z O U W CO 2072'FSL(NTS) • ACCESS ROAD SECTION COR(COMPUTED) <> N:2455946.618 E:342292.388 SECTION LINE (NOT TO SCALE) 8 9 NOTES 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION(EPOCH 2010) ```���1 AND VERTICAL CONTROL(NAVD88)IS AN OPUS SOLUTION FROM ��� OFA 1 I�i NGS STATIONS TBON,TSEA AND ANC2 TO ESTABLISH CP-2. THE • Q-E... x;9.. I, ee ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: t��.` .. '.77 / N=2458384.578 N Tj R'T�- ,* 49 TH i` ._* E=1483669.444 ELEV.=212.690(NAVD88) "'li 1111ll-" j� STAN . 2.SECTION LINES SHOWN WERE ESTABLISHED FROM SURVEY 4637-S SCALE �� 3/4/14...• TIES TO ORIGINAL GLO MONUMENTATION(1987) I� 3. DATUM TRANSFORMATIONS(NAD83 ASPZ4 TO NAD27 ASPZ4) 0 200 400 it - �������` WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. J I FEIET PROJECT HILCORP ALASKA, LLC REVISION: - ConsultingInc SWANSON RIVER FIELD DATE 3/4/14 WELL SCU 22-04 DRAWN BY: ICB MSE AS BUILT SURFACE LOCATION SCALE 1'=200' PROJECT NO. 143020 NAD 27 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. 13-22,14-08 P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION VOICE:(907)283-4218 FAX:(907)283-3265 SECTION 04 TO7N RO9W SHEET EMAIL:SAMCLANE@MCLANECG.COM Hilcc►rp Alaska,LLC OF 1 SEWARD MERIDIAN, ALASKA L U L U 0)oa c S.-3dY C r 0 a) N U N CO M (0 N _ > (0 N- C Q C 4_, }, 4_, N m U a) � (n C U E C c N O N C ` a) (a u D Q•C N -p j N 0)O. a O CO . tL w C p ° N r ° co 1-- Z C _ a) -a L CD (6 0 �>' y U L N C r-,› C } C E al J a) > a Y (6 a) C 3 (n E _ rim E V Y y ° o a) a) (n a) 0 O (O m 3 3 a m w U ° 0 o > v o 3 -0f— 0) �' � o � aCL p ` c 0 = c C o a L O m C -0 C t p ;Ma pcOE (C6 M . U)C°00 O 7c ° 3 ; c Q E .� N ami :co". i. 'C U Q-- a) N E C 3 (ri n. 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NI' N a) a) Q) a) a) a) a) a) 0 o d -) -) -3 -3 -) -3 -3 U) u O co ON CO d f a) - co O V U) U) Y N — LU .- di -O m *k 0• 0 rte. s O Y (0 E (0 d- V _V R V V V -4- zco �' Q O Z O O O O O O O O >, J -a �>+, N N N N N N N N 0 g E F- O o Q p 1 N co d- in O r- co a) N N N N N N N N Cn a � CO CO CO CO CO CO CO o Lu N a r 0 r 0 O 0 O 0 U o C N N N N N N N N J +'• CO 'Cr LU O N- CO 0) O N N N N N N N CO Ign 00 CO CO CO CO CO c0-5 _ 0 = - .22o ± \ 0 0 2 \ * ru C § o % = 2 = .9gf ® - _2 - \ B o m > 6 \ a. > = o m - e w - & o 22220 -0 o co . = 5 $ .2 \ C ,, - - 0 e c c-0 o al R a » \ .P -0 c 6 2 \ c • C c& 2 = c = ° \ 2 = t o• -0 .e / - ( _ ± _ _ .- co c 0 = n O 2 2 \ \ % •§ _ - _ - -0 c e a / / 2 % - E x ' 3 o I o 2 92 � \ 2 % -a \ E ° 7 \ % = k § Q o / C Ecc / — ® o k o ± _ 22 — 0 E2om ; s o m ) Cl E e r k -0 ° ft > = m E _ < c _ = o E _ o = n o 0 \ a •- $ s 5 @ Z, � a_I / 22 e o 0 co o e I t E k cp - 2 ( ƒ 0 O c) t .0 = I E 0. 0 \ / c E 4 § o ccoC \ c 0 / .- S / / / / 4 kG o mmil CD ' f & 0 m 0_« _C = ® \. \ \ / c CD Cl) / \ 0 \ / 7 / gd -o g I c % % \ i 0 \ \ © E \ mak QI r o -- i C \ \ \ / 7 in / 0 CI .g $ / \ / / Q • ƒ 7 & » 0 5 C - _ § = a rl ��\ eL\ .\/ a ? \ ° Q e ® � § a3 \ E O 8 G•- _ ¢ / / 0 E a.2 - � E o § « / q / / 0 / Ct / . / % \ 2 0 6 O E I o c_ a.) X202 3 ® C E = 0 72 f _ \ 2 a \ 0 t a_ \ / \ o § \ \ 7 / o e o q < = >c0'7 \ c _ � \ f 0_ I a) C. U . c g _.. Cl) = a 2 ' // C // / ° y -4- f 7 / \ 9 ( — 6 i ■ 2 7 2 .= t C m = \ # C u) < / 0 \ \ A \ % 1 CO @ . o $ A \ 0 — ± co c \ A- a — I ƒ ƒ $ CV co \ \ / E / \ C - \ E k .4- ca E m 2 ƒ \ c E 0 \ = � \ _ � � 9 tl ? ? & 0 J \ 7 $ / \ \ ® / o / (13 O CI ' - g_ re Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit SCU 31-04 50133101060200 Sperry Drilling Definitive Survey Report 02 September, 2014 HALLIBURTON Sperry Drilling True Vertical Depth (2000 usft/in) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 cci cd o 0 0 0 0 0 0 0 0 0 0 c iiiO O N M V o c+0 O r h mem I I I l I I l l l I l l l l I l I l l I I ilii till ' l l l l I I I l I 1 l ill l l l l l I I l l I I l l l l 1 ECLIY Sbm ZZvv - =so 2'°N 9N 200 - o tiiii m (V _O Z gyJ J d - 4 0 goo p st - 2 cc 4«u I C ‘7.,? -12 Z VrO Or W � 1 0 - M OO S W m-8 0@yDiyg ` I d - Co ,Q_ Z LSSp44 p H _oo , .moo d' fn(OM ---- / N it MGi nK >coc2 U - N GE to C.. ,y.) L N N fAC Z N N t t , M _ V a _ w n - -o 8 -�Q1� r - m IAC TT, 13 ,�" 1 - U + m y 0 IN 8 1 U Y 0V, 0 —o 00 0 O - M 0 VI CD tn M .--Ii -I � M V (V U M M _:.-1 I O I UUU iii CoD coCD p� ' o O O OMC) � / 7 -0-0-0DD Oi �/ _ 000oU /, O cn I � w= ai� = 4 � � N 14 4 .(2.,.(7)> o_ oS - - o �a -.151 P. ?tiL1 I Eo c'.1---00oo ��� O Zn IL0 co QN - _ 2€ o,Nom( ,I - ODS , 2 a 23t.. I � a�m � z ai a „ o` _ r S M N O CC WWW f 'y 1. at W 74 f. J 0 - J I I I I I I I r I I I I 1 I 1 I I I I I 1 I I l Q O O O O 0 0 N 000 kr) 7 X M N y (tlyijSrl Oct)(+)4poN/(-)4pnos Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Project: Soldotna CK Unit ND Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Site: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Well: Soldotna CK Unit 323-04 North Reference: True Wellbore: SCU 31-04 Survey Calculation Method: Minimum Curvature Design: SCU 31-04 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 323-04,5013310106 Well Position +N/-S 0.00 usft Northing: 2,457,991.13 usft Latitude: 60.7251057 +E/-W 0.00 usft Easting: 344,442.01 usft Longitude: -150.8688684 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 152.49 usft / Wellbore SCU 31-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 8/1/2014 17.01 73.71 55,499 Design SCU 31-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,427.57 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 23.71 Survey Program Date 9/2/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 99.15 9,098.95 SCU 22-04 Gyro(SCU 323-04) NS-Gyro-MS Fixed:v2:North-seeking gyro multishot 06/17/2014 9,143.00 9,365.00 MWD_Interp+Azi+Sag(SCU 31-04 PB1) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 07/22/2014 9,396.00 9,427.57 MWD+SC+Sag(SCU 31-04 PB1) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/22/2014 9,438.00 9,766.38 Interp Azi+sag(SCU 31-04) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 08/05/2014 9,828.60 11,738.74 MWD+SC+Sag(SCU 31-04) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 08/12/2014 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) On (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -152.49 0.00 0.00 2,457,991.13 344,442.01 0.00 0.00 UNDEFINED 99.15 0.15 174.46 99.15 -71.34 -0.11 0.01 2,457,991.02 344,442.02 0.18 -0.09 NS-Gyro-MS(1) 199.15 0.25 133.97 199.15 28.66 -0.39 0.18 2,457,990.74 344,442.18 0.17 -0.28 NS-Gyro-MS(1) 299.15 0.28 140.89 299.15 128.66 -0.73 0.49 2,457,990.39 344,442.49 0.04 -0.47 NS-Gyro-MS(1) 399.15 0.31 151.09 399.15 228.66 -1.15 0.78 2,457,989.96 344,442.77 0.06 -0.75 NS-Gyro-MS(1) 499.15 0.29 139.18 499.15 328.66 -1.58 1.07 2,457,989.53 344,443.06 0.07 -1.02 NS-Gyro-MS(1) 599.15 0.37 138.20 599.14 428.65 -2.02 1.45 2,457,989.09 344,443.44 0.08 -1.26 NS-Gyro-MS(1) 699.15 0.14 158.03 699.14 528.65 -2.37 1.71 2,457,988.74 344,443.69 0.24 -1.48 NS-Gyro-MS(1) 799.15 0.10 127.06 799.14 628.65 -2.54 1.83 2,457,988.57 344,443.81 0.07 -1.59 NS-Gyro-MS(1) 899.15 0.14 38.16 899.14 728.65 -2.49 1.97 2,457,988.61 344,443.95 0.17 -1.49 NS-Gyro-MS(1) 9/2/2014 9:25:37PM Page 2 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Project: Soldotna CK Unit TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Site: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Well: Soldotna CK Unit 323-04 North Reference: True Wellbore: SCU 31-04 Survey Calculation Method: Minimum Curvature Design: SCU 31-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 999.15 0.29 19.56 999.14 828.65 -2.16 2.13 2,457,988.94 344,444.12 0.16 -1.12 NS-Gyro-MS(1) 1,099.15 0.34 27.47 1,099.14 928.65 -1.66 2.36 2,457,989.44 344,444.34 0.07 -0.57 NS-Gyro-MS(1) 1,199.15 0.32 17.57 1,199.14 1,028.65 -1.13 2.58 2,457,989.97 344,444.57 0.06 0.00 NS-Gyro-MS(1) 1,299.15 0.41 19.17 1,299.14 1,128.65 -0.52 2.78 2,457,990.57 344,444.78 0.09 0.64 NS-Gyro-MS(1) 1,399.15 0.36 30.86 1,399.13 1,228.64 0.09 3.06 2,457,991.17 344,445.07 0.09 1.31 NS-Gyro-MS(1) 1,499.15 0.43 39.32 1,499.13 1,328.64 0.65 3.46 2,457,991.73 344,445.47 0.09 1.98 NS-Gyro-MS(1) 1,599.15 0.55 52.16 1,599.13 1,428.64 1.23 4.07 2,457,992.31 344,446.10 0.16 2.76 NS-Gyro-MS(1) 1,699.15 0.47 78.62 1,699.12 1,528.63 1.61 4.85 2,457,992.67 344,446.89 0.25 3.42 NS-Gyro-MS(1) 1,799.15 0.60 75.70 1,799.12 1,628.63 1.82 5.76 2,457,992.87 344,447.80 0.13 3.98 NS-Gyro-MS(1) 1,899.15 0.50 70.86 1,899.12 1,728.63 2.09 6.68 2,457,993.13 344,448.72 0.11 4.60 NS-Gyro-MS(1) 1,999.15 0.52 75.68 1,999.11 1,828.62 2.34 7.54 2,457,993.37 344,449.58 0.05 5.18 NS-Gyro-MS(1) 2,099.15 0.37 51.78 2,099.11 1,928.62 2.66 8.23 2,457,993.68 344,450.27 0.24 5.74 NS-Gyro-MS(1) 2,199.15 0.17 45.52 2,199.11 2,028.62 2.96 8.59 2,457,993.97 344,450.64 0.20 6.16 NS-Gyro-MS(1) 2,299.15 0.15 46.42 2,299.11 2,128.62 3.15 8.79 2,457,994.17 344,450.84 0.02 6.42 NS-Gyro-MS(1) 2,399.15 0.14 139.35 2,399.11 2,228.62 3.15 8.96 2,457,994.16 344,451.01 0.21 6.49 NS-Gyro-MS(1) 2,499.15 0.02 143.75 2,499.11 2,328.62 3.04 9.05 2,457,994.05 344,451.10 0.12 6.43 NS-Gyro-MS(1) 2,599.15 0.20 326.26 2,599.11 2,428.62 3.18 8.97 2,457,994.19 344,451.02 0.22 6.51 NS-Gyro-MS(1) 2,699.15 0.17 307.13 2,699.11 2,528.62 3.41 8.75 2,457,994.42 344,450.81 0.07 6.64 NS-Gyro-MS(1) 2,799.15 0.23 296.12 2,799.11 2,628.62 3.59 8.45 2,457,994.60 344,450.51 0.07 6.68 NS-Gyro-MS(1) 2,899.15 0.45 305.23 2,899.10 2,728.61 3.90 7.95 2,457,994.93 344,450.01 0.23 6.77 NS-Gyro-MS(1) 2,999.15 0.48 292.14 2,999.10 2,828.61 4.29 7.24 2,457,995.32 344,449.31 0.11 6.84 NS-Gyro-MS(1) 3,099.15 0.54 298.51 3,099,10 2,928.61 4.67 6.44 2,457,995.71 344,448.51 0.08 6.87 NS-Gyro-MS(1) 3,199.15 0.85 314.36 3,199.09 3,028.60 5.41 5.50 2,457,996.47 344,447.58 0.36 7.17 NS-Gyro-MS(1) 3,299.15 0.88 308.34 3,299.08 3,128.59 6.41 4.36 2,457,997.48 344,446.46 0.10 7.62 NS-Gyro-MS(1) 3,399.15 0.80 303.27 3,399.07 3,228.58 7.27 3.18 2,457,998.35 344,445.28 0.11 7.93 NS-Gyro-MS(1) 3,499.15 0.65 294.33 3,499.06 3,328.57 7.88 2.08 2,457,998.99 344,444.19 0.19 8.05 NS-Gyro-MS(1) 3,599.15 0.60 292.77 3,599.05 3,428.56 8.32 1.08 2,457,999.43 344,443.20 0.05 8.05 NS-Gyro-MS(1) 3,699.15 0.59 298.36 3,699.05 3,528.56 8.77 0.14 2,457,999.89 344,442.27 0.06 8.09 NS-Gyro-MS(1) 3,799.15 0.65 306.77 3,799.04 3,628.55 9.35 -0.77 2,458,000.49 344,441.37 0.11 8.26 NS-Gyro-MS(1) 3,899.15 0.79 305.72 3,899.03 3,728.54 10.09 -1.78 2,458,001.25 344,440.36 0.14 8.53 NS-Gyro-MS(1) 3,999.15 0.77 300.76 3,999.02 3,828.53 10.84 -2.92 2,458,002.01 344,439.24 0.07 8.75 NS-Gyro-MS(1) 4,099.15 0.76 297.18 4,099.02 3,928.53 11.49 -4.08 2,458,002.67 344,438.08 0.05 8.88 NS-Gyro-MS(1) 4,199.15 1.00 247.50 4,199.01 4,028.52 11.46 -5.48 2,458,002.66 344,436.68 0.77 8.29 NS-Gyro-MS(1) 4,299.15 1.23 233.21 4,298.99 4,128.50 10.48 -7.15 2,458,001.70 344,435.00 0.36 6.72 NS-Gyro-MS(1) 4,399.15 1.29 226.83 4,398.96 4,228.47 9.07 -8.83 2,458,000.31 344,433.30 0.15 4.75 NS-Gyro-MS(1) 4,499.15 1.25 224.15 4,498.94 4,328.45 7.51 -10.41 2,457,998.78 344,431.70 0.07 2.70 NS-Gyro-MS(1) 4,599.15 1.00 233.64 4,598.92 4,428.43 6.21 -11.87 2,457,997.50 344,430.22 0.31 0.92 NS-Gyro-MS(1) 4,699.15 0.68 230.70 4,698.91 4,528.42 5.32 -13.03 2,457,996.62 344,429.05 0.32 -0.37 NS-Gyro-MS(1) 4,799.15 0.50 235.95 4,798.90 4,628.41 4.70 -13.85 2,457,996.01 344,428.22 0.19 -1.27 NS-Gyro-MS(1) 4,899.15 0.26 283.87 4,898.90 4,728.41 4.51 -14.43 2,457,995.83 344,427.64 0.38 -1.67 NS-Gyro-MS(1) 9/2/2014 9:25:37PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Project: Soldotna CK Unit TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Site: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Well: Soldotna CK Unit 323-04 North Reference: True Wellbore: SCU 31-04 Survey Calculation Method: Minimum Curvature Design: SCU 31-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,999.15 0.26 323.10 4,998.90 4,828.41 4.75 -14.79 2,457,996.07 344,427.28 0.17 -1.60 NS-Gyro-MS(1) 5,099.15 0.34 352.00 5,098.90 4,928.41 5.22 -14.97 2,457,996.55 344,427.11 0.17 -1.24 NS-Gyro-MS(1) 5,199.15 0.72 6.44 5,198.89 5,028.40 6.14 -14.94 2,457,997.47 344,427.15 0.40 -0.38 NS-Gyro-MS(1) 5,299.15 0.87 19.24 5,298.88 5,128.39 7.48 -14.62 2,457,998.80 344,427.49 0.23 0.97 NS-Gyro-MS(1) 5,399.15 1.01 17.48 5,398.87 5,228.38 9.04 -14.10 2,458,000.35 344,428.03 0.14 2.61 NS-Gyro-MS(1) 5,499.15 1.01 21.63 5,498.85 5,328.36 10.70 -13.51 2,458,002.00 344,428.64 0.07 4.36 NS-Gyro-MS(1) 5,599.15 0.89 17.25 5,598.84 5,428.35 12.26 -12.96 2,458,003.56 344,429.21 0.14 6.01 NS-Gyro-MS(1) 5,699.15 0.77 11.89 5,698.83 5,528.34 13.66 -12.59 2,458,004.95 344,429.60 0.14 7.44 NS-Gyro-MS(1) 5,799.15 0.86 13.43 5,798.82 5,628.33 15.05 -12.28 2,458,006.34 344,429.93 0.09 8.84 NS-Gyro-MS(1) 5,899.15 1.06 13.33 5,898.81 5,728.32 16.68 -11.89 2,458,007.96 344,430.34 0.20 10.49 NS-Gyro-MS(1) 5,999.15 1.16 10.68 5,998.79 5,828.30 18.57 -11.49 2,458,009.85 344,430.77 0.11 12.38 NS-Gyro-MS(1) 6,099.15 1.60 14.03 6,098.76 5,928.27 20.92 -10.96 2,458,012.19 344,431.33 0.45 14.75 NS-Gyro-MS(1) 6,199.15 1.72 16.38 6,198.72 6,028.23 23.71 -10.20 2,458,014.98 344,432.12 0.14 17.61 NS-Gyro-MS(1) 6,299.15 1.59 16.43 6,298.67 6,128.18 26.48 -9.39 2,458,017.74 344,432.98 0.13 20.48 NS-Gyro-MS(1) 6,399.15 1.40 24.10 6,398.64 6,228.15 28.93 -8.49 2,458,020.17 344,433.90 0.28 23.07 NS-Gyro-MS(1) 6,499.15 0.98 21.76 6,498.62 6,328.13 30.84 -7.68 2,458,022.07 344,434.74 0.42 25.15 NS-Gyro-MS(1) 6,599.15 0.91 21.23 6,598.61 6,428.12 32.37 -7.07 2,458,023.59 344,435.37 0.07 26.80 NS-Gyro-MS(1) 6,699.15 0.67 27.69 6,698.60 6,528.11 33.63 -6.51 2,458,024.84 344,435.94 0.26 28.17 NS-Gyro-MS(1) 6,799.15 0.66 27.89 6,798.59 6,628.10 34.66 -5.97 2,458,025.86 344,436.50 0.01 29.33 NS-Gyro-MS(1) 6,899.15 0.69 30.98 6,898.58 6,728.09 35.68 -5.39 2,458,026.88 344,437.09 0.05 30.50 NS-Gyro-MS(1) 6,999.15 0.69 30.41 6,998.57 6,828.08 36.72 -4.78 2,458,027.91 344,437.72 0.01 31.70 NS-Gyro-MS(1) 7,099.15 0.64 31.92 7,098.57 6,928.08 37.71 -4.18 2,458,028.89 344,438.33 0.05 32.85 NS-Gyro-MS(1) 7,199.15 0.62 41.86 7,198.56 7,028.07 38.59 -3.52 2,458,029.76 344,439.00 0.11 33.92 NS-Gyro-MS(1) 7,299.15 0.67 43.27 7,298.56 7,128.07 39.42 -2.76 2,458,030.58 344,439.77 0.05 34.98 NS-Gyro-MS(1) 7,399.15 0.69 46.40 7,398.55 7,228.06 40.26 -1.92 2,458,031.41 344,440.62 0.04 36.09 NS-Gyro-MS(1) 7,499.15 0.81 51.31 7,498.54 7,328.05 41.12 -0.94 2,458,032.25 344,441.62 0.14 37.27 NS-Gyro-MS(1) 7,599.15 0.87 53.95 7,598.53 7,428.04 42.01 0.23 2,458,033.13 344,442.79 0.07 38.55 NS-Gyro-MS(1) 7,699.15 0.84 63.12 7,698.52 7,528.03 42.78 1.50 2,458,033.89 344,444.07 0.14 39.77 NS-Gyro-MS(1) 7,799.15 0.72 62.84 7,798.51 7,628.02 43.40 2.71 2,458,034.49 344,445.29 0.12 40.83 NS-Gyro-MS(1) 7,899.15 0.68 78.85 7,898.50 7,728.01 43.80 3.85 2,458,034.88 344,446.44 0.20 41.66 NS-Gyro-MS(1) 7,999.15 0.73 77.26 7,998.49 7,828.00 44.06 5.05 2,458,035.12 344,447.65 0.05 42.37 NS-Gyro-MS(1) 8,099.15 0.87 76.98 8,098.48 7,927.99 44.37 6.42 2,458,035.41 344,449.01 0.14 43.21 NS-Gyro-MS(1) 8,199.15 0.92 86.68 8,198.47 8,027.98 44.59 7.96 2,458,035.61 344,450.56 0.16 44.02 NS-Gyro-MS(1) 8,299.15 1.00 91.05 8,298.46 8,127.97 44.62 9.63 2,458,035.62 344,452.23 0.11 44.72 NS-Gyro-MS(1) 8,399.15 0.96 101.23 8,398.44 8,227.95 44.44 11.32 2,458,035.41 344,453.92 0.18 45.24 NS-Gyro-MS(1) 8,499.15 1.19 112.86 8,498.43 8,327.94 43.87 13.10 2,458,034.82 344,455.69 0.32 45.44 NS-Gyro-MS(1) 8,599.15 1.17 102.06 8,598.40 8,427.91 43.26 15.06 2,458,034.18 344,457.64 0.22 45.66 NS-Gyro-MS(1) 8,699.15 1.15 102.16 8,698.38 8,527.89 42.83 17.04 2,458,033.73 344,459.61 0.02 46.07 NS-Gyro-MS(1) 8,799.15 0.81 105.53 8,798.37 8,627.88 42.43 18.70 2,458,033.31 344,461.27 0.34 46.37 NS-Gyro-MS(1) 8,899.15 0.84 89.93 8,898.36 8,727.87 42.24 20.11 2,458,033.10 344,462.68 0.23 46.76 NS-Gyro-MS(1) 9/2/2014 9:25:37PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Project: Soldotna CK Unit ND Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Site: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Well: Soldotna CK Unit 323-04 North Reference: True Wellbore: SCU 31-04 Survey Calculation Method: Minimum Curvature Design: SCU 31-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 8,999.15 1.01 48.02 8,998.35 8,827.86 42.83 21.50 2,458,033.67 344,464.08 0.68 47.86 NS-Gyro-MS(1) 0.,...‘12....) .4), 9,099.15 0.66 16.96 9,098.34 8,927.85 43.97 22.33 2,458,034.80 344,464.91 0.56 49.24 NS-Gyro-MS(1) 9,143.00 0.44 35.85 9,142.19 8,971.70 44.35 22.50 2,458,035.18 344,465.09 0.64 49.65 MWD_InterpAzi+sag(2) 9,187.27 3.16 23.01 9,186.43 9,015.94 45.61 23.07 2,458,036.43 344,465.69 6.17 51.04 MWD_InterpAzi+sag(2) 9,210.11 5.48 22.49 9,209.20 9,038.71 47.20 23.74 2,458,038.01 344,466.37 10.16 52.76 MWD_InterpAzi+sag(2) 9,240.04 8.22 22.15 9,238.92 9,068.43 50.50 25.09 2,458,041.29 344,467.77 9.16 56.33 MWD_InterpAzi+sag(2) 9,272.63 10.54 21.95 9,271.07 9,100.58 55.43 27.08 2,458,046.19 344,469.82 7.12 61.64 MWD_InterpAzi+sag(2) 9,306.03 13.62 21.83 9,303.72 9,133.23 61.91 29.69 2,458,052.64 344,472.52 9.22 68.62 MWD_InterpAzi+sag(2) 9,334.34 15.58 21.76 9,331.12 9,160.63 68.54 32.34 2,458,059.23 344,475.25 6.92 75.75 MWD_InterpAzi+sag(2) 9,365.00 17.25 21.70 9,360.53 9,190.04 76.58 35.55 2,458,067.24 344,478.57 5.45 84.41 MWD_InterpAzi+sag(2) 9,396.16 18.90 20.73 9,390.15 9,219.66 85.60 39.04 2,458,076.20 344,482.18 5.38 94.07 MWD+SC+sag(3) 9,427.57 20.76 20.27 9,419.70 9,249.21 95.58 42.77 2,458,086.13 344,486.04 5.94 104.71 MWD+SC+sag(3) 9,438.00 21.49 19.70 9,429.43 9,258.94 99.11 44.05 2,458,089.65 344,487.37 7.27 108.46 MWD_Interp Azi+sag(4) 9,458.70 23.32 19.02 9,448.56 9,278.07 106.56 46.67 2,458,097.06 344,490.08 8.93 116.33 MWD_InterpAzi+sag(4) 9,522.42 23.15 26.99 9,507.13 9,336.64 129.65 56.47 2,458,120.02 344,500.19 4.94 141.41 MWD_InterpAzi+sag(4) 9,584.11 27.06 30.87 9,562.98 9,392.49 152.51 69.17 2,458,142.71 344,513.20 6.87 167.45 MWD_InterpAzi+sag(4) 9,645.38 31.21 31.35 9,616.49 9,446.00 178.04 84.59 2,458,168.03 344,528.95 6.78 197.02 MWD_InterpAzi+sag(4) 9,708.50 35.74 31.74 9,669.13 9,498.64 207.70 102.81 2,458,197.45 344,547.55 7.18 231.50 MWD_InterpAzi+sag(4) 9,766.38 40.43 29.59 9,714.67 9,544.18 238.41 120.98 2,458,227.92 344,566.13 8.42 266.93 MWD_InterpAzi+sag(4) 9,828.60 45.53 28.66 9,760.18 9,589.69 275.46 141.60 2,458,264.69 344,587.24 8.26 309.15 MWD+SC+sag(5) 9,894.38 50.82 27.41 9,804.03 9,633.54 318.72 164.61 2,458,307.64 344,610.82 8.17 358.01 MWD+SC+sag(5) 9,955.31 55.93 24.83 9,840.37 9,669.88 362.62 186.10 2,458,351.26 344,632.89 9.05 406.84 MWD+SC+sag(5) 10,017.02 60.00 24.00 9,873.10 9,702.61 410.25 207.71 2,458,398.59 344,655.13 6.69 459.14 MWD+SC+sag(5) 10,081.02 64.89 23.60 9,902.69 9,732.20 462.15 230.59 2,458,450.19 344,678.70 7.66 515.86 MWD+SC+sag(5) 10,142.40 66.15 24.14 9,928.13 9,757.64 513.23 253.20 2,458,500.97 344,701.98 2.20 571.72 MWD+SC+sag(5) 10,204.77 66.13 24.01 9,953.36 9,782.87 565.31 276.47 2,458,552.73 344,725.93 0.19 628.76 MWD+SC+sag(5) 10,266.37 66.10 24.27 9,978.30 9,807.81 616.71 299.50 2,458,603.82 344,749.64 0.39 685.08 MWD+SC+sag(5) 10,327.80 65.66 24.55 10,003.40 9,832.91 667.76 322.67 2,458,654.57 344,773.49 0.83 741.15 MWD+SC+sag(5) 10,389.35 65.27 24.95 10,028.96 9,858.47 718.61 346.11 2,458,705.10 344,797.60 0.87 797.13 MWD+SC+sag(5) 10,450.77 66.27 24.00 10,054.17 9,883.68 769.59 369.32 2,458,755.76 344,821.47 2.15 853.13 MWD+SC+sag(5) 10,513.99 65.93 23.47 10,079.78 9,909.29 822.50 392.58 2,458,808.36 344,845.44 0.94 910.93 MWD+SC+sag(5) 10,576.20 65.89 23.51 10,105.17 9,934.68 874.58 415.22 2,458,860.14 344,868.76 0.09 967.72 MWD+SC+sag(5) 10,638.20 66.00 23.41 10,130.45 9,959.96 926.52 437.76 2,458,911.78 344,891.98 0.23 1,024.34 MWD+SC+sag(5) 10,700.22 65.82 23.17 10,155.76 9,985.27 978.52 460.14 2,458,963.48 344,915.06 0.46 1,080.95 MWD+SC+sag(5) 10,762.09 65.88 23.52 10,181.07 10,010.58 1,030.36 482.51 2,459,015.01 344,938.11 0.53 1,137.41 MWD+SC+sag(5) 10,824.44 65.56 23.24 10,206.71 10,036.22 1,082.53 505.07 2,459,066.88 344,961.35 0.66 1,194.24 MWD+SC+sag(5) 10,885.89 65.19 23.09 10,232.32 10,061.83 1,133.88 527.04 2,459,117.94 344,984.01 0.64 1,250.10 MWD+SC+sag(5) 10,947.59 65.12 22.94 10,258.24 10,087.75 1,185.42 548.93 2,459,169.18 345,006.58 0.25 1,306.09 MWD+SC+sag(5) 11,011.00 64.91 22.87 10,285.02 10,114.53 1,238.36 571.30 2,459,221.82 345,029.64 0.35 1,363.56 MWD+SC+sag(5) 11,072.50 65.12 22.38 10,311.00 10,140.51 1,289.81 592.75 2,459,272.99 345,051.77 0.80 1,419.29 MWD+SC+sag(5) 9/2/2014 9:25:37PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Project: Soldotna CK Unit TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Site: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') Well: Soldotna CK Unit 323-04 North Reference: True Wellbore: SCU 31-04 Survey Calculation Method: Minimum Curvature Design: SCU 31-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,132.99 64.93 21.86 10,336.54 10,166.05 1,340.61 613.40 2,459,323.51 345,073.09 0.84 1,474.10 MWD+SC+sag(5) 11,195.87 64.03 22.00 10,363.63 10,193.14 1,393.25 634.59 2,459,375.86 345,094.97 1.45 1,530.82 MWD+SC+sag(5) 11,258.43 63.89 21.59 10,391.09 10,220.60 1,445.44 655.46 2,459,427.77 345,116.53 0.63 1,587.00 MWD+SC+sag(5) 11,320.56 63.63 21.75 10,418.56 10,248.07 1,497.23 676.04 2,459,479.29 345,137.79 0.48 1,642.69 MWD+SC+sag(5) 11,380.62 63.01 21.79 10,445.53 10,275.04 1,547.07 695.94 2,459,528.86 345,158.35 1.03 1,696.33 MWD+SC+sag(5) 11,444.20 62.44 21.69 10,474.67 10,304.18 1,599.56 716.87 2,459,581.07 345,179.98 0.91 1,752.80 MWD+SC+sag(5) 11,505.02 61.62 21.37 10,503.19 10,332.70 1,649.53 736.58 2,459,630.77 345,200.35 1.43 1,806.48 MWD+SC+sag(5) 11,568.22 61.23 21.24 10,533.42 10,362.93 1,701.24 756.75 2,459,682.21 345,221.20 0.64 1,861.93 MWD+SC+sag(5) 11,630.60 60.55 21.23 10,563.77 10,393.28 1,752.04 776.49 2,459,732.74 345,241.61 1.09 1,916.38 MWD+SC+sag(5) 11,691.16 60.13 20.61 10,593.74 10,423.25 1,801.19 795.28 2,459,781.64 345,261.05 1.13 1,968.94 MWD+SC+sag(5) 11,738.74 59.77 20.51 10,617.56 10,447.07 1,839.75 809.74 2,459,820.01 345,276.02 0.78 2,010.07 MWD+SC+sag(5) 11,775.00 59.77 20.51 10,635.82 10,465.33 1,869.10 820.72 2,459,849.20 345,287.38 0.00 2,041.35 PROJECTED to TD Checked By: Patrick Walker ,,,,,,- . Approved By: Cary Taylor ry-®,,,,,,,,,u„m'-= Date: 9/2/2014 9/2/2014 9:25:37PM Page 6 COMPASS 5000.1 Build 70 SCU 31-04 Definitive Survey H HEADER INFORMATION H COMPANY : Hilcorp Energy Company H FIELD : Soldotna CK Unit H SITE : Soldotna CK Unit H WELL : Soldotna CK Unit 323-04 H WELLPATH: SCU 31-04 H DEPTHUNT: usft H SURVDATE: 9/2/2014 H H WELL INFORMATION H WELL EW MAP : 344442.01 H WELL NS MAP : 2457991.13 H DATUM ELEVN : 170.49 H VSECT ANGLE : 23.71 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 99.15 - 9098.95 SCU 22-04 GYRO : NS-GYRO-MS H 9143.00 - 9365.00 MWD_INTERP+AZI+SAG : MWD_INTERP AZI+SAG H 9396.00 - 9427. 57 MWD+SC+SAG : MWD+SC+SAG H 9438.00 - 9766.38 INTERP AZI+SAG : MWD_INTERP AZI+SAG H 9828.60 - 11738.74 MWD+SC+SAG : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 18.00 0.00 0.00 18.00 0.00 0.00 99.15 0.15 174.46 99.15 -0.11 0.01 199.15 0.25 133.97 199.15 -0.39 0.18 299.15 0.28 140.89 299.15 -0.73 0.49 399.15 0.31 151.09 399.15 -1.15 0.78 499.15 0.29 139.18 499.15 -1. 58 1.07 599.15 0.37 138.20 599.14 -2.02 1.45 699.15 0.14 158.03 699.14 -2.37 1.71 799.15 0.10 127.06 799.14 -2. 54 1.83 899.15 0.14 38.16 899.14 -2.49 1.97 999.15 0.29 19. 56 999.14 -2.16 2.13 1099.15 0.34 27.47 1099.14 -1.66 2.36 1199.15 0.32 17. 57 1199.14 -1.13 2.58 1299.15 0.41 19.17 1299.14 -0.52 2.78 1399.15 0.36 30.86 1399.13 0.09 3.06 1499.15 0.43 39.32 1499.13 0.65 3.46 1599.15 0.55 52.16 1599.13 1.23 4.07 1699.15 0.47 78.62 1699.12 1.61 4.85 1799.15 0.60 75.70 1799.12 1.82 5.76 1899.15 0. 50 70.86 1899.12 2.09 6.68 1999.15 0. 52 75.68 1999.11 2.34 7. 54 2099.15 0.37 51.78 2099.11 2.66 8.23 2199.15 0.17 45. 52 2199.11 2.96 8. 59 2299.15 0.15 46.42 2299.11 3.15 8.79 2399.15 0.14 139.35 2399.11 3.15 8.96 2499.15 0.02 143.75 2499.11 3.04 9.05 2599.15 0.20 326.26 2599.11 3.18 8.97 2699.15 0.17 307.13 2699.11 3.41 8.75 2799.15 0.23 296.12 2799.11 3.59 8.45 2899.15 0.45 305.23 2899.10 3.90 7.95 2999.15 0.48 292.14 2999.10 4.29 7.24 3099.15 0. 54 298. 51 3099.10 4.67 6.44 3199.15 0.85 314.36 3199.09 5.41 5.50 3299.15 0.88 308.34 3299.08 6.41 4.36 3399.15 0.80 303.27 3399.07 7.27 3.18 3499.15 0.65 294.33 3499.06 7.88 2.08 3599.15 0.60 292.77 3599.05 8.32 1.08 Page 1 • SCu 31-04 Definitive survey 3699.15 0. 59 298.36 3699.05 8.77 0.14 3799.15 0.65 306.77 3799.04 9.35 -0.77 3899.15 0.79 305.72 3899.03 10.09 -1.78 3999.15 0.77 300.76 3999.02 10.84 -2.92 4099.15 0.76 297.18 4099.02 11.49 -4.08 4199.15 1.00 247. 50 4199.01 11.46 -5.48 4299.15 1.23 233.21 4298.99 10.48 -7.15 4399.15 1.29 226.83 4398.96 9.07 -8.83 4499.15 1.25 224.15 4498.94 7.51 -10.41 4599.15 1.00 233.64 4598.92 6.21 -11.87 4699.15 0.68 230.70 4698.91 5.32 -13.03 4799.15 0. 50 235.95 4798.90 4.70 -13.85 4899.15 0.26 283.87 4898.90 4.51 -14.43 4999.15 0.26 323.10 4998.90 4.75 -14.79 5099.15 0.34 352.00 5098.90 5.22 -14.97 5199.15 0.72 6.44 5198.89 6.14 -14.94 5299.15 0.87 19.24 5298.88 7.48 -14.62 5399.15 1.01 17.48 5398.87 9.04 -14.10 5499.15 1.01 21.63 5498.85 10.70 -13. 51 5599.15 0.89 17.25 5598.84 12.26 -12.96 5699.15 0.77 11.89 5698.83 13.66 -12. 59 5799.15 0.86 13.43 5798.82 15.05 -12.28 5899.15 1.06 13.33 5898.81 16.68 -11.89 5999.15 1.16 10.68 5998.79 18.57 -11.49 6099.15 1.60 14.03 6098.76 20.92 -10.96 6199.15 1.72 16.38 6198.72 23.71 -10.20 6299.15 1. 59 16.43 6298.67 26.48 -9.39 6399.15 1.40 24.10 6398.64 28.93 -8.49 6499.15 0.98 21.76 6498.62 30.84 -7.68 6599.15 0.91 21.23 6598.61 32.37 -7.07 6699.15 0.67 27.69 6698.60 33.63 -6. 51 6799.15 0.66 27.89 6798. 59 34.66 -5.97 6899.15 0.69 30.98 6898. 58 35.68 -5.39 6999.15 0.69 30.41 6998. 57 36.72 -4.78 7099.15 0.64 31.92 7098. 57 37.71 -4.18 7199.15 0.62 41.86 7198. 56 38. 59 -3. 52 7299.15 0.67 43.27 7298. 56 39.42 -2.76 7399.15 0.69 46.40 7398. 55 40.26 -1.92 7499.15 0.81 51.31 7498. 54 41.12 -0.94 7599.15 0.87 53.95 7598. 53 42.01 0.23 7699.15 0.84 63.12 7698. 52 42.78 1. 50 7799.15 0.72 62.84 7798. 51 43.40 2.71 7899.15 0.68 78.85 7898. 50 43.80 3.85 7999.15 0.73 77.26 7998.49 44.06 5.05 8099.15 0.87 76.98 8098.48 44.37 6.42 8199.15 0.92 86.68 8198.47 44. 59 7.96 8299.15 1.00 91.05 8298.46 44.62 9.63 8399.15 0.96 101.23 8398.44 44.44 11.32 8499.15 1.19 112.86 8498.43 43.87 13.10 8599.15 1.17 102.06 8598.40 43.26 15.06 8699.15 1.15 102.16 8698.38 42.83 17.04 8799.15 0.81 105.53 8798.37 42.43 18.70 8899.15 0.84 89.93 8898.36 42.24 20.11 8999.15 1.01 48.02 8998.35 42.83 21.50 9099.15 0.66 16.96 9098.34 43.97 22.33 9143.00 0.44 35.85 9142.19 44.35 22.50 9187.27 3.16 23.01 9186.43 45.61 23.07 9210.11 5.48 22.49 9209.20 47.20 23.74 9240.04 8.22 22.15 9238.92 50. 50 25.09 9272.63 10.54 21.95 9271.07 55.43 27.08 9306.03 13.62 21.83 9303.72 61.91 29.69 9334.34 15. 58 21.76 9331.12 68.54 32.34 9365.00 17.25 21.70 9360. 53 76.58 35. 55 Page 2 SCU 31-04 Definitive Survey 9396.16 18.90 20.73 9390.15 85.60 39.04 9427.57 20.76 20.27 9419.70 95.58 42.77 9438.00 21.49 19.70 9429.43 99.11 44.05 9458.70 23.32 19.02 9448. 56 106.56 46.67 9522.42 23.15 26.99 9507.13 129.65 56.47 9584.11 27.06 30.87 9562.98 152.51 69.17 9645.38 31.21 31.35 9616.49 178.04 84. 59 9708. 50 35.74 31.74 9669.13 207.70 102.81 9766.38 40.43 29.59 9714.67 238.41 120.98 9828.60 45. 53 28.66 9760.18 275.46 141.60 9894.38 50.82 27.41 9804.03 318.72 164.61 9955.31 55.93 24.83 9840.37 362.62 186.10 10017.02 60.00 24.00 9873.10 410.25 207.71 10081.02 64.89 23.60 9902.69 462.15 230. 59 10142.40 66.15 24.14 9928.13 513.23 253.20 10204.77 66.13 24.01 9953.36 565.31 276.47 10266.37 66.10 24.27 9978.30 616.71 299. 50 10327.80 65.66 24. 55 10003.40 667.76 322.67 10389.35 65.27 24.95 10028.96 718.61 346.11 10450.77 66.27 24.00 10054.17 769. 59 369.32 10513.99 65.93 23.47 10079.78 822.50 392.58 10576.20 65.89 23.51 10105.17 874.58 415.22 10638.20 66.00 23.41 10130.45 926.52 437.76 10700.22 65.82 23.17 10155.76 978.52 460.14 10762.09 65.88 23.52 10181.07 1030.36 482.51 10824.44 65. 56 23.24 10206.71 1082.53 505.07 10885.89 65.19 23.09 10232.32 1133.88 527.04 10947. 59 65.12 22.94 10258.24 1185.42 548.93 11011.00 64.91 22.87 10285.02 1238.36 571.30 11072. 50 65.12 22.38 10311.00 1289.81 592.75 11132.99 64.93 21.86 10336. 54 1340.61 613.40 11195.87 64.03 22.00 10363.63 1393.25 634.59 11258.43 63.89 21.59 10391.09 1445.44 655.46 11320. 56 63.63 21.75 10418. 56 1497.23 676.04 11380.62 63.01 21.79 10445. 53 1547.07 695.94 11444.20 62.44 21.69 10474.67 1599. 56 716.87 11505.02 61.62 21.37 10503.19 1649. 53 736.58 11568.22 61.23 21.24 10533.42 1701.24 756.75 11630.60 60.55 21.23 10563.77 1752.04 776.49 11691.16 60.13 20.61 10593.74 1801.19 795.28 11738.74 59.77 20.51 10617. 56 1839.75 809.74 11775.00 59.77 20.51 10635.82 1869.10 820.72 Page 3 • Well: SCU 31-04 Grid Conve' 0.757935 Date:2-Sep-14 HALLIBURTON DDI:5.359 170.49 ft V.S.Plane:23.7l° Unwrapped Displacemi 1.74 ®perry Drilling e.rvto.. AID Inc Azimuth TVllSS TVD Local Coordinates Map Coordinates `- DLS Vertical SVY 8 (usft) (°) (°) (usft) 00'0Northing Lasting Northing Lasting (°/IOOosf Section Comments (usft) (usft3 (usft) (usft) t) (rift) 1 18.00 0.00 0.00 -152.49 18.00 0.00 N 0.00 E 344442.01 E 2457991 13 N 0.00 0.00 2 28.49 0.02 174.46 -14200 28,49 0.00 S 0.00 E 344442.01 F 2457991.13 N 0.18 0.00 22"-NS-Gyro-MS(1) 3 99.15 0.15 174.46 -71.34 99, -0.11 S 0.01 E 344442.02 E 2457991.02 N 0.18 -0.09 4 199.15 0.25 13.97 28.66 L -0.39 S 0.18 E 344442.19 II 2457990.74 N 0.17 -0.28 t+, 5 269.15 0.28 140.89 128.66 2 -0.73 S 0.49 E 344442.49 1 2457990.39 N 0.04 -0 47 6 399.15 0.31 151.09 228.66 395' >t -1.15 S 0,78 E 344442.77 I .'.2457989.96 N 0.06 -0.75 .is (t _ 7 499.15 0.29: 139.18 328.66 499.15; -1.58 S 1.07 E 344443.06 1 2457989.53 N 0.07 -1.02 8 599.15 0.37: 138.20 428.65 599 14 -2.02 S 1.45 E 344443.44 I:: 2457989.09 N 0.08 -(26 9 699.15 0.14:: 158.03 528.65 699.14 -2.37 S 1.71 E 344443.69F, 2457988.74 N 0.24 -1.48 10 799.15 0.10 127.06 628.65 799.14 -2.54 S 1.83 E 344443.81 E 2457988.57 N 0.07 -1.59 11 899.15 0.14 38.16 728.65 899.14. -2.49 S 1.97 E 344443.95 E 2457988.61 N 0.17 -1.49 12 999.15 0.29 19.56 828.65 999.14 -2.16 S 2.13 E 344444.12 E 2457988.94 N 0.16 -1.12 13 1099.15 0.34 27,47 92865 1099.14 -1.66 S 2.36 E 344444.34 E 2457989.44 N 0.07 -0,57 14 1199.15 0.32 17.57 1028.65 1199.14 -1.13 S 2.58 E 344444.57 E 2457989.97 N 0.06 0.00 15 1299 15 0.41 19.17 1128.65 1299.14 -0.52 S 2.78 E 344444.78 E<2457990 57 N 0.09 0.64 16 1399.15 0 36 30.86 1228.64 I39 s 0.09 N 3.06 E 344445.07 E 2457991 17 N 0.09 1,31 17 1413.51 0.37 32.27 1243.00 1410.16 N 3.11 F. 344445.12 E 2457991 25 N 0.09 'fi6i 11 3/4" 18 1499.15 0.43' 1328.64 149' 0.65 N 3.46 F. 344445.48 E 2457991 73 N 0.09 1.98 19 1599 15 0.55 r 1428.64 1599. 1 1.23 N 4,07 E 344446.10 E 2457992 31 N 0.16' ' 2.76 20 169915 0.47` 78.62 1528.63 169912 1.61 N 4,85 E 344446.89 E.)-s.2457992 67 N 0.25 3.42 21 1799.15 0.60 75.70 1628.6: 1700 12 1.82 N 5,76 E 344447.80 E =2457992.87 N 0.13 3.98 22 1899.15 0.50 70.86 1728.63 1899 12 2.09 N 6.68 E 344448.72 F 2457993 13 N 0.11 4.60 23 1999.15 0.52 75.68 1828.62 1999.11 2.34 N 7.54 E 344449.58 F. 2457993 37 N 0.05 5.18 24 2099.15 0.37 51.78 1928.62 2099.11 2.66 N 8.23 E 344450.27 I[ 2457993.68 N 0.24 5.74 25 2199.15 0.17 45.52 2028.62 2199.11. 2.96 N 8.59 E 344450.64 E 2457693.97 N 0.20 6.16 26 2299.15 0.15 4642 2128.62 2299.11 3.15 N 8.79 E 344450.84 E 2457994 17 N 0.02 6.42 27 2399.15 0.14 139.35 2228.62 2399.11 3.15 N 8.96 E 344451.01 E 2457994 16 N 0.21 6.49 28 2499.15 0.02 143.75 2328,62 2499.11 3.04 N 9.05 E 344451.10 E 245799405 N 0.12 6.43 29 2599.15 020 326.26 2428.62 2599,11 3.18 N 8,97 E 344451.02 E ;2457994.19 N 0.22 6.51 30 2699,15 0.17 307.13 2528.62 2699.11 3.41 N 8,75 E 344450.81E ' 994 42 N 0.07 6.64 31 2799.15 0.23 296.12 2628.62 2799.11 3.59 N 8,45 E 344450.51 E 094.61 N 0.07 6.68 32 2899.15 0.45 305.23 2728.61 2899.10 3.90 N 7.95 E 344450.01 E 4 '5799493 N 0.23 6.77 33 2999.15 0.48 292.14 2828.61 2999.10 4.29 N 7.24 E 344449.31 E'S'245799532 N 0.11 6.84 34 3099.15 0.54 298.51 2928.61 3099.10 4.67 N 6.44 E 344448.51 F =2457995.71 N 0.08 6.87 35 3199.15 0.85 314.36 3028.60 3199.09 5.41 N 5.50 E 344447.58 E 2457996.47 N 036 7.17 36 3299.15 0.88 308.34 312859 3299.08 6.41 N 4.36 E 344446.46 E 2457997.48 N 0.10 7.62 37 3399.15 0.80 303.27 3228.58 3399.07 7.27 N 3.18 E 344445.28 E 2457998 35 N 0.11 7.93 38 3499.15 0.65 294.33 3328.57 3499.06. - 7.88 N 2.08 E 344444.19 E 2457998.99 N 0.19 8.05 - 39 3599.15 0.60 292.77 3428,56 3599.05'. 8.32 N 1.08 P. 344443.20 E 2457999.44 N 0.05 8.05 40 3699.15 0.59 298.36 3528,56 3699.05 8.77 N 0.14 E 344442.27 E 2457999.89 N 0.06 8.09 41 3799.15 0.65 306.77 3628,55 3799 04. 9.35 N -0.77 W 344441.37 E 2458000.49 N 0.11 8.26 42 3899.15 0.79 305.72 3728.54 3899.03 10.09 N -1,78 W 344440.36 E 2458001 25 N 0.14 8.53 43 3999.15 ((77 300.76 3828.53 3999.02' 10.84 N -2,92 W 344439.24 E '2458002.01 N 0.07 8.75 44 4099.15 0.76 297.18 3928.53 409902` 11.49 N -4.08 W 344438.08 1, 2458002.67 N 0.05 8.88 45 4199.15 I.00 247.50 4028.52 4199.01 11.46 N -5.48 W 344436.68 1. 245800266 N 0.77 8.29 46 4299.15 1.23 233.21 4128.50 4298.99 10.48 N -7.15 W 344435.00 I. 2458001.70 N 0.36 6.72 47 4399.15 1.29 226.83 4228.47 4398.96 9.07 N -8.83 W 344433.30 11 2458000.31 N 0.15 4.75 48 4499.15 1.25 224.15 4328.45 4498.94 7.51 N -10.41 W 344431.70 I[ 2457998.78 N 0.07 2.70 49 4599.15 1.00 233.64 4428.43 4598.92 6.21 N -11,87 W 344430.22 E 2457997,50 N 0.31 0.92 50 4699.15 0.68 .230.70 452842 4698.91 5.32 N -13.03 W 344429,05 F 2457996.62 N 0.32 -0.37 51 4799.15 0.50 235.95 4628.41 4798.90 4.70 N -13,85 W 344428.22 1' 2457996.01 N 0.19 -127 52 4899.15 0.26 283.87 4728.41 4898.90 4.51 N -14,43 W 344427.64 1', 2457995.83 N 0.38 -1.67 53 4999.15 0.26 323.10 4828.41 4998.90 4.75 N -14.79 W 344427.28 I: 2457996.07 N 0.17 -1.60 54 5099.15 0.34 352.00 4928.41 5098.90: 5.22 N -14.97 W 344427.11 I. 2457996.55 N 0.17 -1.24 55 5199.15 0.72 6.44 5028.40 5198,89 6.14 N -1494 W 344427.15 E 2457997.47 N 0.40 -038 56 5299.15 0.87 19.24 5128.39 5298,88 7.48 N -14.62 W 344427.49 E =2457998.80 N 0.23 0.97 57 5399.15 1.01 17.48 5228.38 5398.87 9.04 N -14.10 W 344428.03 E 2458000.35 N 0.14 2.61 58 5499.15 1.01 21.63 532836 5498.85 10.70 N -13.51 W 344428.64 E 2458002.01 N 0.07 4.36 59 5599.15 0.89 17.25 5428.35 5598.84 12.26 N -12.96 W 344429.22 E 2458003.56 N 0.14 6 01] 60 5699.15 0.77 11.89 5528.34 5698.83 13.66 N -12.59 W 344429.60 F 2458004 95 N 0.14 7.44 61 5799.15 0.83 13.43 5628.33 5798,82 15.05 N -12.28 W 344429.93 E 2458006.341,,, 0.09 8.84 62 5899.15 I.06 13.33 5728.32 5898.81 16.68 N -11,89 W 344430.34 E 2458007.90.20 1049 63 5999,15 1,16 10,68 5828.30 5998.79 18.57 N -11.49 W 344430.77 E 2458009.85 N 0.11 12,38 64 6099.15 1.60 14.03 5928.27 6098.76 20.92 N -10.96 W 344431.33 E 2458012 19 N 0.45 14.75 65 6199.15 1.72 16.38 6028.23 6198.72 23.71 N -10.20 W 344432.12 I3 2458014.98 N 0.14 17.61 66 6299.15 1.59 16.43 6128.18 6298.67 26.48 N -9,39 W 344432.98 I' 2458017.74 N 0.13 20.48, 67 6399.15 1.40 24.10 6228.15 639864 28.93 N -8,49 W 344433.90 F. 2458020.17 N 0.28 23.07 68 6499.15 0.98 21.76 6328.13 6498.62 30.84 N -7,68 W 344434.74 E 2458022.07 N 0.42t 25 15 69 6599.15 0.91` 21.23 6428.12 6598,61. 32.37 N -7.07 W 344435.37 E' 2458023.59 N 0,07 ' `�26 80 70 ` 6699,15 0.67 27.69 6528.11 6698,60 33.63 N -6.51 W 344435.94 E#-2458024 84 N 0.26 28.17 71 6799.15 0.66 27.89 6628.10 6798,59 34.66 N -5.97 W 344436.50 E2458025.86 N 0.01 29.33 72 6899,15 0.69 30.98 6728.09 6898.58 35.68 N -5.39 W 344437.09 E 2458026.88 N 0.05 30.50 73 6999.15 0.69 .30.41 6828.08 6998.57 36.72 N -4.78 W 344437.72 F 2458027.91 N 0.01 31.70 74 7099.15 0.64 31.92 6928.08 7098.57 37.71 N -4.18 W 344438.33 E 2458028.89 N 0.05 32.85 75 7199.15 0.62 41.86 7028.07 7198.56 38.59 N -3.52 W 344439.00 F 2458029.76 N 0.11 33.92 76 7299.15 067 43.27 7128.07 7298.56 39.42 N -2,76 W 344439.77 E 2458030.58 N 0.05 34.98 77 7399.15 0.69 46.40 7228.06 7398.55 40.26 N -1,92 W 344440.62 E 2458031.41 N 0.04 36.09 78 7499.15 0.81 51.31 7328.05 7498.54 41.12 N -0,94 W 344441.62 E 2458032.25 N 0.14 37.27 79 7599.15 0.87 53.95 7428.04 7598.53 42.01 N 0.23 E 344442.80 E5 2458033.13 N 0.07 € Page 1 of 2 • - Local Coordinates slap Coordinates DLf rticaI' 1AID Inc Azimuth TRUSS SVA N Northing Lasting Northing Fasting (%100 coon Comments (nsft) (°) (°) (rift) (m. lusfll (usft) (usft) Cosh) t) (asfp b - ` 80 7699.15 0.84 63.12 7528.03 7698.52 42.78 N 1.50 E 344444.07 E 2458033.89 N 0.14 39.77 81 7799.15 0.72 62.84 7628.02 7798.51 43.40 N 2.71 E 344445.29 E 2458034.49 N 0.12 40.83 82 7899.15 0.68 78.85 7728.01 7898.50 43.80 N 3.85 E 344446.44 E 2458034.88 N 0.20 41.66 83 7999.15 0.73 77.26 7828.00 7998.49 44.06 N 5.05 E 344447.65 E2458035.12 N 0.05 4237 84 8009.15 0.87 76.98 7927.99 8098,48 44.37 N 6.42 E 344449.01 E 2458035.41 N 0.14 4321 85 8199.15 0.92 86.68 8027.98 81� 44.59 N 7,96 E 344450.56 E 12458035.61 N 0.16 44.02 86 8299.15 1.00 91.05 8127.97 82 r'* 44.62 N 9.63 E 344452.23 E 2458035.62 N 0.11 41.72 87 8399.15 0.961 101.23 8227.95 83 44.44 N 1 l 32 E 344453.92 L 2458035.41 N 0.18 4524 88 8409.15 1.19 112.86 8327.94 8498'"' 43.87 N 13.10 E 344455.69 11 2458034.82 N 0.32 45.44 89 8599.15 1.17' 102.06 8427.91 8598.40 43.26 N 15.06 E 344457.64 11 2458034.18 N 0.22 45.66 90 8699.15 1.15 r 102.16 8527.89 8698.38 42.83 N 17.04 E 344459.61 E 2458033.73 N 0.02 46.07 91 8799.15 0.81 105.53 8627.88 879837. 42.43 N 18.70 E 344461.27 1 2458033.31 N 0.34 4637 92 8899.15 0.84" 89.93 8727.87 8898.36 42.24 N 20.11 E 344462.68 1. 2458033.10 N 0.23 46.76 93 8999.15 1.01 48.02 8827.86 8998.3511 42.83 N 21.50 E 344464.08 E 2458033.67 N 0.68 47.86 94 9099.15 0.66 16.96 8927.85 9098 34. 43.97 N 22.33 E 344464.92 E 2458034.80 N 0.56 49.24 95 9143.00 0.44 35.85 8971.70 9142.19 44.35 N 22.50 E 344465.09 E 2458035 18 N 0.64 49.65 51 WD_Interp Azi+sag(2) 96 918727 3.16 23.01 9015.94 9186.43 45.61 N 23.07 E 344465.69 E 2458036 43 N 6.17 51.04 97 9210.11 5.-18 2249 9038.71 9209.20 47.20 N 23,74 E 344466.37 E '2458038.01 N 10.16 52.76 98 9240-04 8.22 22 15 9068.43 9238.92 50.50 N 25.09 E 344467.77 1. '.2458041 30 N 9.16 5633 99 9272.63 10.54 21.95 9100.58 9271 07 55.43 N 27.08 E 344469.83 1. 2458046 19 N 7.12 61.64 100 9306.03 13.62. 21.83 9133.23 9303.72 61.91 N 29.69 E 344472.52 1' -2458052.64 N 9.22 68.62 101 9334.34 15.581 21.76 9160,63 9331.12'. 68.54 Niki 32.34 E 344475.25 E-2458059.23 N 6.92 7575 102 9365.00 17.25 21.70 9190.04 9360 53. 76.58 N ' x35.55 E 344478.57 E 2458067 24 N 5.45 84.41 103 9396.16 18.90 20.73 9219.66 9390 15' 85.60 N 39.04 E 344482.18 E 2458076.20 N 5.38 94-07 AI WD+SC+,sag(3) Tie-On 9427.57 20.76 20.27 924921 9419.70 95.58 N 42.77 E 344486.04 E 2458086.13 N 5.94 104.71 1 9438.00 21.49 19.70 9258.9-4 9429.43 99.11 N 44.05 E 344487.37 E 2458089.65 N 7.27 108.46 3(WD_Interp Azi+sag(4) 2 9458.70 23.32 19.02 9278.07 9448.56 106.56 N 46.67 E 344490.08 E 2458097.06 N 8.93 116.33 3 9522.42 23.15 26.99 9336.64 9507,13 129.65 N 56.47 E 344500.19 E 2458120.02 N 4.94 141.41 4 9584.11 27.06 30.87 9392.49 9562.98 152.51 N 69.17 E 344513.20E 2458142.71 N 6.87 167.45 5 9645.38 31.21 31.35 9446.00 96104 178.04 N 84.59 E 344528.95 1 2158168.03 N 6.78 197.02 f> 9708.50 35.74 L 31.74 9498.64 96 207.70 N 102.81 E 344547.55 E 245819745 N 7.18 231.50 7 9766.38 40.431, 29.59 9544.18 9714, 7 238.41 N 120.98 E 344566.13 E245822792 N 8.42 266.93 8 9828.60 45.531-1:: 28.66 9589 69 9760.18 275.46 N 141.60 E 344587.24 E 2458264.69 N 8.26 309.15 MWD+SC+sag(5) 9 9894.38 50.82 27.41 9633.54 9804.03 318.72 N 164,61 E 344610.82 E 2458307.64 N 8.17 358.01 10 9955.31 55.93 24.83 9669.88 9840.37 362.62 N 186,10 E 344632.89 E 2458351.26 N 9.05 406.84 11 10017.02 60.00 24.00 9702.61 9873.1C 410.25 N 207,71 E 344655.13 E 2458398.59 N 6.69 459.14 12 10081.02 64.89 23.60 9732.20 9902.69 462.15 N 230.59E 344678.70 I; 2458450.19 N 7.66 515.86 13 10142.40 66.15 24.14 9757.64 9928.13. 513.23 N 253.20 E 344701.98 E 2458500.97 N 2.20 571.72 14 10204 77 66.13 ?. ---2____ _4.OI 9782,87 9953.36 565.31 N 276.47E 344725.93E 245855_.73 N 0.19 628.76 15 10266.37 66,10 24.27 9807.81 9978.30 616.71 N 299.50 E 344749.65 E 2458603.82 N 0.39 685.08 16 10327.80 65.66 24.55 9832.91 10003 40 667.76 N 322.67 E 344773.49 E 2458654 57 0.83 741,15 17 10389.35 65.27. 24.95 9858,47 10028.96 718.61 N 346.11 E 344797.60 E 2458705 10', 0.87 7 18 10450.77 66.27 24.00 9883.68 1005417' 769.59 N 369.32 E 344821.47 E 2458755.77 N 2.15 ., s 19 1051399 65.93'=1- 23.47 9909.29 10079 78 822.50 N 392.58 F. 344845.44 E 2458808.36 N 0.94.`g&ask, 20 10576 20 65.89} 23.51 9934.68 10105.17 874.58 N 415.22 1: 344868.76 E 2458860.14 N 0.094MAL 21 1063820 66.00: 23.41 9959-96 1013045 926.52 N 4.7,76 E 344891.99 E 2458911.78, N 0.23 102'11 .; 22 1070022 65.82 23.17 9985.27 10155.7 978.52 N 460.14 E 344915.06 E 2458963.48 N 0.46 1080.95 23 10762.09 65.88 23.52 10010.58 10181 07 1030.36 N 482.51 E 344938.11 E 2459015.01 N 0.53 1137.41 24 10824.44 65.56 23.24 1003622 10206.74. 1082.53 N 505.07 E 344961.35 E 2459066.88 N 0.66 119424 25 10885.89 65.19 23.09 10061.83 1023232 1133.88 N 527.04E 344984.01 E 2459117.94 N 0.64 1250.10 26 10947.59 65.12 22.94 10087.75 1025824. 1185.42 N 548.93 E 345006.58 E 2459169.18 N 0.25 1306.09 27 11011.00 64.91 - 22.87 10114.53 1028502 1238.36 N 571.30 E 345029.64 E 2459221.82 N 0.35 1363.56 28 11072.50 65.12 22.38 10140.51 10311.00 1289.81 N 592.75 E 345051.77 E 2459272.99 N 0.80 1419.29 29 1 1 132.99 64.93 21.86 10166.05 10336 54 1340.61 N 613,40 E 345073.09 E 2459323.51 N 0.84 1473 10: 30 1 1 195.87 64.03 22.00 10193.11 10363 63 1393.25 N 634.59 E 345094.97 E;2459375.86 N 1.45 1530 82^ 31 11200.77 64.02 21.97 1019529 10365 78 1397.34 N 636.24 E 345096.68 E 2459379.93 N 0.63 1535.23 SCU 31-04 SR_H1ST Tgt 1 32 11258.43 63.891,59 10220.60 10391 09 1445.44 N 655,46 E 345116 53 E.5,.2459427 77 N 0.63 1587 00 33 11320.56 63 63 x,75 10248.07 10418 56 1497.23 N 676,04 E 345137 79 Et-12459479,29 N 0.48 1642 69 bs 34_ 11380.62 63.01= 21.79 10275-04 10445 53 1547.07 N 695,94 E 345158.35 E 2459528.86 N 1.03 169w 35 11444?0 62.44` 21.69 10304.18 1047467 1599.56 N 716,87E 345179.98 E 245958107 N 0.91 17520 36 11505.02 61.62 2137 10332.70 10503 19 1649.53 N 736.58 E 345200.35 E 2459630.77 N 1.43 1806 4R 37 11568.22 61.23 21.24 10362.93 10533 42. 1701.24 N 756.75 E 345221.20 E 2459682.21 N 0.64 1861.93 38 11630.60 60.55 21.23 10393.28 10563 77 1752.04 N 776.49 E 345241.61 E 2459732-74 N 1.09 191638 39 11691.16 60.13 20.61 10423.25 10593.74 1801.19 N 795.28 E 345261.05 E 2459781.64 N 1.13 1968.94 40 11738 74 59.77 . 20.51 10447.07 10617.56. 1839.75 N 809.74 E 345276.02 E 2459820.01 N 0.78 2010.07 SCU 31-04 SR_H7ST Tgt 2 41 11775.00 59.77 20.51 10465.33 10635 82 1869.10 N 820.72 E 345287.38 E 2459849.20 N 0.00 2041.35 PROJECTED to TD Page 2 of 2 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. SCU-31-04 Date 19-Aug-14 County Kenai Peninsula Borough State Alaska c Supv. Rance Pederson/Jimmy Greco CASING RECORD IS "Z.dte•- TD 11775.00 Shoe Depth: 11773.00 PBTD: 11648.76 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length _ Bottom Top Shoe 41/2 1-80 WFD 1.61 11,773.00 11,771.39 2 Joints 41/2 12.6 L-80 JWC/C-H" 79.85 11,771.39 11,691.54 Flt Clr 4 1/2 WFD 1.39 11,691.54 11,690.15 1 Joint 4 1/2 12.6 L-80 JWC/C-H- 40.27 11,690.15 11,649.88 Landing Clr 41/2 WFD 1.12 11,649.88 11,648.76 68 Joints 4 1/2 12.6 L-80 JWC/C-H- 2,664.23 11,648.76 8,984.53 Pup Joint 4 1/2 12.6 L-80 DWC/C-H- 6.10 _ 8,984.53 8,978.43 Hanger/Pckr 7.625 DWC/C-H- Baker 31.89 8,978.43 8,946.54 Totals Csg N.On Hook: 47,578 Type Float Collar: Model 402E No.Hrs to Run: 20.5 Csg'M.On Slips: Type of Shoe: Bull Nose/303E Casing Crew: WFD Fluid Description: 11.1 ppg 6%kcl/polymer,PV 12,YP 17 Liner hanger Info(Make/Model): Baker-Flex-Lock w/HRD-E ZXPN Packer Liner top Packer?: x Yes _No Liner hanger test pressure: 1000 Centralizer Placement: 1 free floating Valant centralizer per joint CEMENTING REPORT Preflush(Spacer) Type: Mud Push II _ Density(ppg) 12 Volume pumped(BBLs) 16 Lead Slurry Type: Class G Density(ppg) 15.3 Volume pumped(BBLs) 85 Mixing/Pumping Rate(bpm): 4.9 Tail Slurry Type: Icj Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): w Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: 0 LL Displacement: Type: Produce Water Density(ppg) 8.5 Rate(bpm): 8 Volume(actual/calculated): 162/164 FCP(psi): 2400 Pump used for disp: Schlumberger Plug Bumped? x Yes No Bump press 5000 Casing Rotated? Yes x No Reciprocated? x Yes No %Returns during job 100 Cement returns to surface? x Yes No Spacer returns? X Yes No Vol to Surf: 10 Cement In Place At: 1:40 Date: 8/19/2014 Estimated TOC: 8,946 Method Used To Determine TOC: With cement to surface we know we have cement at liner hanger top. I 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): y Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w Displacement: co 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 CIW Type Serial No. Size 7 1/16 W.P. 5000 Test Head To 250/5000 PSIG 15 MIN test good OK Remarks: SCU 31-04 Days Vs Depth 8000 -- -SCU 31-04 Plan -SCU 31-04 Final 8500 9000 9500 5 10000 a Z.) L z 110500 a P "t( 11000 11500 12000 1'A)/ 12500 , 0 5 10 15 20 25 30 35 40 Days SCU 31-04 MW Vs Depth 8000 - -SCU 31-04 Plan SCU 31-04 PB1 - SCU 31-04 Final 8500 9000 9500 s10000 d v S3 10500 2 11000 11500 12000 12500 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) 0 Note to File 10-1-2014 Well SCU 31-04 (PTD 214-090) Water Flow Zone While Drilling Discussion While drilling SCU 31-04(a sidetrack of well SCU 22-04) an influx of higher pressure water was seen while drilling to the Hemlock target zone. During a BOP test,an AOGCC inspector noticed that the casing was open to the trip tank and the well was flowing about 6 BHP (mud returns)during the test. This obviously raised concerns regarding well control. SCU 31-04 was sidetracked at 9157' measured depth,which is above the target Hemlock reservoir and in a known area of"waterflow zones." These waterflow zones are at a significantly higher pressure (approx. 11.4 ppg EMW)than the underlying, depleted Hemlock zones(approx. 3.6-4 ppg EMW). These water flow zones are discontinuous sand lenses that are found at various depths above the Hemlock. Since these sand lenses are not continuous,the issue is not cement channeling of the upper waterflow zone, but the fact that these discontinuous zones may or may not be penetrated while drilling to the Hemlock below. Thus cement channeling after cutting the window for the sidetrack is not what is occurring. Hilcorp is maintaining well control by keeping the waterflow zones almost at balance as too much mud weight will cause lost circulation issues with the Hemlock. Even with reduced mud weight (10.5-11.0 ppg)there are only partial returns while drilling. Once circulation is stopped, bottom-hole pressure is reduced,which causes the well to be slightly underbalanced and allows some water to flow into the wellbore (with no associated gas). The influx of water(at 8.4 ppg)dilutes the mud somewhat but never reduces the bottom-hole pressure to enough to allow the Hemlock formation to flow (Hemlock is 4 ppg EMW). While this is not standard drilling practice,the absence of substantial gas-cut mud during circulation just above the Hemlock formation indicates that the well is not becoming underbalanced to the hydrocarbon reservoir. AOGCC's recommendation is to encourage Hilcorp to have a contingency to top set casing in future sidetrack wells that see a water influx, regardless of economics. The loss of a drilling bottom-hole assembly in SCU 31-04 was also partially attributed to the significant pressure differences between these zones,and top setting would have likely prevented this loss. Hilcorp normally top sets the waterflow zone in grassroots wells to avoid this problem. Guy Schwartz /01/1 if 74/ AOGCC 2_,4, ...0,, o II Debra Oudean Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8337 Hilrnrp Alaska.1.1.x; Fax: 907 777-8510 D LOGGE DATA E-mail: doudean@hilcorp.com c A OGLE M. .BENDEF RECEIVED DATE 09/26/14 SEP 292014 To: Alaska Oil & Gas Conservation Commission ���^l�� Makana Bender Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 31-04 & SCU 31-04 PB1 Zig o-1 24-q ov4 Elog data 2Lt_°10'z) '2.4-0% D Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron TVD CD 1: Final Well Data CGM 9/26/2014 10:59 A... File folder DLIS+LAS 9/26/2014 10:59 A... File folder k EMF 9/26/2014 10:59 A... File folder PDF 9/26/201410:59 A... File folder ji, TIFF 9/26/2014 10:59 A... File folder CD 2: Directional survey data 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 Receivedp.),Agaye4,L,17) `e„`,ezt Date: Debra Oudean Hilcorp Alaska, LLC -2.40C 5 GeoTech II 3800 Centerpoint Drive, Suite 100 •L1e52, Anchorage, AK 99503 Tele: 907 777-8337 Ifilcurp Uarkn.1.1.1 Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED /201 M.K.BENDER DATE 07/30/14 To: Alaska Oil & Gas Conservation Commission Makana 333 W 7th Bender Ste 100 RECEIVED Anchorage, AK 99501 SEP 16 2014 DATA TRANSMITTAL AOGCC SCU 31-04 & SCU 31-04PB1 Mudlog Data Prints: Final Well Report Formation Log MD 5" Formation Log TVD 5" Formation Log MD 2" Formation Log TVD 2" LWD Combo Log MD 2" LWD Combo Log TVD 2" Drilling Dynamics MD 2" Drilling Dynamics TVD 2" Gas Ratio Log MD 2" Gas Ratio Log TVD 2" CD : Final Well Data Files Currently on the Disc (8) Daily Reports 9/12/2014 10:30 A... File folder DML Data 9/12/2014 10:30 A... File folder LAS Data 9/12/2014 10:30 A... File folder Log PDFs 9/12/2014 10:30 A... File folder Log TIFFS 9/12/2014 10:30 A... File folder Show Reports 9/12/2014 10:30 A... File folder xSCU 31-04 PB1 9/12/2014 10:30 A... File folder SCU 31-04-Final Well Report.pdf 9/11/2014 10:36 A... Adobe Acrobat D... 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 Received By, ✓ L-420V I5e.c.e4tDate: c9fLI—oto Debra Oudean Hilcorp Alaska, LLC /L6� GeoTech II 3800 Centerpoint Drive, Suite 100 / l Anchorage,AK 99503 Tele: 907 777-8337 IiGMarp tln.ka.1.1.(. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 9/15/2013 To: Alaska Oil & Gas Conservation Commission Makana Bender, Natural Resource Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Transmitted herewith are cuttings WELL BOX# SAMPLE INTERVAL SCU 31-04 PB1 BOX 1 9180'- 10350' SCU 31-04 PB1 BOX 2 10350'- 11360' SCU 31-04 PB1 BOX 3 11360'- 11820' SCU 31-04 PB1 BOX 4 11820'- 11960' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receiv:'!y ' Date: • AOGCC .2/4l- oqo Debra Oudean Hilcorp Alaska, LLC /'/ GeoTech II 3800 Centerpoint Drive, Suite 100 ` 'C Anchorage,AK 99503 Tele: 907 777-8337 FI�I,uri11:14.1.LT.t. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 9/15/2013 To: Alaska Oil & Gas Conservation Commission Makana Bender, Natural Resource Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL Transmitted herewith are cuttings WELL BOX # SAMPLE INTERVAL SCU 31-04 ST BOX 1 9510'- 10790' SCU 31-04 ST BOX 2 10770'- 11360' SCU 31-04 ST BOX 3 11360'- 11775' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received ByLim Date: RECEIVED SEP 15 2014 AOGCC t � Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, August 27, 2014 3:29 PM To: 'Monty Myers' Cc: Luke Keller; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)' Subject: RE: SCU 31-04 (214-090) WaterFiow zone Monty, The AOGCC is concerned about operating SCU/SRU wells in this manner during drilling. It would be helpful if yourself, Luke and some geologists came over to explain this particular well behavior to us and your thoughts on well control . If Paul Mazzonili can make it that would be great also. Let us know when you can come over and we will schedule it. 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(s1.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 1 or(Guy.schwartz@alaska.gov). From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Monday, August 25, 2014 2:56 PM To: Schwartz, Guy L (DOA) Subject: RE: SCU 31-04 (214-090) Hey Guy, We have seen this on almost every well we have sidetracked now. We plan to kick off below the high pressure water zone so we don't have to deal with it. On some wells, like SCU 31-04, we saw it immediately. On others it takes a few hundred feet to see it. We do have CBL's that we are going off of and the plan is to kick off in pipe where there is "good" cement. We have found that it doesn't necessarily matter. The water must be channeling down the annulus and into the wellbore through the window. I haven't listed the water zone as a hazard because we know that the water is there, and we always treat the first encounter of the water flow as if it could potentially have gas or be gas. We have gotten better at predicting the mud weight to "kill" the flow with ECD and only see it during connections. We haven't planned any squeeze work because there would be nothing to squeeze. As I mentioned we are using CBL's to help select our KOP. However, some of the CBL's are old ones from the original wells. The drilling summary must have missed the BOP test witness with John crisp?We have it in our drilling report. 1 t TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 9:30 3.5 Clear and clean rig floor, RU test manifold and pump, flush BOP stack, pull wear ring, install test plug, purg[ (drl)Idisc line and choke manifold. Install test joint and shell test stack. IAOGCC Rep John Crisp on location to witness BOP test.Released sample catchers. Delivered samples to 9:30 17:30 8.0 Tstg BOP/WH/Perform bk-weekly BOPE test at 250/3500 psi(2502500 on annular)at 10 minute intervals. Had pass fail or CMV#9. Functioned HCR and re-tested ok. Attempted to replace gate seals in CMV#9 then changed out valve completely.Shell tested CMV and flang tested CMV#9 ok.Total Safety tested gas detection equip. SLB loaded silo with 430 sx(90 bbls)of cement and spotted batch mixer. Koomey test: System PSI-3100,, 200 psi Attained-20 sec, Full PSI Attained-90 sec. Gained 76 bbls at surface, over 12 hours from annulus. Rig crew installed wear ring during CMV#9 test a sub in prep to RIH. 17:30 18:00 0.5 Rig Service Serviced rig and topdrive for trip in hole. 18:00 18:30 0.5 (drl)Misc Rig down testing equipment and blow down choke. The flow out that you are reading is talking about partial returns. We are pumping at drilling rates, but only get back 27% of what we are pumping.This well acted very weird, because we had a water flow and also loss circulation. And then the well would give back some fluid. It was the strangest acting well I have ever encountered. On the 17th we were performing some short trips to clean up the well bore for our liner run and we had spotted some weighted pills to control the flow. On my report I have static or flow associated with all the times we stopped to check? Can you be more specific on this piece? 2 Hilcorp Energy C. pony IDRILLING DAILY REPORT REPORT NO. LEASE WELL NO. COUNTY;PARISH iVELL STATE 35 FEDA028997 31-04 1F SCU 31-04(ST SCU 22- AK RIG AFE NO. AFE BUDGET DAILY COST CDC RIG F Saxon 169 1411838D 3332500 41111101. 1111111111111 907-Tr ACTIVITY TYPE: DRLG Drilling RD Rig C DEPTH:MD/TVD PROGRESS/HRS PROP.TD LAST SHOETEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR 11936 7/20/2014 29 34 R Pederson l J Greco ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S LD CDS-40 DP at 7529'. TIME LOG ELAPSED ACTIVITY COMMENTS FROM TO TIME 6:00 7:00 1.0 Circ&Cond Coat circulating at 9115'(just above casing window)with cleanout assembly, at 247 gpm-854 psi.BGG we units.Well flows at 8 bph. 7:00 11:00 4.0 Wash&Ream Single in hole 4 joints with no problem exiting window. RIH from derrick,at 9613'had tight hole,MU topdrive down to 9633'.At more tight holes issues at 9830'and 9899'. At 10,320'MU topdrive and washed ream remaining stands to bottom at 11,775'as hole got sticky.While w; 10,320'we had a max of 1440 units gas to surface. 13:30 15:00 1.5 Circ&Cond Pumped 20 bbl hi-vis sweep as we washed last single to bottom at 284 gpm-1397 psi,90 rpm-8081 to 8317 BGG at 180 units. Had 200%increase in cuttings with sweep to surface consisting of sand, fine coal and pea sized coal. BGG dropped to 32 units. Reloeased the two S Peak hands build containment and spot frac tank. 15:00 18:00 3.0 (drl)Trips POOH from 11,775'having to rotate and pump out of hole to 11,030'. Stopping rotation or pump we immediat 11,030'we could pull on elevators at 200K up weight. At 10,505'we stopped to check for flow and had no flow. Coat POOH on elevators to 9116'(Just above 7' tight hole at 9332'.Checked for flow again and had no flow. 18:00 19:30 1.5 Rig Service Crew change, PJSM,slip and cut 150'of drill line with well on trip tank. Service rig. 19:30 21:30 2.0 (drl)Trips Trip in hole F19115'T/9342', MU topdrive and ream Fl 9342'T19385', continue trip in hole Fl 9385'T/10,800' 10,800', continue trip in hole T/1154T on elevators. 21:30 22:00 0.5 Wash&Ream Wash and ream F/1154T T/11775',96 skslmin,282 gpm, 1350 spp, 50 rpm,6.1 k torq, plu 190k,s/o 157k. 22:00 0:00 2.0 Circ&Cord Pump hi vise sweep and circulate out,30%increase in cuttings©bottoms up,flow check well,well flowin 0:00 1:30 1.5 Could not straight pull on elevators coming off bottom, backream out of hole F/11,775'17 11,458',stk/min 92 (drl)Trips 190/240k,s/o 157k,torque 6.1k. 1:30 2:30 1.0 Circ&Cond At 11,458', pumped 84 bbl hi vis pill, (76 vis). 2:30 4:00 1.5 (drl)Trips Continue tripping out Fl 11,458'Fl 9102' pulling on elevators. No issue at all pulling BHA into casing window 4:00 4:30 0.5 Well Control (At 9102', flow check well-well flowing et 2.3 bph.Stage thread protectors and prep to LD DP. 4:30 6:00 1.5 (drl)Trips Lay down 51 jts CDS-40 4 1/2"drill pipe from 9102'to 7529'. Hauled 0 bbls of cuttings to KGF Total hauled=562.5 bbls Hauled 250 bbls of class II junk fluid to KGF Total hauled=5913 bbls Thanks again Guy! Please let me know if this clarifies thing or if you need more information. Monty M Myers 3 Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) [ nailto:guy.schwartz@alaska.gov] Sent: Monday, August 25, 2014 2:03 PM To: Monty Myers Subject: SCU 31-04 (214-090) Monty, I need some clarification on what is going on with these wells when the water flow zone is encountered. In this case the well is sidetracked (9300 ft TVD) but I was under the impression it was below the high pressure water zone. I don't see any mention of this in the drilling hazard summary in the PTD application. In this case is the water zone above the 7 5/8" window and channeling down? If so, was a CBL run on the 7 5/8"to verify isolation? Cmt Sqz options? In looking at the drilling summary,there is no mention of the witnessed BOP test done on the Aug 15`h. (Inspector John Crisp)was on site. He mentioned in his report that the well was flowing 5-9 BPH during the test(water flow) . Later in the reports on Aug 16th there are mentions of"27%flow out"... can you clarify what that means? Also,there are numerous statements on Aug 17th that the well was flow checked but no remarks following such as "Static or flowing" . 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). 4 Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, August 25, 2014 2:56 PM To: Schwartz, Guy L(DOA) Subject: RE:SCU 31-04 (214-090) Hey Guy, We have seen this on almost every well we have sidetracked now. We plan to kick off below the high pressure water zone so we don't have to deal with it. On some wells, like SCU 31-04, we saw it immediately. On others it takes a few hundred feet to see it. We do have CBL's that we are going off of and the plan is to kick off in pipe where there is "good" cement. We have found that it doesn't necessarily matter.The water must be channeling down the annulus and into the wellbore through the window. I haven't listed the water zone as a hazard because we know that the water is there, and we always treat the first encounter of the water flow as if it could potentially have gas or be gas. We have gotten better at predicting the mud weight to "kill" the flow with ECD and only see it during connections. We haven't planned any squeeze work because there would be nothing to squeeze. As I mentioned we are using CBL's to help select our KOP. However, some of the CBL's are old ones from the original wells. The drilling summary must have missed the BOP test witness with John crisp? We have it in our drilling report. TIME LOG ELAPSED ACTIVITY COMMENTSFROM TO TIME 6:00 9:30 3.5Clear and clean rig floor, RU test manifold and pump, flush BOP stack, pull wear ring, install test plug, purgc (drl)Misc line and choke manifold. Install test joint and shell test stack. IAOGCC Rep John Crisp on location to witness BOP test.Released sample catchers.Delivered samples to 9:30 17:30 8.0 Tstg BOP/WH/Perform bi-weekly BOPE test at 250/3500 psi(250/2500 on annular)at 10 minute intervals. Had pass fail or CMV#9. Functioned HCR and re-tested ok. Attempted to replace gate seals in CMV#9 then changed out valve completely.Shell tested CMV and flang tested CMV#9 ok.Total Safety tested gas detection equip. SLB loaded silo with 430 sx(90 bbls)of cement and spotted batch mixer. Koomey test: System PSI-3100,, 200 psi Attained-20 sec, Full PSI Attained-90 sec. Gained 76 bbls at surface,over 12 hours from annulus. Rig crew installed wear ring during CMV#9 test a sub in prep to RIH. 17:30 18:00 0.5 Rig Service Serviced rig and topdrive for trip in hole. 18:00 18:30 0.5 (drl)Misc Rig down testing equipment and blow down choke. The flow out that you are reading is talking about partial returns. We are pumping at drilling rates, but only get back 27% of what we are pumping. This well acted very weird, because we had a water flow and also loss circulation. And then the well would give back some fluid. It was the strangest acting well I have ever encountered. On the 17th we were performing some short trips to clean up the well bore for our liner run and we had spotted some weighted pills to control the flow. On my report I have static or flow associated with all the times we stopped to check? Can you be more specific on this piece? 1 Hilcorp Energy Company DAILY DRILLING REPORT REPORT NO. LEASE WELL NO. COUNTY/PARISH bVELL STATE 35 FEDA028997 31-04 2F SCU 31-04(ST SCU 22- AK RIG AFE NO. AFE BUDGET DAILY COST CDC RIG F Saxon 169 1411838D 3332500 411611111.1119 111111111b1 907-fl ACTIVITY TYPE: DRLG Drilling RD Rig C DEPTH:MD/TVD PROGRESS/HRS PROP.TD LASrSNOETEST PPG DAYS SINCE SPUD AFE DAYS FIELD SUPERVISOR 11936 7/20/2014 29 34 R Pederson/J Greco ACTIVITY SUMMARY AT: 06:00 HRS SURVEY: MD ANGLE AZIMUTH TVD SECTION N/S LD CDS-40 DP at 7529'. TIME LOG ELAPSED ACTIVRY COMMENTS FROM TO TIME 6:00 7:00 1.0 Circ&Cond Cont circulating at 9115'(just above casing window)with cleanout assembly,at 247 gpm-854 psi. BGG we units.Well flows at 8 bph. 7:00 11:00 4.0 Wash&Ream Single in hole 4 joints with no problem exiting window. RIH from derrick, at 9613'had tight hole, MU topdrive down to 9633'.At more tight holes issues at 9830'and 9899'. At 10,320'MU topdrive and washed ream remaining stands to bottom at 11,775'as hole got sticky.While w; 10,320'we had a max of 1440 units gas to surface. 13:30 15:00 1.5 Circ&Cond Pumped 20 bbl hi-vis sweep as we washed last single to bottom at 284 gpm-1397 psi,90 rpm-8081 to 831-i BGG at 180 units. Had 200%increase in cuttings with sweep to surface consisting of sand, fine coal and pea sized coal. BGG dropped to 32 units. Reloeased the two S Peak hands build containment and spot frac tank. 15:00 18:00 3.0 (drl)Trips POOH from 11,775'having to rotate and pump out of hole to 11,030'.Stopping rotation or pump we immediat 11,030'we could pull on elevators at 200K up weight. At 10,505'we stopped to check for flow and had no flow.Cont POOH on elevators to 9116'(Just above 7' tight hole at 9332'.Checked for flow again and had no flow. 18:00 19:30 1.5 Rig Service Crew change, PJSM, slip and cut 150'of drill line with well on trip tank. Service rig. 19:30 21:30 2.0 (drl)Trips Trip in hole F/9115'T/9342', MU topdrive and ream F/9342'T/9385', continue trip in hole Fl 9385'T/10,800' 10,800',continue trip in hole T!11547'on elevators. 21:30 22:00 0.5 Wash&Ream Wash and ream F/11547'Ti 11775',96 sks/min,282 gpm, 1350 spp,50 rpm,6.1 k torq, p/u 190k,s/o 157k. 22:00 0:00 2.0 Circ&Cond Pump hi visc sweep and circulate out,30%increase in cuttings©bottoms up,flow check well,well flowin 0:00 1:30 1.5 (drl)Trips Could not straight pull on elevators coming off bottom, backream out of hole Fl 11,775.T/11,458',stk/min 92 1901240k, s/o 157k,torque 6.1k. 1:30 2:30 1.0 Circ&Cond At 11,458',pumped 84 bbl hi vis pill, (76 vis). 2:30 4:00 1.5 (drl)Trips Continue tripping out F/11,458'F/9102' pulling on elevators. No issue at all pulling BHA into casing window 4:00 4:30 0.5 Well Control (At 9102',flow check well-well flowing(1 2.3 bph.Stage thread protectors and prep to LD DP. 4:30 6:00 1.5 (drl)Trips Lay down 51 its CDS-40 4 1/2"drill pipe from 9102'to 7529'. Hauled 0 bbls of cuttings to KGF Total hauled=562.5 bbls Hauled 250 bbls of class II junk fluid to KGF Total hauled=5913 bbls Thanks again Guy! Please let me know if this clarifies thing or if you need more information. Monty M Myers 2 Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) fmailtoguy.schwartz@alaska.gov] Sent: Monday, August 25, 2014 2:03 PM To: Monty Myers Subject: SCU 31-04 (214-090) Monty, I need some clarification on what is going on with these wells when the water flow zone is encountered. In this case the well is sidetracked (9300 ft TVD) but I was under the impression it was below the high pressure water zone. I don't see any mention of this in the drilling hazard summary in the PTD application. In this case is the water zone above the 7 5/8" window and channeling down? If so, was a CBL run on the 7 5/8"to verify isolation? Cmt Sqz options? In looking at the drilling summary,there is no mention of the witnessed BOP test done on the Aug 15`h. (Inspector John Crisp) was on site. He mentioned in his report that the well was flowing 5-9 BPH during the test (water flow) . Later in the reports on Aug 16th there are mentions of"27%flow out"... can you clarify what that means? Also,there are numerous statements on Aug 17th that the well was flow checked but no remarks following such as"Static or flowing" . 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(Guv.schwartzg)alaska.gov). 3 $ Regg, (DOA) James B ( ) From: Crisp, John H (DOA) Sent: Monday, August 25, 2014 7:54 AM 6(,,('( OLA To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay (Li`l'ikre" C, Subject: Weekly Report and Changeout notes 08/14/2014 Mr. Regg requested I witness BOP test Saxon 169 on SCU 31-04. Contacts and timing with Hilcorp Rep. Rance Pederson. 08/15/2014 Early morning travel to Hilcorps Swanson River 31-04 for witness of their two week BOP test. They were still rigging up test equipment when I arrived and that was enough to make me happy happy. Did a little walk thru and verified annulus valve was open. This was required due to BOP test and the well was flowing 5 BPH prior to starting BOP test. I then realized I needed a little schooling on just what we were doing allowing the well to flow with the production hole drilled and ready to case. The history of the well was explained to me by Mr. Pederson. They had lost a 1.2 million BHA (with nukes) on a prior attempt to drill production hole. The production hole was a taker and some sort of water flow formation was a giver. When they were stuck and attempting to back off earlier they said the well was flowing 15 BPH semi fresh water. I asked what the shut in pressure was and they did not know because they didn't shut the well in. My understanding was this was the third well that was side . -1 that had water flow from .-.'i. " . "i. as soon as they cut a window. They did perform a successful FIT after drilling 20' of new hole out of the casing. The Rig Manager seemed very concerned with allowing this water flow to occur while drilling and while testing BOP's. I asked the Hilcorp WSL what amount of flow increase would trigger shutting in the well. This could not be answered because there was no amount of flow that they would shut the well in.The flow increased from 5 BPH to 9 BPH during our BOP test. This is getting more and more difficult for me to un-learn basic concepts of well control, casing design and remedial cementing for well control. Mr. happy face turned into Mr. sad face. One failure, choke manifold valve had to be replaced. 08/18/2014 Anchorage Office turn in timesheets and TA for Cl. Go to work on the North Slope. 08/19/2014 Picked up our Senior Petroleum Engineer Victoria Ferguson at the airport about 0930. Little snafu with badging but nothing serious. Lunch, smoked turkey sandwiches with green salad. Doyon 25 WSL and Toolpusher showed us around and explained Rig Operation and Well control equipment. Back home for really nice steaks prepared by Mr. Bob Noble. 08/20/2014 Victoria and I traveled to MPU for MITT and MITIA on F-13. Pad of safety valves on K Pad. Brian Bixby explained the testing procedure. Traveled to KRU to have a little lunch at KCC and have a look at CDR2. They were P/U BHA to RIH and Jim Newell gave Victoria a great tour. Back to Camp. Chicken and bell pepper shish kabobs with corn on the cob and cole slaw. 08/21/2014 Victoria had questions about certain well plans submitted by BPX and CPAI, Jeff, Victoria and I sat around for a while and discussed drilling and workovers and we explained as much as possible to Victoria from Field Inspectors perspective about any question Victoria had. Victoria and I drove out east a little bit and looked at G&I on DS 6. We drove around and looked at a few big ass old school wellheads on that side of the Field. Lunch at MCC. Rig walk thru on Parker 272 on PBU B Pad.Thanks Ryan Caidenhead. We drove over to PBU G-07 to watch Jeff Jones witness SVS test on G-07. Back to Camp. Prime Rib, roasted potatoes and green beans cooked to perfection. 4 Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Daily Operations: Wednesday,August 13, 2014 Drilling 6 3/4" producion hole f/8010'to 8145'. WOB 5K,SPP 3000, GPM 315,TQ 8100, RPM 70-100, PU 195K,SO 125K, Rot 150K, MW 10.1,Vis 64. No Losses to well bore. Drilling 6 3/4" producion hole f/8145'to 8440'WOB 5K, SPP 3000, GPM 315, TQ 8100, RPM 70-100, PU 195K,SO 125K, Rot 150K, MW 10.3,Vis 78. Increase MW due to increasing background gas. Drilling 6 3/4" producion hole f/8440'to 8653' WOB 5K, SPP 3000, GPM 315,TQ 7500, RPM 70-100, PU 205K,SO 120K, Rot 150K, MW 10.3,Vis 78. Continue having trouble sliding. Reduced inc T/7.14. Service rig. Drilling 6 3/4" producion hole f/8653'to 8668'WOB 5K,SPP 3000, GPM 315,TQ 7500, RPM 70-100, PU 205K,SO 120K, Rot 150K, MW 10.3, Vis 78. Thursday,August 14, 2014 Drilling 6 3/4" producion hole f/8668'to 9022' MD. Observed 2797 units trip gas w/ 1990 units background. WOB 5K, SPP 3000, GPM 315,TQ 7500, RPM 70-100, PU 205K, SO 120K, Rot 150K. Weight up MW F/10.3-T/ 11.0 MW. Circulate and reciprocate pipe @ 9022' MD. Pump @ 2-3 bbls/min, 705 psi, 17%flow out. Gas went from 1998 units to 700 units background gas. Drilling 6 3/4" producion hole f/9022'to 9522' MD. Continue wt up F/11.0-T/ 11.6 in.2 ppg increments. WOB 5K,SPP 3330,GPM 305,TQ 9500, RPM 75, PU 205K,SO 120K, Rot 150. 185 units bgg.Circulate and condition mud while reciprocating pipe @ 9522' -9460' MD. Pump @ 306 gpm, 3270 psi, 60 rpm, 8.4k tq off. Increase MW F/11.6-T/ 11.8 ppg. Observed 55 units max @ btms up after leaving pumps down for 5 min then circulating btms up. Background gas subsided to 33 units. Monitor well (static). 225k up, 165k rot, 145k dn.TOH F/9522'-T/7474' MD. Observed slight overpull when coming out of slips first 500', but no indicators of tight hole,just light differential sticking(20-40k). Friday,August 15, 2014 Cont TOH F/7474'-T/6495' MD with no issues. Hole in good condition. CBU from 6494'just under the 7 5/8" casing shoe with 0 units gas. Flow Check well.Well static. Slip and cut 73' Drill line. Service Rig,Check Crown Saver, Recalibrate Rig Smart System.TIH from 6483'to 9494'with no issues.Wash to TD from 9494'to 9522'. Encounter 2250 units trip gas. Note: 23'fill on btm. Hole fill took 4 bbls over calculated. Circulate out trip gas. Send 25 bbls Hi vis sweep(75%increase). Continue to drill 6 3/4" Production hole F/9522'-T/10032' MD. Pump @ 294 gpm, 3100 psi on, 204 psi diff,28%flow out, 75 rpm, 11.2k tq on. 40 units bgg. Iry Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 _ 50-133-10106-01 199-083 Saturday, August 16, 2014 Drill 6 3/4" Production hole F/ 10032'-T/ 10310',AROP 46 FPH. Pump @ 294 gpm, 3150 psi on, 350 psi diff, 28%flow out, 75 rpm, 11.2k tq on.40 units bgg. Pump Sweep with 75% increase at shakers. Drill 6 3/4" Production hole F/ 10310'-T/10580', AROP 45 FPH. Pump @ 294 gpm, 3350 psi on, 250 psi diff, 28%flow out, 75 rpm, 11.8k tq on. 65 units bgg. Drill 6 3/4" Production hole F/10580'-T/ 10638' MD,AROP 58 FPH. Pump @ 292 gpm,2340 psi on, 250 psi diff, 27%flow out, 75 rpm, 11.9k tq on. 41 units bgg. CBU while reciprocating pipe @ 10638' MD. Pump @ 292 gpm, 2956 psi, 27%flow out, 60 rpm, 10.1k tq, circulated a total of 328 bbls, peak gas @ 75 w/40 bgg. Flow check(static). Wiper trip F/ 10638'-T/ 10322' MD. 250k up, 175k dn, 205k rot, 12.6k tq (wts/tq taken with pumps off). Observed slight differential sticking when pulling out of slips(40-50k over). Used rotary to break sticking initially then straight pull on elevators each stand. 1 bbl/hr losses observed throughout day.TIH w/8 singles off catwalk then out of Derrick F/10322' -T/ 10608' MD. Wash down F/10608'-T/10638. No obstructions observed. RT took proper displacement. Observed 327 units gas at btms up. Drill 6 3/4" Production hole F/ 10638'-T/10885' MD,AROP 31 FPH. Pump @ 292 gpm, 2340 psi on, 250 psi diff, 27%flow out, 75 rpm, 11.9k tq on.41 units bgg. Note: Function test BOPE @ 22:00 hrs Sunday,August 17, 2014 Drill 6 3/4" Production hole F/10885'-T/ 10895' MD and TD of Production section. Pump @ 292 gpm, 2340 psi on, 250 psi diff, 27%flow out, 75 rpm, 11.9k tq on.41 units bgg. CBU from 10895'with 60 units max gas. Continue circulate shakers clean.TOH f/10895'to 8400'. Encountering Differential sticking coming out of slips. Had to rotate off wall every stand to 8500'. Once free of wall we were able to straight pull with no issues. Flow check well. CBU from 8400'with 92 units gas @ BUS. Flow Check Well.TIH on elevators from 8400'to 10770'. Wash to TD from 10770'to 10895'. CBU from 10895'with 1692 units gas. Pump flagged sweep to surface with sweep back on time and 75%cuttings increase @ shakers. Pump and spot 50 bbls LCM pill @ 75 ppb/5% lube in annulus from 6756'to 8585'w/DP in hole,8183'to 9381'w/out pipe in hole. Flow check well. Well static.TOH from 10895'to 10298' having to rotate off wall due to Differential sticking coming out of slips. Differential sticking gradually diminishing. Continue to TOH on elevators from 10298'to 6488' (just outside 7 5/8" shoe @ 6483'). CBU @ 6488' MD. Pump @ 284 gpm, 2392 psi, 25%flow out. Observed 48 units max gas @ btms up. Monitor well (static). Pump 20 bbl slug(2#over). Dropped drill pipe wiper(Mud Dog).TOH F/6488'-T/2361' laying down drill pipe. Monday,August 18, 2014 Continue to POOH laying down 4" drill pipe from 2361'to 1600' Retrieve Mud Dog Pipe Wiper.TIH with remaining pipe in derrick to 6183'. CBU to clear 1st slug from annulus. Pump slug and Drop Mud Dog Pipe Wiper. POOH Laying down Drill pipe from 6183'to HWDP. Monitor Well (static). Lay down HWDP,Jars,Sperry Tools. PJSM prior to removing sources (secure same), Drain Mtr and B/O bit. Bit grade 1,1,ER,S,X,I,NO,TD. Clean and clear rig floor. Bring jewelry to rig floor for 5" casing run. Remove wear bushing and dummy run 5" hanger- 19.35' RKB. R/U weatherford CRT. R/U control panel, bring svc loop to floor and hang in derrick, R/U and tail CRT to floor, M/U to top drive, Install spiders and elevators. Adjust Top Drive tq 11,400 ft/lbs. Run 5" casing as per detail. Bakerlok shoe track. Check floats(good), Pump through shoe track-clear. Continue running 5"T/458' MD. Losses to wellbore around .75 bbls/hr I _ Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Tuesday,August 19, 2014 Pick up and RIH with 5", 18#, L-80 Casing from 458'to the 7 5/8" Casing Shoe @ 6483. Losses @.75 bph. UP 120k, DN 90k. Circulate casing volume x 1.5 @ 288 gpm, 1170 psi. 609 units of B/U Gas. Continue to RIH with 5" Production Casing from 6483'. Begin seeing differential sticking starting @ 8800'. 5k-10k down wt initially to break free once out of the slips and increasing to 60k by 10,850'. Fill pipe every joint with CRT while slacking off. Losses diminished to<.25 bph while in open hole. Break circulation on Jt#270 @ 1.5 bpm. Increase rate slowly to 3 bpm. Work pipe slowly while bringing up pump rate. Establish rotation @ 45 RPM,8800-10,000 tq. Wash and ream from 10850'. Cleaned out 8'of Fill from 10883'and then tagged TD 4' high @ 10891' (Casing measurements)Circulate and condition dropping YP from 27 to 21. 2068 units of Gas at B/U. Rig up Baker Cementing lines.Stop rotation and shut down pump. Release CRT, make up Baker Plug Drop Head and Cementing/Circulating lines. Resume circulating with Rig pump. Rig up drop plug head and hard lines.Continue to circulate hole through bypass with rig pumps. PJSM w/Baker Hughes Cementers. Perform cmt job as follows: Drop btm plug, pump 5 bbls FW, load top plug and test lines to 560/5130 psi. Packing on "B" pump failed (isolate pump from job). PT good. Open to well and batch spacer. Pump 13 ppg spacer(2 ppb Icm) @ 4.1 bpm,w/1090 psi ICP (pumped 43.7 bbls spacer). Batch cement and pump. Pump 15.7 ppg class"G" cement @ 4 bpm (pumped 145 bbls cement). Drop top plug,wash up to slop tank and displace with 6% KCL(Filtered to 3 NTU's). Bumped plug @ 193 bbls. FCP 3180 psi. Psi up 3550 hold for 5 min then bleed off (floats held, bleed back 2.25 bbl. Cmt in place @ 02:55 hrs. Lost 19 bbls to wellbore during cementing operations. Maintain good returns during cement job from start to finish. Note: Lost 1 hr due to plugged transfer line. Pressure up on casing to 3600 psi and hold for 30 min. Chart and record same. Observed no psi drop (test good). Bleed back 2.25 bbls.WOC, rig down cementers, and start nippling down low psi side of stack(flowline,etc.). MT pits and clean. Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Daily Operations: Wednesday,July 23,2014 Drill F/10366'to 10520'while weighting up to 10.7 ppg.Well flowing at 22 bph during connections Circulate a hi/vis sweep around while camp generator is serviced, Pason Down Drill F/10520'to10616'while weighting up to 10.9 ppg.well still flowing at 22 bph. Drill F/10,616'to 10925'with 10.9 ppg mud. No flow while pumping, 15 bbls/hr during connections.ADT 7.29 hr,ART 7.29. hr,AST 0 hrs CBU, biuld 11.3 baracarb pill and pump 36 bbls.flow check well,well flowing @ 10 BPH. Trip out of hole F/10925'T/9143',flow check well every 10 stds, ( @ 10297'flowing 8.5 bph, @ 9689'flowing 7.5 bph, @ 9179' flowing 7.0 bph Trip in hole F/9143' back to bottom @10925'. Drilling assembly went to bottom without any issues. Hole in good shape Pump sweep and circulate out,914 units gas @ bottoms up and dumped 35 bbls of water cut mud Rotate and slide F/10925'T/11204,wob 5k, rpm 39,spp on bot 2450,spp off 2200,gpm 260,trq on 8k,trq off 6k, p/u 185k,s/o 140, rt wt 168k well bore influx= 125 bbls in last 24 hrs.Well bore is 2' low and 3' left of plan Hauled 130 bbls cutting,Cumulative bbls cutting hauled to KGF=350 bbls, Hauled 0 bbls class II fluids,cumulative class II fluids hauled to KGF/G&I=490 bbls Thursday,July 24, 2014 Drilled from 11204'to 11358' pumping 260 gpm rotating 60 to 105 rpm.Torque is ranging from 6800 to 12000 ft/lbs depending on rotary speed. Drilling the Hemlock formation Drill F/11358'to 11458'attempting different parameters for ROP. Drill F/11458'T/11550',wob 5-7k, rpm 90,spp on bttm 2250,spp off 2050,gpm 257,trq on bttm 6/9k,trq off 6.5k, p/u 198k,s/o 155k, rt wt 170k Drill F/11550 T/11731',wob 5/7k, rpm 90,spp on bttm2250,spp off 2100,gpm 257,trq on bttm 8/9k,trq off 6.5k, p/u 198k,s/o 150k, rt wt 168k Service Rig and Topdrive well bore influx= 15 bbls in last 24 hrs,cumulative influx= 281 bbs Well bore is 8' high and 14' left of plan, 16'center/center Hauled 70 bbls cutting, Cumulative bbls cutting hauled to KGF=420 bbls, Hauled 0 bbls class II fluids,cumulative class II fluids hauled to KGF/G&I=490 bbls Friday,July 25,2014 Drill from 11,731'to 11792'pumping 250 gpm rotating at 105 rpm.Torque average is 10k ft/lbs,spiking up to 14k. Hole not flowing while pumping, 15 bbls per hr on connections.. Continue drilling F/11792'to 11930'the ROP was up and down through the day,average ROP for the day is 21 ft/hr drilling the Hemlock formation. Due to the angle in the well drag has increased Drilling F/11930'to 11967' Pu Wt-200k, So Wt-150k, RotaryWt-165k, pumping 250 gpm,2300 psi,5k wt and torque @ 9k. Lost all returns at 19:10 hrs at 11967'Jump 40ppg LCM pill, @ 11930' Pulled 2 stds, Pump 2nd-40 ppg LCM pill @ 11787' Pull 4 stds and pump 3rd-LCM pill @ 50 PPG @ 11413', no returns, unable to pull on elevators F/11967 T/11,200' Trip out of hole T/9109', double displacment every 5 stands, no retuns,add 10bbls mud to annulas every 1/2 hr- Lost total of 909 bbls to well Build mud volume w/50 ppb back ground LCM Last Survey: 11877.76 MD, 67.36 inc, 19.32 azm.Well bore is 14'high and 17' left of plan Hauled 0 bbls cutting,Cumulative bbls cutting hauled to KGF=420 bbls, Hauled 155 bbls class II fluids,cumulative class II fluids hauled to KGF/G&I=645 bbls Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Saturday,July 26, 2014 Mixing new mud with 50 ppb baracarb, check fluid level with Echo meter, pump 5 bbls down backside every 30 min. Trip in F/9125'to 11864',the assembly started taking weight. Pick up and make up the top drive break circulation.At 64 bbls away we got returns to the pits.Attempt to work the drillstring down. Drill string taking weight,working the string up, pulling tight plus had a full stand with no room to move. Drill string hung up,circulate and work tight hole.We could not get the drilling (\ jars to fire.Jars are 538' above the bit putting them @ 11,330' Continue working with stuck pipe,while waiting for pollard V wire line& Baker fishing tool personnel,&tools Make up free point tools,strap and tally fishing tools, losining 32 bbls fluid toSL� Cs— well bore while pumping @ 133 gpm,well flowing @ 80 BPH with pumps off, 668 units gas, discuss with Drilling Engineer, ` dicission made to spot 10 PPG weighted pill to slow influx, build 50 bbl weighted pill pump and Spot 40 bbls of 10 ppg pill @ 9143',well flowing @ 50 bph,well bore flow decreased T/10 BPH after 1 hr Rig up wire line, rotating head and free point ---2 tools and RIH with tools to free point pipe. Losses in 24 hrs=846'/1/ Total losses are 1843 bbls Hauled 0 bbls cutting, Cumulative bbls cutting hauled to KGF=420 bbls, Hauled 0 bbls class II fluids,cumulative class II fluids hauled to KGF/G&I= 645 bbls Sunday,July 27, 2014 Pull out with wire line and freepoint due to not getting down past 9995'. Need more weight for the angle in the well bore Take out the weight bars and install weighted roller boogies Run in with the wire line and freepoint with weighted roller boogies. Could not get past 10022' Pull out with wire line and free point tools. Rig down side entry sub and swivel and put left hand torque in the drill string for the back-off Make up side entry sub and swivel for Back-off Run in with a back off charge on wireline and back off drill pipe at 9958' Pull out with wire line and lay down back off shot and tools. P/U= 180k, S/O= 160k, Breake circulation and circulate a complete round,at bottoms up 132 bbls of water cut mud was dumped plus 539 units of gas. Circulate and condition mud, mw @ 9.1 ppg, increase mw T/9.5 ppg,flow check well,well taking 15 bbl/hr Trip out of hole F/9958 T/9143,flow check well flow,well taking 11bbl/hr continue TOHleft 32 jts drill pipe and bha in hole i) L Load fishing tools on cat walk,get strap, ID'S,OD'S,fish necks,start picking up fishing tools Cumulative losses down hole= 2143 bbls,cumulative influx down hole=279 bbl Hauled 0 bbls cutting,Cumulative bbls cutting hauled to KGF=420 bbls, Hauled 140 bbls class II fluids,cumulative class II fluids hauled to KGF/G&I =785 bbls />M Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Monday,July 28, 2014 Continue picking up the fishing BHA and running in the hole Trip in with drill pipe F/218'to 9081'.tripping in the hole to 7474' the hole fill was 4 bbls over calculated, F/7474'to 9081'the hole started losing at 15 bbls/hr Cut and slip 130'of drilling line, inspect linkage and brakes. Circulate bottoms up at the window,at bottoms up the mud had a few light spots of of 9.3 ppg with no gas show. Check Parameters before tripping in-Up=162, Dn=155, Rt=160,Tq @ 30 rpm=6000 ft/lbs Service the rig, topdive and crown.Check things out for jarring Pre job safety meeting with the rig crew, Baker fishing hand, mud man,Sperry DD and MWD before tripping into open hole Trip in F/9081'to 9520'with no hole issues and slight losses CBU, P/U 162k,S/O 158k, RT WT 160k,spp 350,gpm 133 @ 46 stk/min,trq 6k TIH F/9520 T/9952' break circulation and circulate., p/u 162k,s/o 158k, rt wt 160, rt trq 6k @ 30 rpm Wash down and screw into fish@ 9952',spp 350,gpm133,jar down on fish, p/u 200k,s/o 60k,w/5/10ft/lbs trq, discuss with Drilling Engineer Work with freeing stuck pipe,jar up @ 280/325k, s/o to 40/60 k,with 5/10k trque,alternate between jaring up and jaring down, increasing pump rate F/46 to 88 stk/min,work pipe with out pumps, attempts failed, discussed with Drilling engineer,call out Pollard wire line for another Free Point Inspect derrick, brake linkage,draw works brakes, crown sheaves, &top drive Continue working with stuck pipe while waiting on Pollard wire line Hauled 0 bbls cutting, Cumulative bbls cutting hauled to KGF=420 bbls, Hauled 0 bbls class II fluids,cumulative class II fluids hauled to KGF/G&I =785 bbls Daily Losses down hole=480 bbls Cumulative losses down hole=2481 bbls, cumulative influx down hole=279 bbl Tuesday,July 29,2014 Jaring on fish pulling 280k to 325k to fire the jars,ciculating at 134 gpm 731 psi and 9.3 ppg mud.The oil jars started getting weak and finally quit. Pre Job with wire line crew, rig crew, Baker hand and truck drivers. Rig up wire line equipment, make up side entry sub and swivel. Run in with wire line and free point to 9900',free point was hanging up in drill pipe.After several attempts with no success pull 220k on drillstring and slacking off to 180k working wire line. Working the drill string the free point fell through the tight spot falling to 11280'.Working the drillstring up to 240k down to 180k and free point comming up from 11280'. Free pointing on the way up some stretch started at 10765'.A tool joint at 10704'and free pipe at 10697'. Pull wire line to surface and lay down free point. Break out the side entry sub and swivel. make up the topdrive and put left hand torque in the drillstring for the backoff. Make up entry sub and swivel Hold Pre Job Safety meeting with Pollard wire line, Baker and the rig crew. RIH w/wireline charge and fire charge on depth at 10,704', POOH and L/D wireline and remove swivel.Well was flowing at 43 BPH We were seeing the bumper sub travel up at 190k and dn at 160k,we worked 2 more turns to left(6 turns total)w/10k torque in string worked torque down hole w/up wt=210, dn wt=140 At this time we backed off in the(drill collars)on a 3 1/2 IF connection, (up wt= 140k)screwed back into 3 1/2 IF connection and torqued to 12.5k working torque down hole Added 2 turns left w/4k tq and worked tq down hole,added 3 more turns left w/9k tq and worked tq down hole,added 1 more turn left w/10k tq and worked tq down hole,added 1 more turn w/10.5k tq we backed off in the drill collars again(up wt=140k),screwed back into 3 1/2 IF connection and torqued to 15k working torque down hole,then we put 4 turns left w/10k tq and worked it down hole R/U wire line and RIH w/wireline charge and fire charge on depth again at 10,704', POOH and L/D wireline and remove swivel. Well flowing at 40 BPH added 1 more turns left w/9k tq and worked tq down hole, added 1 more turn left w/10k tq and worked tq down hole, backed off on 3 1/2 if again, M/U connection to 15k again and worked torque in string till we got another string shot from pollard shop.Well flowing at 47 BPH R/U wire line and RIH w/wireline charge and fire charge on depth at 10,420',POOH and currently LID wireline and remove swivel. TOTAL fluid(water)gained in last 24 hrs=907 bbls Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Daily Operations: Wednesday,July 30, 2014 Hold 10,000 lbs torque in string with topdrive and work string F/140k to 210k. working torque down hole. Cap the side entry sub and break circulation and pump 134 gpm, caught pressure @ 34 bbls away. lnital pressure@ 400 psi, pressure slowly built to 850 psi. 300 bbls away pressure @ 1280 psi. Put 4 turns to left in string and work torque down hole, PJSM with Baker hand, wireline personnel and rig crew. R/U wireline and RIH to 10,015' and fire string shot, POOH and LID wireline and swivel. Work string while holding 10k left hand torque fr: 130k down and 225k up. Work string while holding 10k left hand torque, while pumping at 134 gpm( no circulation ), pipe backed off at 3 1/21F connection again( 140k weight ),Well was flowing at 30% and tapered to 8%flow. Screwed back into 3 1/2 IF connection and torqued to 18k, worked torque down hole, Work 4 1/2 wraps left hand torque down hole w/ 10k torque. PJSM, R/U wireline and swivel, RIH to 10,015' and shot 600 grain string shot, POOH and R/D wireline and swivel. Work pipe while holding 5 turns left hand torque= 12k, pipe came unscrewed at 3 1/2 IF connection again( 140k weight ). While discusing forward plan with town and fishing hands we filled hole with 44 bbls of water, did flow check, well was flowing at 6BPH. Screwed back into 3 1/2 IF connection and torqued to 18k, worked torque downhole, Then we worked 4 1/2 left hand turns(11.5k torque) down hole. PJSM, R/U wireline and swivel, RIH to 9,983' and shot 640 grain string shot, POOH and R/D wireline and swivel. Work pipe while holding 6 turns left hand torque= 12k, pipe came unscrewed at 3 1/2 IF connection again( 140k weight ). R/D top sheave and side entry sub assembly. Grease drawworks, blocks and top drive. Filled hole with 12 bbls water, flow check was 3.5 BPH. POOH from estimated depth of +/- 9,750'- 9192 • Thursday,July 31, 2014 Trip Out F/9500' to 3975', well flowing 6 bbls/hr, hole fill took half of calcuated fill_Safety meeting on cut and slip: Change out drilling line spool, slip new line on blocks and crown sheaves. Un spool old line and spool on new line. Install weight indicator and crown-o-matic. Service rig and topdrive. Continue tripping out F/3975' to surface, missing 1952' of CDS40 drillpipe_and the fishingBHA. New TOF @ +/- 7781'. PJSM, Pull ware bushing and install test plug. Rig the trip tank up to annulas to monitor well through out the BOP test. Meeting with both crews for wildlife management from Hilcorp HSE. PJSM, with drilling crew on high pressure testing. Fill stack, choke manifold and test equipment, All tests 5 minutes low and high, Test annular to 250/2500 psi and test all other BOP components 250/3500 psi. RID test equipment pull test plug and install wear ring. M/U new fishing BHA, CDS-40 screw in sub, Bumper sub,jars, XO, 12 jts HWDP, XO intensifiers, XO, total BHA length= 403.44'. Torqued all 3 1/2 IF connections to 13k. Check and compare torque readings on tongs vs iron roughneck vs top drive in all three mode settings. Witness waived by Jim Regg with AOGCC at 3:15 pm on 7/30/14 Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Friday, August 01, 2014 Finish picking up the fishing BHA.Trip in from 403 to 5620' checking each break for loose connections. Two bad joints on stand #36. Lay down both joints. Stand#111 under torqued. Check and adjust torque output on topdrive. Well Flowing 8.5 bbls/hr. Trip in F/5620'to 7777',Tagging fish. Up= 143 Dn=142 Rot= 142. Circulate above the fish at 134 gpm, 140 psi, screw into the top of the fish w/15k torque. Pressure increased to 1100 psi, drillstring plugged. Working the string picking up to 190k and Dn 120k. Rig up the wire line, M/u side entry sub, xo and swivel. Run in with wire line. M/U and RIH w/ 1.75" drift to 10,800', POOH and L/D drift assembly. M/U and RIH with free point assembly, couldn't get pass 9,765'(WLM), POOH w/wireline and inspect bow springs(OK). RIH with free point assembly again, couldn't get pass 9,765'(WLM), adjust weight pulled on string to 220k, pumped on hole(still couldn't get passed 9,765',POOH w/wireline and remove 1 weight bar. RIH with free point assembly again, couldn't get pass 9,901'(WLM), worked it several times with various perameters, POOH and L/D free point assembly. Talked with town about not being able to get down with freepoint tools, Decision was made to sever pipe 3 joints higher than planned depth of 10,688', NEW severing depth is 10,585'. PJSM, M/U and RIH with 1.75" severing tool to 10,800', pull up hole and get on firing depth of 10,585'. Attempt to sever pipe at 10,585', blew a fuse in wireline unit, C/O fuse and tried again with no success, POOH to figure out whats wrong( operator thinks theres a short in severing tool assembly ) Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Saturday, August 02, 2014 PJSM W/Wire line crew, pull shot through the table. Shot is gone, tool fired. Lay down swevel and side entry sub. M/U topdrive and work pipe, break circulation. Took 50 bbls before pressure increased, building to 1050 psi. Pumps down and pressure blead down to 0 pressure. Work pipe F/ 140k pulling up to 290k. Attempt to regain MWD pulse pumping 185 stks. Pressure increased to 2000 psi, pumps down. Continue working pipe. Pumps down, Make up side entry sub and swivel, make up free point, stab it in the drill string and run in to 9810'. Work pipe attempting to get down through the tight spot at 9810' with no success. Pull wire line out of pipe. and change tools to a 1.75" gauge ring. Run in with gauge ring to 10550' and pull back to surface and lay down the gauge ring. Pick up perf gun assm. and RIH w/wire line and perforate pipe fr: 10,553'- 10,556', no change in flow, POOH and LID perf gun assm. work pipe fr 120k to fire jars at 210k and straight pull to 300k, took 38 bbls to fill pipe then pump pressure went to 1800 psi, shut pump off, did this around ten times. M/U perf gun assm. and RIH w/wire line and perforate pipe fr: 10,198'-10,201', did not fire, POOH and L/D perf gun assm. Pump up to 4000 psi several times to attempt to rupture circ sub at 9,929', we worked pipe setting jars off at 210k and straight pull to 300k to try help rupture disc, pumped a total of 120 bbls away. Pick up perf gun assm. and RIH w/wire line and perforate pipe fr: 9,645'- 9,648', flow instantly went fr 4 to 12 percent when we fired guns, POOH and LID perf gun assm. Pump at 135 gpm/ 500 psi with decent return flow to confirm free pipe at 9,645'. M/U and RIH w/ 1.75" severing tool to firing depth of 9,645'( we pulled on drill string 210k while severing= 30k over estimated string weight ), POOH and L/D severing tool, remove swivel assm. pulled up on string and fired jars at 210k/ straight pull to 300k 5 times, put 10k right hand torque in string and pulled 300k 3 times( pipe became free ). Worked stand out of hole fr: 9,645'-9,582', we had packing off with pumps and very eratic torque w/20- 50k over pulls, up= 160k/ rot= 155k/couldn't go back down for a down weight. Got pipe rotating w/5k torque and pumps up to 300 gpm w/930 psi, Decided to sit still while pumping 30 bbls of mud as a sweep to try help clean up hole(100% increase in cuttings/coal-p gravel-clay). Well flowing at 30 to 40 bbls/hr. Pump 50 bbls of 11.0 ppg mud with 50 ppb LCM. After spotting the weighted LCM pill the flow slowed to 22 bbls/hr Sunday, August 03, 2014 Trip out F/9582' to 9075' up in the window, once the hole was circulated clean the drill string pulled up through the open hole section with no issue. Rig down wire line equipment, lay down side entry sub and swivel. Mix and pump a 50 bbl pill at 11.5 ppg with 50 ppb LCM. Spot at the window, Flow check at 23 bbls/hr. Trip out F/9075'to 2185' on a single to change the breaks. On stand #98 found connection that had been backed out, threads dry. Lay down ACC jar and stand back HWDP. Lay dowd remainder of the fishing BHA. Lay Down fish, 60 jts of CDS40 drill pipe and severed joint, Count all drill pipe on location. M/U BHA#6- 6.125" bit, bit sub, stab, 2 flex collars, xo, xo, 6 jts hwdp, xo,jars, xo, 9 jts hwdp total BHA length= 564.68'. RIH w/drill pipe out of derrick fr: 564'- 6,270' filled pipe every 1,500'. P/U singles off the deck fr: 6,270'- 7,270'. RIH w/drill pipe out of derrick fr: 7,270'-9120' filled pipe @ 7,700". Break circulation and circulation. Rigging to weight up to 10.5 ppg in the the pits. Hauled 25 bbls of cuttings to KGF total hauled=445 bbls Hauled 650 bbls of class II junk fluid to KGF total hauled= 2795 bbls II Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Monday, August 04, 2014 Circulate water at 9130' while weighting up the pit system from 9.5 ppg to 10.5 ppg (245 gpm @ 520 psi). Displace the well bore with 10.5 ppg KCL mud. Circulate the mud all the way around, In and Out. Shut down and flow check, well is flowing at 0 V bbls/hr. Attempt to trip in without pumping, Bottom of the window is at 9157', the drilistring started taking weight @ 9198'. Wash and ream F 9198'to 9630' with 240 gpm 70 rpm on rotary and 4600ft/lbs torque. Circulate a sweep around cleaning the hole.the sweep at the shakers increased the cuttings by 50%. Check flow at 4.5 bbls/hr. circulate at 235 gpm w/700 psi while weighting up mud system to 10.5 ppg. pump and spot on bottom a 50 bbl 12.5 ppg/50 ppb LCM pill. flow check( 7 BPH ), POOH on elevators fr: 9,630'-9,120'w/no issues, flow check( 3 bph ), continue POOH fr: 9,120'- BHA. flow check( 4 bph ), L/D all HWDP and remainder of BHA. R/U casing handling equipment, Lay out and strap 2 3/8" tubing. inspect and grease up drawworks,top drive and blocks. Start P/U 2 3/8" tubing for cement stinger,5 joints picked up= 155'. Hauled 30 bbls of cuttings to KGF Total hauled=465 bbls Hauled 460 bbls of class II junk fluid to KGF Total hauled= 3255 bbls Tuesday, August 05, 2014 _Trip in with the cement stinger and 4 1/2" drill pipe to 9134'. MU topdrive. CBU lx at 238 gpm-810 psi. Dumped 33 bbls_ --.� water at bottoms up. Cont trip in hole from 9134'to 9633', washing each stand down. Had no issue exiting window a 9157' or at previous tight spots at 9530' and 9545'.At 9633', up wt 143K, dwn wt 141K while pumping. Circ surface to surfa 240 gpm-944 psi until good 10.5 ppg in/out. Performed flow check. Well flowing at 8 bph. Notified Drilling Engineer. Decision made to increase mud weight 2/10's. Cont circ at 240 gpm-998 psi and increase MW from 10.5 ppg to 10.7 ppg in/out. Initial flow check is 4 bph. After 15 minutes flow at 3.8 bph. R/U cement lines and manifold on rig floor. PJSM w/all parties, circulate at 240 gpm/975 psi ,fill cement lines,test lines 250/3000 psi. Circulate and maintain 10.7 ppg in/out while C,_ batching up cement. Pump 17 bbls mud push then 26 bbls of 17 ppg cement w/ 1ppb cemnet d displaced with 105 bbls of 10.7ppg mud, ESTIMATED TOC= 8,954'CEMENT IN PLACE AT MIDNIGHT POOH fr 9,630'-8,700' slowly up wt= 143k( had no overpulls ) had +-2 BPH flow on trip. Insert drill pipe wiper ball, Pump 1 1/2 STS volumes to clean well( dumped 55 bbls of mud at BU, it had traces of cement and mudpush ) ROT at 8 rpm's and pumped at 300 gpm/ 1300 psi.Cut and slip 121' of drilling line. Well flowing at 2 BPH. POOH fr: 8,700'-4,000'. Well flowing at+-2 BPH. Hauled 325 bbls of class II junk fluid to KGF total hauled= 3580 bbls Hauled 75 bbls of class II junk cement contaminated fluid also Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Daily Operations: Wednesday, August 06, 2014 Cont POOH from 4000' to 2 3/8" tubing at 644'. No flow at 4000' from well. EHS field coordinator John Coston did walkthrough of rig. Found rig to be in good shape and everyone to be in compliance. RU Weatherford tongs and handling equipment, cont POOH LD 20 joints 2 3/8" tubing. RD Weatherford equipment. Well flowing at 2 bph. Close blinds, clean and clear rig floor. Stage cleanout BHA componants. Well built to 210 psi in 1 hour with blinds closed. MU 6 1/8 rotary cleanout assembly as follows: 6 1/8" mill tooth jetted at 3x18's, bit sub with float, stabilizer, 2 flex DC's, XO, PU singled in w/12 jnts HWDP, XO,jars, PU singled in 11 jnts HWDP. Cont. RIH, checking connections and filling pipe every 2500'. Replaced two bad joints during trip. RIH from 809' to 8,700'. Wash down fr: 8,700'- 9,300' at 146 gpm w/335 psi ( no cement ). CBU at 280 gpm/900 psi( started dumping watered back mud w/ hi ph/13.4, dumped a total of 155 bbls ). POOH fr: 9,300'- 9,112' w/ NO issues. Talked to town engineer and decision was made to weight up mud system to 10.9+and build more volume,,after pits are 10.9+ we rolled the hole over to weight it up to 10.9+ before going in open hole. RIH fr: 9,112'-9,300' and wash down to 9,375' w/ 146 gpm= 350 psi, at 9,375' increased pump to 300 gpm/1250 psi, rot at 60 rpms w/4500 torque fr:9,375'-9,438'. Hit a bridge at 9,331', Cement started firming at 9,435'= 200 FPH( got real good at 9,438',it was 80 FPH w/ 10k wob and 60 -� rpm's ) WELL STILL FLOWING AT 2 BPH. Circulate to clean up wellbore while increasing MW to 11 ppg( at BU we dumped 129 bbls of cement contaminated mud/ PH= 13.6 ). flow check(1.5 BPH), POOH fr: 9,438'- 9,100' with no open hole issues. flow 1 check( 1.5 BPH ), pump 20 bbls of 13.5 mw dry job. Hauled 180 bbls of class II junk fluid to KGF total hauled= 3760 bbls Thursday, August 07, 2014 POOH with 6 1/8" drillout assembly from 9100'. Racked back HWDP and flex DC's. LD bit sub and rollercone bit. Re-run bit graded at 1-1-WT-A-E-I-BHA (same as dull grade in). MU 6 1/8" HDBS PDC bit jetted with 5 x 12's, 6.0 stage motor with 1.5 deg bend, stabilizer, float sub, DM collar, slim phase 4 collar, TM HOC tool and uploaded MWD. MU flex DC's,. Shallow test MWD (good), cont RIH with HWDP,jars and 4 1/2" CDS-40 DP from derrick, filling pipe every 2500'. Well flowing at 1.5 bph. RIH to 4,970'. RIH P/U singles fr: 4,970'- 6,650'. Continue RIH out of derrick fr: 6,650'- 9,060'. wash down fr: 9,060'- 9,408', reaming as needed( ledges@ 9,210, 9,285, 9,334, 9,370 ) pump at 256 gpm= 1500 psi. Trench hole fr: 9.408'-9.438' (W 85-90.7 degrees right. Time drill fr: 9438'-9450', started time drilling to ease off plug at 9438/with 85R TF 2 ft/hr. Increased wob at A \ 9443/to 5k. Now rop is 6 ft/hr. Samples are showing less cement at 80%. 256 gpm= 1560 psi up/ rot/do = 170/ 158/ 160. Hauled 480 bbls of class II junk fluid to KGF Total hauled=4240 bbls 1�u*d . Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Friday,August 08, 2014 Cont time drilling 6 1/8" hole from 9450' to 9482'. Sliding: 5K wob, 256 gpm-1562 psi, 47 to 177 psi diff, 8 to 18 ft/hr, MW 10.9/46 vis, H2O on at 5 bph. At 9466' samples are at 30 to 40%cement. Survey indicates we are not getting any inclination build. Notify Drilling Engineer, decision made to trench to low side. Orient low side and trench from 9450' through 9482'. Cont time drilling from 9482'to 9488' at 1 ft/hr at 160 degrees right. Did increase ROP to 2 ft/hr for an hour then reduced to 1 ft/hr. 0 to 1K wob, 300 gpm-1952 psi, 15 to 75 psi diff. Cont.time drilling fr: 9,488'-9494' at 1 FPH at 135 degrees right. 300 gpm= 1922 psi wob= 1k 50-60%cement in cuttings at 9,488' 30-40%cement in cuttings at 9,490' 25%cement in cuttings at 9,492'. Cont. time drilling fr: 9494'- 9,499' at 2 FPH at 135 degrees right. 260 gpm= 1572 psi wob= 1k 20%cement in cuttings at 9,498'. Cont. time drilling fr: 9,499'-9,500' at 3 FPH at 135 degrees right. 260 gpm= 1575 psi wob= 1k 30%cement in cuttings at 9,500'. Cont. time drilling fr: 9,500'- 9503' at 1 FPH at 160 degrees right. 260 gpm= 1590 psi wob= 1k. Hauled 3 bbls of cuttings to KGF total hauled=468 bbls Hauled 480 bbls of class II junk fluid to KGF total hauled=4720 bbls Saturday, August 09, 2014 Cont time drilling 6 1/8" hole at 1 ft/hr from 9503'to 9505'. Cement content dropped from 80%to 40%. Pumped hi-vis sweep around with very little increase in cuttings. Cont sliding f/9505' to 9518'. 5K wob, 302 gpm-2094 psi,48 to 100 psi diff, cement content droped from 40%to 10%and getting more ashy sand. Cuttings bacame 100%formation, diff psi. increased to 100 psi, 1.5 deg difference in Inclination at this depth vs other leg, notified Drilling Manager and Engineer of parameters. Decision made to drill ahead as planned. Cont drilling 6 1/8" hole from 9518' to 9721', Sliding: 5K wob, 302 gpm-2138 psi, 57 to 155 psi diff, 22 to 49 ft/hr ROP. Rotating: 6K wob, 302 gpm-2200 psi, 44 rpm-5500 ft/lbs on bott torque,. 48 to 56 ft/hr ROP,flow check at 9620' at 2.5 bph, MW 10.9/vis 47, running centrifuge at 13:30, water on at 5 bph. Continue Drilling fr: 9,721'-9,785', slid 100%of stand 260 GPM= 1760 PSI up/ rot/dn = 176/ 170/ 163 on connection the well was flowing at 9_ BPH. Continue Drilling fr: 9,785'-9,867', slid 100%of stand 260 GPM= 1835 PSI. up/rot/dn = 176/ 170/ 163. Grease drawworks, top drive and blocks, C/O crown saver actuator, tested same. Continue Drilling fr: 9,867'-9,870' 260 GPM= 1835 PSI. up/rot/dn = 176/ 170/ 163.Total slide time = 37.92 hrs Total rotating time =.74 hrs. We are 30'to the right of the plug back well. 7.8' low to plan and 3.06' left of plan. Hauled 11 bbls of cuttings to KGF. total hauled =479 bbls Hauled 430 bbls of class II junk fluid to KGF.Total hauled = 5150 bbls I Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date • SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Sunday,August 10, 2014 Cont drilling 6 1/8" hole from 9870' to 9918'. Sliding: 3K wob, 277 gpm-1984 psi, 62 psi diff, 23 ft/hr ROP. Flow check 7 bph. Pull off bottom, pump hi-vis sweep around at 277 gpm-1985 psi while rotating and reciprocating at 80 rpm-8022 ft/lbs off bott torque. Had 25% increase in cuttings with sweep to surface. Cont slide drilling f/9918' to 9991'. Sliding:3K wob, 276 gpm- 2035 psi, 66 to 82 psi diff, 8 to 22 ft/hr ROP. Rotating: 3K wob, 277 gpm-1956 psi, 50 rpm-8583 ft/lbs on bott torque, 28 ft/hr ROP. Continue sliding in build section fr: 9,991'- 10,010'4k WOB 277 GPM= 1840 PSI. Continue sliding in build section fr: 10,010'- 10,026'4k WOB 250 GPM= 1650 PSI up/ rot/dn = 184/ 165/ 177 MW = 10.9/VIS=45. Continue sliding in build section fr: 10,026'- 10,060' 4k WOB 278 GPM= 1920 PSI up/ rot/dn = 184/ 164/ 177 MW= 10.9/VIS=46. TOTAL SLIDE TIME = 54.45 HRS TOTAL ROT TIME =.93 HRS. We are 12.07 ft low to plan, 1.28 ft left and. 53.49 ft from plug back well. . Hauled 9 bbls of cuttings to KGF Total hauled =488 bbls Hauled 70 bbls of class II junk fluid to KGF Total hauled = 5220 bbls Monday, August 11, 2014 Cont drilling 6 1/8" hole f/10,060' to 10,434'. Sliding: 3K wob, 282 gpm-2149 psi, 65 psi diff, 20 ft/hr ROP. Rotating: 6K wob, 282 gpm-2141 psi, 60 rpm-9400 ft/lbs on bott torque,. 23 to 91 ft/hr ROP, 6 bph flow check, 10.9 ppg/46 vis, water on at 2.5 bph, no centrifuge, BGG at 4 units. Up wt 191K, dwn wt 166K, rot wt 180K.ADT: 10.55 hrs,ART: 5.7 hrs,AST: 4.85 hrs. Cont drilling fr: 10,434'- 10,613'. 6k wob w/60 rpm's= 10600 torque 80 gpm's= 2160 psi MW = 10.9/VIS=47 up/rot/dn = 192/ 180/ 165 FLOW CHECK= 9 BPH. Pump Hi-Vis w/nut plug sweep around to clean up wellbore at 280 gpm w/2060 psi Rotating and recipricating fr: 10,551'- 10,601', (top 50' of stand) 50% increase in cuttings on sweep. POOH fr: 10,613'-9,115', tight spots of 20-30k over were 10390, 9851, 9840, 9812, 9805, able to pump through without issues, at 9230' we had to rotate and pump for 5' ( acted like chunky cement here. Cut and slip 95' of drill line, ( well was flowing at 9 bph ). Change oil in allison transmission, grease crown, drawworks, top drive and blocks. We are 4.72' low of plan, 8.11' right of plan and 86.6' right from the plugged back well (fish).TOTAL SLIDE TIME = 61.06 HRS TOTAL ROTATE TIME= 10.17 HRS. Hauled 22 bbls of cuttings to KGF Total hauled= 510 bbls Hauled 70 bbls of class II junk fluid to KGF Total hauled= 5220 bbls Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 214-090 7/16/14 50-133-10106-01 199-083 Tuesday, August 12, 2014 RIH f/9119' (inside 7 5/8" casing) with no issue exiting window at 9157'.,Singled in hole 4 jnts then trip f/derrick. At 9358' encountered tight hole. MU topdrive and washed through tight spot lx. Worked through 9358' with no rotation or pump 2 x with no problem, cont RIH. At 10,081' another tight spot. MU topdrive and washed down to 10,115'. Worked string through tight spot 2x with no pump. or rotation with no problem. Cont RIH washing last stnd down to 10,613' (bottom) w/3' of fill. Pump 20 bbl hi-vis sweep and work string at 284 gpm-2204 psi, 80 rpm-11,200 ft/lbs off bott torque. At bottoms up we dumped 17 bbls watered back mud (9.8ppg) and had max 1037 units gas. Cont drilling 6 1/8" hole f/10,613'to 10,946'. Rotating: 5K wob, 285 gpm-2188 psi, 80 rpm-11,080 ft/lbs on bott torque, 50 to 55 ft/hr ROP (holding that ROP for mud loggers), had 25% increase. in cuttings (fine sand) on shakers with sweep to surface. ADT: 7.04 hrs, ART: 6.71 hrs,AST:.33 hrs. Up wt 223K, dwn wt 172K, rot wt 192K. BGG 18 units. Cont drilling 6 1/8" hole f/10,946'T/11020', SPM 90, gpm 282, spp 2184, rpm 40, diff 147, p/u rotating 180k, p/u with out rt 195/210k, s/o 160. Work with tight hole @ 11020'. Pump 15 bbl hi- vis sweep and work string. Continue drilling F/11,020'T/11,172', 282 gpm-2260 psi,4 to 8 K wob, 40 rpm-11,748 ft/lbs on bott torque, up wt 225K, dwn wt 165K, rot wt 175K. ADT: 9.95 hrs, ART: 8.84 hrs,AST: 1.11 hrs. Last survey at 11,072' and we are 0.87' low and 8.12' right of the line. Hauled 15 bbls of cuttings to KGF Total hauled= 525 bbls Hauled 210 bbls of class II junk fluid to KGF Total hauled= 5430 bbls Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 50- 214-090 199-083 7/16/14 133-10106-01 Daily Operations: Wednesday,August 13, 2014 Pump 20 bbl hi-vis sweep around to clean hole for short trip. 282 gpm-2151 psi, 65 rpm-10,913 ft/lbs off bott torque. No increase in cuttings at shakers. Pull up hole from 11,170'to 10,552' on elevators with no problem. Up wt 210K. RIH to 11,170' on elevators with no problem,washed last stand down. Down wt 168K. No fill on bottom. Pump 20 bbl hi-vis sweep and work string while filling pipe. Had max of 1047 units gas just prior to bottoms up.Gas dropped to 180 units in 10 minutes. Resume drilling 6 1/8" hole f/11,172'to 11,358'. Rotating:6 to 8K wob, 284 gpm-2519 psi,45 rpm-10,598 to 12,000 ft/lbs on bott torque,5 to 45 ft/hr ROP. BGG at 37 units. ADT:8.67 hrs,ART:8.67 hrs,AST:0 hrs. Up wt 190K,dwn wt 160K,rot wt 172K. Cont drilling 6 1/8" hole f/11,358'to 11,510', 96 stks/min, 282 gpm, 2432 spp,40 rpm,trq on 8k,trq off 6k, p/u 210k,s/o 160k, rt wt 180k. Cont drilling 6 1/8" hole f/11,510'T/11668',gpm 282,spp 2398,trq on 9ki,trq off 6k, p/u 210k, s/o 160k, rt wt 170k, rpm 48,wob 8k, 12 bbls gain last 24 hrs. ADT: 10.20 hrs,ART: 10.20 hrs,AST:0 hrs. Last survey at 11,568' md,61.23 deg Inc, 21.24 deg Azi, 10,533'tvd.That puts us 15.3' low and 1.16' left of the line. Hauled 17 bbls of cuttings to KGF Total hauled= 542 bbls Hauled 58 bbls of class II junk fluid to KGF Total hauled=5468 bbls Thursday,August 14,2014 Drill 6 1/8" hole f/11,668'to 11,700'. Rotating:4K wob,283 gpm-2375 psi,45 rpm-8500 ft/lbs on bott torque, BGG 121 units, 38%flow.At 11,700' notified geologist and stop drilling. Pump 15 bbl hi-vis sweep and rot/reciprocate drill string at 82 gpm- 2174 psi,50 rpm-8400 ft/lbs off bott torque and wait on definate TD depth. Pump sweep out bit. Cont drill to TD at 11,775', pumping 11.1 ppg in/10.9+ppg out. 5K wob,283 gpm-2214 psi, 50 rpm-8450 ft/lbs on bott torque, BGG 21 units,36%flow. CBU at 282 gpm-2189 psi, 60 rpm-7900 ft/lbs off bott torque. POOH from 11,775'. Had to pump and rotate from 11,775' up to 11,478', up wt 220K. From 11,478' had to pump and rotate to break loose then cont pull with no rotation to 11,250'. From 11,250' had to pump and rotate to break loose,then cont pull with no pump no rotation up to 10,969'. From 10,969'we could pull on elevators with no problems.Cont POOH from 10,969'to 9120' on elevators. Had some over pull pulling flex collars through window. MU topdrive and rotated 10 rpm and idle pump and pulled flex collars through window. Held BOP and fire drills.Service rig and topdrive. Checked oils in mud pumps,draw-works motor and gen sets. Initial flow rate at 5 bph. Final flow rate at 6 bph. RIH from 9120'to 9623',then after discussion with Drilling Engineer, pull back into 7 5/8"casing for trip out of hole. Did have to rotate one stand at 10 rpm to get flex DC in window. At 9120', monitor well while building 35 bbl 13 ppg pill to spot in casing as a weighted cap.Well flowing at 4 bph. Pump and spot 35 bbls weighted cap in casing, leaving 18 bbls in drill string. POOH from 9120', rack back HWDP and jars. Down load mwd, break off bit, lay down motor and MWD tools. Bit graded at 2-5-BT-G-X-I-WT-TD and had no plugged jets. Hauled 10 bbls of cuttings to KGF Total hauled=552 bbls Hauled 65 bbls of class II junk fluid to KGF Total hauled=5533 bbls IIHilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 50- 214-090 199-083 7/16/14 133-10106-01 Friday,August 15, 2014 Clear and clean rig floor, RU test manifold and pump,flush BOP stack, pull wear ring, install test plug, purge air from stack, choke line and choke manifold. Install test joint and shell test stack. AOGCC Rep John Crisp on location to witness BOP test. Released sample catchers. Delivered samples to FedEx for shipping. Perform bi-weekly BOPE test at 250/3500 psi (250/2500 (5� !r on annular) at 10 minute intervals. Had pass fail on choke side HCR and CMV#9. Functioned HCR and re tested ok. Attempted ` f > to replace gate seals in CMV#9 then changed out valve completely.Shell tested CMV and flanges that were broke,then tested CMV#9 ok.Total Safety tested gas detection equip. SLB loaded silo with 430 sx(90 bbls)of cement and spotted batch mixer. Koomey test:System PSI-3100,After Closure PSI-1400, 200 psi Attained-20 sec, Full PSI Attained-90 sec. Gained 76 bbls at surface,over 12 hours from annulus. Rig crew installed wear ring during CMV#9 test and staged bit and float sub in prep to RIH. Serviced rig and topdrive for trip in hole. Rig down testing equipment and blow down choke. Make up cleanout BHA as follows:Smith 6 1/8" mill tooth jetted w/3 x 18's, bit sub w/float,stabilizer, 2 x flex DC's, HWDP,jars, HWDP. Trip in hole F/871'T/7693'filling pipe every 2500'. At 7693' circulate out water from well bore,dumped 210 bbls water, circulate until 11.0 ppg coming out,flow check well,well flowing @ 10.2 bph. Max 339 units gas./Cont trip in hole F/7693'T/9115'. Circula - • at 247 gpm-610 psi. Returns went from 11.0 ppg to water in a matter of minutes. Dumped 70 bbls water. Hadtemax of 840 units ga•� Keeping returns w/MW at 10.8 ppg. Hauled 10.5 bbls of cuttings to KGF Total hauled=562.5 bbls Hal -.11 130 bbls of class II junk fluid to KGF Total hauled=5663 bbls Saturday,August 16, 2014 I Cont circulating at 9115' (just above casing window)with cleanout assembly,at 247 gpm-854 psi. BGG went from 52 units to 18 units.Well flows at 8 bph. Single in hole 4 joints with no problem exiting window. RIH from derrick, at 9613' had tight hole, MU topdrive and washed/reamed down to 9633'.At more tight holes issues at 9830'and 9899'. At 10,320' MU topdrive and washed ream remaining stands to bottom at 11,775' as hole got sticky.While washing/reaming at 10,320'we had a max of 1440 units gas to surface. Pumped 20 bbl hi-vis sweep as we washed last single to bottom at 284 gpm-1397 psi,90 rpm-8081 to 8317 ft/lbs ofFott torque. BGG at 180 units. Had 200%increase in cuttings with sweep to surface consisting of sand,fine coal and pea sized coal. BGG dropped to 32 units. Reloeased the two Sperry MWD Reps. Had Peak hands build containment and spot frac tank. POOH from 11,775' having to rotate and pump out of hole to 11,030'.Stopping rotation or pump we immediately started sticking.At 11,030'we could pull on elevators at 200K up weight. At 10,505'we stopped to check for flow and had no flow.Cont POOH on elevators to 9116' (Just above 7 5/8" window). Had slight tight hole at 9332'.Checked for flow again and had no flow. Crew change, PJSM,slip and cut 150'of drill line with well on trip tank.Service rig. Trip in hole F/9115' T/9342', MU topdrive and ream F/9342'T/9385',continue trip in hole F/9385'T/10,800'on elevators,fill pipe at 10,800', continue trip in hole T/11547'on elevators. Wash and ream F/11547'T/11775',96 sks/min,282 gpm, 1350 spp,50 rpm,6.1 k torq, p/u 190k,s/o 157k. Pump hi visc sweep and circulate out,30%increase in cuttings @ bottoms up,flow check well,well flowing 3.5 bph. Could not straight pull on elevators coming off bottom, backream out of hole F/11,775'T/11,458',stk/min I 92,ssp1060, rpm 50, p/u 190/240k,s/o 157k,torque 6.1k. At 11,458', pumped 84 bbl hi vis pill, (76 vis). Continue tripping out F/11,458' F/9102' pulling on elevators. No issue at all pulling BHA into casing window at 9143'. At 9102',flow check well- well flowing @ 2.3 bph.Stage thread protectors and prep to LD DP. Lay down 51 jts CDS-40 4 1/2"drill pipe from 9102'to 7529'. Hauled 0 bbls of cuttings to KGF Total hauled=562.5 bbls Hauled 250 bbls of class II junk fluid to KGF Total hauled= 5913 bbls Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04 (SCU 22-04 ST) 50-133-10106-02-00 50- 214-090 199-083 7/16/14 133-10106-01 Sunday,August 17, 2014 Crew change, PJSM,flow check-no flow. Cont POOH LD CDS-40 DP from 7529'to 6506". Monitor well 30 minutes. No initial flow but built to 3.5 bbls in 30 minutes. Pumped and spotted 30 bbl, 13 ppg pill in the 7 5/8" casing. Dropped 2" drift on wire and cont POOH racking back 4 1/2" DP, 9 stnds HWDP, LD remaining HWDP and flex DC's. Mill Tooth bit graded at 1/1. Hole took 3.9 bbls over calculated. Clean and clear rig floor, pull the 6 3/8" wear ring (liner hanger OD 6.45"), RU fill up hose, CO handling equipment, stage centralizers and XO's.Clear catwalk of drilling tools, stage shoe track and liner on racks, prep to PU shoe track. Found Weatherford elevators have 4" catch plate, not 4 1/2". Weatherford called for delivery of 4 1/2" catch plate,field hand drove to highway to meet delivery. Rig performed 30 minute rig service. Monitor well at 4 BPH flow. PJSM, make up shoe track, check float equipment (good) pick up and run 67 joints of 4.5", L-80, 12.6 ppf, DWC/C-HT liner. Rig down casing running equipment. Make up 7.625 X 5.5 Baker HRD-E ZXPN liner top packer with Llex-Lock liner hanger, mix pal-mix and pack running tool, allow 30 minutes to set up. M/U stand of HWDP and circulate casing volume, 56 stk/min 650 spp. Continue running in hole with liner on drill pipe F/2788'T/5402',top filling on the fly,then MU topdrive and filling pipe every 10 stands. Monday,August 18, 2014 Cont RIH with 4 1/2" liner from 5402'to 9093'.Top filling pipe on the fly,the filling pipe completly every 10 stands. At 9093' (just above window) MU topdrive and circ at 141 gpm-368 psi. at bottoms up we dumped 145 bbls watered back mud. Lowest MW 9.1 ppg. Had max of 697 units gas. Circ to 10.9 ppg out. MU Baker cement head and torqued up XO's and pups. Staged same on catwalk. Flow at 5 bph. MU topdrive and with pump rate at 141 gpm, up wt 150K, dwn wt 145K, rot wt 142K. At 10 rpm =3048 ft/lbs, 20 rpm =3100 ft/lbs, 30 rpm =3205 ft/lbs torque. Cont to run in open hole from 9093'to 10,463'. No issue exiting window. Cont filling on the fly and top filling every 10 stands completely. At 10,463' MU topdrive and CBU at 142 gpm- 547 psi, up wt 165K, dwn wt 155K. Had max of 1750 units gas at bottoms up. Dumped 120 bbls water and light mud, 9.1 ppg. Circ to 10.9 ppg out. Cont RIH f/10,463'to 11,760', MU topdrive on last stand and washed to bottom. PU cement head, drop carbide bomb, MU cement head and topdrive.Tagged bottom at 11,778'. PU 2'off bottom and circ at 147 gpm-833 to 943 psi. up wt 180K, dwn wt 155K. Had to keep string moving so as not to excede 1500 psi.The moment we stop working string psi increases. Flow at 27%. No losses, no gain while pumping. BGG at 22 units. Built 20 bbls 12 ppg MudPush in pill pit. Calculated surf to surf strokes 6287, actual 6450 strokes. RU hardline to rig floor and cement head, PJSM with all personnel. SLB pumped 5 bbls water to fill lines, PT hardlines at 1000 and 6000 psi. SLB began to batch up cement. Rig pumped 15 bbls 12 ppg Ci MudPush II at 3 bpm-788 psi. Lined up on SLB. SLB pumped 85 bbls (353 sx) 15.3 ppg cement at 4.8 bpm-987 to 400 psi with full returns, reciprocated string non-stop w/10?stroke. Up wt 200K. Dropped dart,and SLB displaced with 8.5 ppg produce water at 4 to 4.5 bpm-75 psi ICP. Cont to reciprocate string to reduce chance of packoff under hanger, up wt 200K.Slowed to 2 bpm and saw dart latch wiper plug at calculated 17.4 bbls into calculated 17.4 bbls into displacement and parked string on depth with 10 bbl to go.With pump rate at 2 bpm-2014 psi, bumped plug/landing collar with 162 bbls displaced,fcp 2400 psi, held 5000 psi (2600 over fcp)f/3 minutes. CIP at 01:40 on 8-19-14. Pumped a total of 263 bbls (Mud Push, cement and displacement)with 263 bbls returns. No losses. Floats holding. Set Flex-Lock Liner Hanger and HRD-E ZXPN liner top packer as per Baker:test liner lap TO 1000 PSI,TEST GOOD. Press up DP to 1500 psi, PU out of hanger and SLB pumped @ 8 BPM using 8.5 ppg produced water. 10 BBLS contaminated cement to surface. Lay down baker cement head, install wiper ball, rig circulated 1 1/2 dp volume. Trip out of hole with running tool, laying down drill pipe to 8569'. Hauled 0 bbls of cuttings to KGF Total hauled=562.5 bbls Hauled 265 bbls of class II junk fluid to KGF Total hauled= 6421 bbls Hilcorp Alaska LLC Weekly Drilling Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-04(SCU 22-04 ST) 50-133-10106-02-00 50- 214-090 199-083 7/16/14 133-10106-01 Tuesday,August 19, 2014 Cont POOH LD 4 1/2" CDS-40 drill pipe and Baker liner hanger running tool. Shipped out SLB cement silo and batch mixer. Break down cement head and clear rigfloor Rig up and test casing to 2500 psi for 30 min, Rig down equipment. Casing lost 150 psi in 30 min Nipple down bop's, start cleaning pits Install hanger with two way check, nipple up well head with valve Test well head @ 250/5000 F/15 min (test Good) Continue cleaning pits, pits 4,5, and 6 are clean, cleaning 1, 2, 3, hauling fluid from 7,8. Rig release @ 06:00 OF Tie e �,�. \��%%', a THE STATE A.� S�ir,�. :� a1 _ 333 West Seventh Avenue GOVERNOR SPAN PARNEL1. 0 nchorage, Alaska 99501-3572 026 Main 907 279 1433 9 Fa) 907 `.,/6 7;;/? Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-04 Sundry Number: 314-475 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, e) Daniel T. Seamount, Jr. Commissioner DATED this 20day of August, 2014. Encl. RECEIVED • STATE OF ALASKA AUG 18 2014 �IA 0-414 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0. Pull Tubing❑ Time Extension❑ Operations Shutdowl❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Initial Completion 2. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ .. 214-090 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10106-02 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)31-04 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 ' Swanson River/Hemlock • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,775' 10,636' 11,649' 10,573' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 1,413' 11-3/4" 1,413' 1,413 3,070 psi 1,510 psi Intermediate Production 9,143' 7-5/8" 9,143' 9,147 6,890 psi 4,790 psi Liner 2,826' 4-1/2" 11,773' 10,635' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(R): See Attached Schematic See Attached Schematic N/A WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A WA 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proprsed work: Detailed Operations Program n BOP Sketch n Exploratory n Stretigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 08/23/14 Oil ❑✓ Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 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 sDorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature "` / _i_._ Phone 907-777-8412 Date X /GOt{ COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\1—1 — `—� Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: k 3000 S: v..* Tc:734-- j1 l/ � / Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: Lia7 �L �` 0 , APPROVED BY jL Z 2' 1 c Approved b COMMISSIONER THE COMMISSION Date: / Submit Form and �n�gg�lo 4p (Rest; �20> Approvgd�p a IGKA Lmths from the date of approval. A chments inDuplicateLy vi /{ b d y� LJ VVV 1 \\\ rl ��7 l� ,(� (f I r, i,! • II • Well Prognosis Well: SCU 31-04 Hilcorp Alaska,LU Date:8/15/2014 Well Name: SCU 31-04 API Number: 50-133-10106-02 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: August 23r1, 2014 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 199-083 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: - 0 psi @ 10,468 TVD (Measured BHP Survey) Maximum Expected BHP: - 2,600 psi @ 10,468' TVD (Based on offset wells of Hemlock H-5) Max. Allowable Surface Pressure: - 0 psi (1,400 gaslift) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 3,715' TVD.) Brief Well Summary SCU 22-04 was drilled and completed as a gas cap blowdown well in 1999 as a sidetrack of SCU 323-04. In 2004 a coiled tubing velocity string was installed to help remove fluid from the well, but the work wasn't successful to obtain sustained flowing pressures. The coiled tubing velocity string was removed in August 2012, the lateral was attempted to be cleaned out, but the coil tubing work was unsuccessful. A new 2-3/8" gaslift completion was run inside the 4-1/2" tubing in December 2012.The well was sidetracked using the Saxon#169 drilling rig and a 4-1/2" liner was ran and cemented in mid-August 2014 and renamed SCU 31-04. The purpose of this work/sundry is to run the completion with the Moncla #401 rig.This work follows that which was approved in the Permit to Drill up to cementing the 4-1/2" liner and demobilization of the Saxon #169 Drilling Rig. WO Rig Procedure: 1. MIRU Moncla #401 WO Rig. 2. Set BPV. ND Tree. 3. NU 7-1/16" BOPE. Set BPV.Test to 250 psi Low/3,000 psi Highannular to 250 psi Low/ 1,500 psi High (hold each valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notify BLM 48 hrs in advance of BOP test. 4. Bleed any pressure off tubing. Pull BPV. 5. PU 3-3/4" mill and 4-1/2" casing scraper on 2-7/8" Tbg and XO to 3-1/2" Tbg and 7-5/8" Casing Scraper. 6. RIH to above liner top. 7. RU and pressure test liner lap to 3,000 psi for 30 min and chart. 8. RIH to tag liner top at 8,947' with 7-5/8" casing scraper. a. Setup BHA to have 4-1/2" Casing Scraper run to+/- 11,600'. 9. Circulate well clean w/3% KCI fluid (filter fluid going downhole). 10. POOH. LD 3-3/4" mill, 2-7/8"Tbg,4-1/2" Casing Scraper, 7-5/8" Casing Scraper. a. Rack back the 3-1/2"tubing. 11. MIRU E-line. 12. RIH and run cement bond log from PBTD to 8,800' MD. —>s4---4 / '4-C4C( (— Well Prognosis Well: SCU 31-04 Ililroru Ala.ka.I.I! Date:8/15/2014 13. RD E-line. 14. PU completion jewelry and hydraulic packer. 15. RIH and set packer at+/-8,913' MD. a. Leave tubing tail to land just above the liner top at 8,945' (TOL at 8,947'). 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. 16. MIRU Slickline. 17. RIH w/2.5"x20' dummy gun w/roller boggies on the tool string to PBTD. a. Maximum deviation is 66°. 18. RIH and set RHCP plug body in X-profile. 19. RIH and set RHCP ball and rod. Keep setting tools latched. 20. Pressure up to 3,500 psi and set hydraulic packer. 21. Test tubing to 3,500 psi for 30 min and chart. 22. Pull RHCP ball and rod. RD Slickline. 23. Test casing to 2,500 psi for 30 min and chart. / N I r- I''k 24. Lay down landing joint. Set BPV. ND BOPE. NU tree. Pull BPV. 25. Set TWC.Test hanger to 250/3,500 psi. Test tree to 250/5,000 psi. Pull TWC. 26. RD Moncla #401 WO Rig. 27. Turn well over to production in preparation of moving off the Moncla#401 WO Rig. 28. Replace IA x OA pressure gauge if removed (7-5/8" x 11-3/4"). Slickline Procedure: 29. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 30. RIH and pull dummy valves from each gaslift mandrel (6 mandrels). POOH. 31. RIH and pull dummy valve from the chemical injection mandrel. POOH. 32. RIH and set live valve in chemical injection mandrel. POOH. 33. RIH and set live valves in each gaslift mandrel (6 mandrels). POOH. 34. RIH and pull RHBC plug body from X-profile. POOH. 35. RIH w/2.5"x20' dummy gun and tag PBTD. POOH. E-line Procedure: 36. Rig up gaslift lines to tree. Production to gaslift off top of well to achieve desired underbalance. a. Est BHP = 2,600 psi. Est hydrostatic= 2,100 psi. (Fluid level at GLM #3 at 6,800' MD) 37. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 38. RU 2.50" 6 spf HC wireline guns (will make multiple runs, 20' guns, 6 spf shot density). 39. Bleed tubing pressure down to below 150 psi, as directed by Reservoir Engineer. 40. RIH and perforate the following intervals: 41. Hemlock H-1 from 11,115'-11,200' (85') (5 runs,total of 6 spf). 42. Hemlock H-5 from 11,430'-11,560' (130') (7 runs, total of 6 spf). 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. e. No Spacing allowance required, per CO 123B, no spacing limits in Hemlock/Tyonek G. ✓ Well Prognosis Well: SCU 31-04 !mem') tla.ka.LI Date:8/15/2014 43. RD E-line. 44. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic (7-1/16") 4. Choke Manifold 5. Wellhead Schematic SCU 31-04 Swanson Unit WeIISCURiver3104 Actual Schematic Post-Sidetrack Hilcorp Alaska,LLC Updated 8/18/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB-THF:16.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top '' q 22" Conductor Surf 28' - unknown Surf. rX 22" " 11-3/4" Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' ,, r. 7-%" 39 6.625" Surf 131' „ 7-%" 33.7 6.765" 131' 3,623' w, 1, 7-'/" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST ' 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-%" 7-%" 39 6.625" 6,552' 6,983' '+. Vr a- 7-%" DV Collar 6,983' 6,986' ' 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-%" 345 sx 8,947'EST Tubing Cplg OD I I I I I °`' EST TOC.,, 4,220' � 0 r; JEWELRY DETAIL p No. Depth ID OD Item Short RA Marker Joints @ 10,979'-10,999'MD @ 11,164'-11,174'MD @ 11,379'-11,399'MD EST TOC @ 11,519'-11,529'MD 8,947' L' TOL PERFORATION DETAIL 8,947' iL 0 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments EST TOC ' 8,993' 7-5/8" L , GLV Port Temp © 9,143' # Size Depth TCF PSC PSO PTRO Description RAMrkJt $ •` PENDING GASLIFT DESIGN RA Mrk Jt J • RA Mrk Jt ,r, t �+� i RA Mrk Jt'? it a:- 4-1/2" i, 11,773' !, {q►s TD=11,775' PBTD=11,649' MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Actual Schematic 8-18-14 Updated by STP 8/18/14 SCU 31-04 Swanson U R31 0iver4 Unit V Proposed Schematic illCompletion Proposed IHikorpAlaika,LLC Updated 8/18/14 RKB:171.1'/GL:152.5'AMSL Casing & Tubing KB—THF:16.0' Size Type Wt Grade 1 ID Top Btm Hole Cmt Cmt Top 1 I i 22" Conductor - - - Surf 28' - unknown Surf. 22" �. • 2 °'+'�� 11-'/I' Surf Csg 47 J-55 11.000" Surf 1,413' 16" 1,000 sx Surf. 28' 7-%" 39 6.625" Surf 131' 7-'/," 33.7 6.765" 131' 3,623' 3 7-%" 29.7 N-80 6.875" 3,623' 5,654' 1,000 sx 4,220'EST r .. 7-%" Prod Csg 33.7 6.765" 5,654' 6,552' 10-'/" 7-%" 39 6.625" 6,552' 6,983' = 7-'/," DV Collar 6,983' 6,986' . 11-3/4" , 4 i a 7-%" 39 N-80 6.625" 6,986' 9,143' 500 sx 8,993'EST 1,413' 4-1/2" Liner 12.6 L-80 3.958" 8,947' 11,773' 6-'4,- 345 sx 8,947'ES Tubing Cplg OD 3%" EUE 8RD 19.3 I L-80 I 2.992" I 0' I 8,945' 4.500" EST TOC 4,220' . 5 Q"; 4, , JEWELRY DETAIL 6 MD 7 '/ No. _ Depth ID OD Item `9'' 1 16' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 1 2 17' 2.992" 3.500" Pups,3-1/2"8RD 6 3 1,400' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#6 4 3,200' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#5 7 SIR p 5 5,000' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4 I 6 6,800' 2.992" 5.250" 3-1/2"5F0-1 Mandrel 8RD GLV#3 7 8,000' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2 8 8,848' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1 Orifice 9 8,896' 2.992" 5.250" Chemical Injection Mandrel 8 NB 1 1 10 - 8,913' 3.000" 5.875" Olgoonik DLH Hydraulic Packer I11 8,933' 2.813" 4.500" X-Nipple 9 12 8,945' 2.992" 1.500" WL Entry Guide U I MAIL I Short RA Marker Joints 10 = II . @ 10,979'-10,999'MD ` @ 11,164'-11,174'MD MI 11 X @ 11,379'-11,399'MD EST TOC @ 11,519'-11,529'MD 8,94712 TOL PERFORATION DETAIL 8,947' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) , SPF Ft Phase Comments IX r. 7 Proposed H-1 11,115' 11,200' 10,329' 10,365' 6 85 60 2.5"PowerJet Nova Proposed H-5 11,430' 11,560' 10,468' 10,529' 6 130 60 2.5"PowerJet Nova EST TOC yy,, 8,993' ' '41 - . . f4 7-5/8" GLV Port Temp cl 9,143' # Size Depth TCF PSC PSO PTRO Description RA Mrk Jt. • t I. PENDING GASLIFT DESIGN =7 H-1 RA Mrk Jt+ '_ re x RA Mrk Jt Y • 11-5 RA Mrk Jt 4-1/2" 1 11,773' '- ii illi TD=11,775' PBTD=11,649' MAX HOLE ANGLE=66.3°@ 10,451' SCU 31-04 Proposed Schematic 8-18-14 Undated by STP 8/18/14 . II Swank,.. River SCU 31-04 Proposed 08/18/2014 11.1..,,I. u.-1....1.1 Swanson River SCU 31-04 3 1/8 5M Tree assy 3 1/2 completion U. u. ! u. MEW Valves, Swab,WKM, '"^"' 3 1/8 5M FE, HWO (. '�C1 Valve, Wing,SSV,VG- Qty1 00e o M, 31/85MFEw/ � •• Barber operator . Valves,Wing,WKM, m .Q. or'\~� 0?:�3 / Fr :[ ic , 1 Qty 3 � Ts 0 o ^00 4O (-C^ O Valves,Master,WKM, 3 1/8 5M FE,HWO „, Qty2 a00 @qlo 0,6,0 0 r, III III . $ . $ - IN n_I -it q IiK Tbg head,Sea board-S, 1!I 1111 13 5/8 3M X 7 1/16 5M O•� o `. w/2-2 1/16 5M SSO,SP-2 i - • (• Valve,Seaboard, bottom prep, bored out for 7 1 1 c'4,�O]I� ■■ I[0`;0,�) Il-I.. 2 1/16 5M FE, HWO,Qty 2 5/8 casingLLJJ . 00 00 III 1 A Casing head,Shaffer KD, in air um 13 5/8 3M X 11 Y.SOW,w/2- Ill — 1ltl 2" LPO,7 5/8 KD slip and seal 1 ,�.€ ,, r•) unit in head lit ii ile/PA 1,l_h_• Valve,CIW-F, 2" LPO .tee V 0 ie s • `- T • t uu i ill 01 Ic' fl} IIIj ,`t li: ' 0 NOM 0C Sm S CD W''' r-) I ( , ) E Y a ..mow til N 1 (Likkip; III) ° e, ''. ...i z AM 0 n:1 Ut V ( .) * 1 urn l • j c0 O ` g 54 A ..t. V R N if o Swanson River 2014 Moncla Rig 401 al...r�� �i:�,ka.1.1.1, Knight Oil Tools BOP r � 0 0 III 1111 ill li i lil 1111 2.5 7' Shaffer 71/16 5000 lii til iii Ili iii ItT 2 3/8-31/2 variable CAMERON - - 3.68' - H Blind IMO 71/16 5000 ( ri - r i • i iii iv! Ili iii 1i1 2 1/16 10M Kill Valves 2 1/16 10M Choke Valves Manual and HCR Manual and HCR g 1 1 liI9.I1 lin I 1 fu G 1.56' � � � 11.24) Ehh150 00 � � 2-‘24,- 09D ,,`pt.oF �1%% � 1 HE STATE A1a21`a .:_i- .;. _ (..? s -_ — 333 Wept Sevenih i venue t it _, 3ovoR\\OR SEANJ�.\RNEi-'_ A�ichorage Alo ko 99501-3577 t 5 Van 907.7 9 _3P Monty M. Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-04 Sundry Number: 314-450 Dear Mr. Myers: 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, 7),Z4,11--t-- Cathy P Foerster Chair DATED this 0 day of August, 2014. Encl. RECEIVED STATE OF ALASKA JUL 3 1 20�� OSN c Ju11`l ALASKA OIL AND GAS CONSERVATION COMMISSION ,s gtQ APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril' `J , Perforate New Pool ❑ Repair Well 0 ( Change Approved Program E, Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ �y Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other: �ttJc+ . f 4 8/' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q 214-090 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive Suite 1400,Anchorage AK 99503 50-133-10106-02-00 • 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? SCU 31-04 - Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 ' Swanson River/Hemlock Oa_ • 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): 11967 10634 2010 Casing Length Size MD TVD Burst Collapse Structural Conductor 28 22" 28 28 Surface 1413 11-3/4" 1413 1413 Intermediate 9969 7-5/8" 10100 10100 Production 407 5-1/2" 10100 10100 Liner 1550 3-1/2" 10096 11474 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ t Service ❑ 14.Estimated Date for 1-Aug-14 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 2. 16.Verbal Approval: Date: '7/31/2014 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Guy Scwartz GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Monty M Myers Email mmvers(c�hilcorp.com Printed Name Monty M Myers Title Drilling Engineer Signature Phone 907.777.8431 Date 7/31/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3`4-l_ L{SO Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / Lt).tV /C•gt ) Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: IO' /10.7 7 C „i„.,,4____ APPROVED BY Approved by:0,‘6,1 COMMISSIONER THE COMMISSION Date: g _Ls---7 YlY � n �14, s:( /t4 Submit Form and Form 10-403(Revised /2012) ApprovetllatW�+ti� iSIir hs from the date of approval. Attachments in Duplicate ��v� ' ` R$DMS AUG — 5 20 • Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hil.orp Ala.la,LIA: July 31, 2014 RECEIVED Commissioner JUL 3 1 2014 Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue AOGCC Anchorage, Alaska 99501 Re: Soldotna Creek Unit 31-04 (Sidetrack of SCU 22-04). Dear Commissioner, Enclosed for review and approval is the sundry application for the SCU 31-04 Development Oil well. While drilling at a depth of 11967', loss circulation was encountered. An attempt was made to regain circulation and while proceeding to drill ahead, the drilling BHA with a nuclear source became stuck at 11860'. Several attempts have been made to free the fish since this time with no success. At present time we are backed off in the fishing assembly at approximately 9850'. The BHA that is left in the hole consists of a bit, drilling motor, MWD tools, LWD tools, drilling jars, HWDP, DP and various crossovers. Also there are 2 nuclear sources left in the hole with the LWD equipment, consisting of Cesium 137 and Americium-Beryllium. I would like to request permission to spot at minimum 125' cement above the fish, sidetrack around the fish and re-drill the interval to TD. / Drilling operations are expected to commence approximately August 3rd, 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 the approved drilling procedure and this sundry: 1. Spot cement above fish °3°'.� I c).� 2. WOC 12 hours 3. Perform clean out run to cement plug(-9725'). 4. POOH and PU directional tools. - 5. Drill 6-1/8" production hole from 9175' to 11936' MD. 6. Perform short trip and condition mud. POOH 7. LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. 8. POOH, laying down DP and liner running tools, ND BOPE 9. RDMO 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 r BHA Schematic } _,,ef_ 1 f 3 s CTN Collar I ,' IADC Rig BHA# : • Run# : 300 Drillstring : Drillstring Flex Collar Created On:Aug 01 2014 4 3 4'.ALC'Collar 4.500 0.75 HDBS MM55 (Gauge: 6.125 in) • 5.000 23.36 5"SperryDrill Lobe 6/7-6.0 stg Stabilizer (Gauge:5.875 in,Pos' 1.25 ft) 4.850 2.99 Float Sub 4 3 4' TM HO, 4.760 5.27 WBS (Gauge: 5.875 in, Pos*: 1.48 ft) 4.710 8.54 4 3/4"DM Collar 4.720 24.50 4 3/4"Slim Phase 4 Collar 4 3 4' Shm Phase 4 4.720 14.31 4 3/4"ALD Collar �.. Stabilizer (Gauge:5.630 in,Pos':3.68 ft) 4.740 11.03 4 3/4"CTN Collar 4.750 11.13 4 3/4"TM HOC 4.700 30.73 Flex Collar 5.240 2.00 X-Over 3 1/2"IF Pin x CDS-40 Box 4.500 368.67 12 jts 4-1/2" HWDP CDS-40 5.240 2.62 X-Over CDS-40 Pin x 3 1/2"IF Box 43!4"DM Collar 4.750 30.02 Weatherford DAH Jar 5.280 2.60 X-Over 3 1/2"IF Pin x CDS-40 Box 4.500 398.76 13 jts 4-1/2"HWDP CDS-40 WBS *Pos:Measured as distance from bottom of the component. Float Sub 5"SperryDrill Lobe 6/7-6.0 stg HDBS MM55 Job No: Well Name: BHA Schematic INSITE V8.0.0 Page 1 § 39.77 Notification of incidents and lost P sources; abandonment procedures for irretrievable sources. (a) The licensee shall immediately notify the appropriate NRC Regional Office by telephone and subsequently, within 30 days,by confirmation in writing,using an appropriate method listed in § 30.6(a)of this chapter, if the licensee knows or has reason to believe that a sealed source has been ruptured. The written confirmation must designate the well or other location, describe the magnitude and extent of the escape of licensed materials, assess the consequences of the rupture, and explain efforts planned or being taken to mitigate these consequences. (b) The licensee shall notify the Commission of the theft or loss of radioactive materials, radiation overexposures, excessive levels and concentrations of radiation, and certain other accidents as required by §§ 20.2201 -20.2202, § 20.2203 and § 30.50 of this chapter. (c) If a sealed source becomes lodged in a well, and when it becomes apparent that efforts to recover the sealed source will not be successful,the licensee shall-- (1)Notify the appropriate NRC Regional Office by telephone of the circumstances that resulted in the inability to retrieve the source and—Notified Michael Vasquez on 7/31 (i) Obtain NRC approval to implement abandonment procedures -Received verbal approval to abandon and sidetrack at 14:38 EST on 7/31/2014 or (ii) That the licensee implemented abandonment before receiving NRC approval because the licensee believed there was an immediate threat to public health and safety; and (2)Advise the well owner or operator, as appropriate, of the abandonment procedures under § 39.15 (a) or(c); and (3) Either ensure that abandonment procedures are implemented within 30 days after the sealed source has been classified as irretrievable or request an extension of time if unable to complete the abandonment procedures. (d) The licensee shall,within 30 days after a sealed source has been classified as irretrievable, make a report in writing to the appropriate NRC Regional Office. The licensee shall send a copy of the report to each appropriate State or Federal agency that issued permits or otherwise approved of the drilling operation. The report must contain the following information: (1) Date of occurrence; 7/31/2014 (2)A description of the irretrievable well logging source involved including the radionuclide and its quantity, chemical, and physical form; - Logging while drilling equipment consisting of a Cesium 137 nuclear source and an Americium-Beryllium nuclear source. Data sheets attached. (3) Surface location and identification of the well; - 2072' FSL, 2126' FWL, Sec 4, T7N, R9W, SM, AK, Kenai Alaska (4)Results of efforts to immobilize and seal the source in place; -Attempted to jar the assembly free from the stuck point, unable to free. Severed pipe at 964 ' Measured Depth, Spot cement above fish from 9630' to 9400'. (5)A brief description of the attempted recovery effort; -Jar on drill pipe and fish and try to pull free,no success, Back off drill pipe at 9952' and pick up new jarring fishing assembly. Screw in to fish and try to jar fish free,no success. Sever pipe at 9645'. (6) Depth of the source; - 11769' to 11794' Measured depth (10557' to 10567' Vertical depth) (7) Depth of the top of the cement plug; -9400' (8)Depth of the well; - 11967' MD (10634' TVD) (9) The immediate threat to public health and safety justification for implementing abandonment if prior NRC approval was not obtained in accordance with paragraph(c)(1)(ii)of this section; - NiA (10)Any other information, such as a warning statement, contained on the permanent identification plaque; and—N.';1 (11) State and Federal agencies receiving copy of this report. -Alaska Oil and Gas Conservation Commission(AOGCC) and Bureau of Land Management (BLM) [52 FR 8234, Mar. 17, 1987, as amended at 56 FR 64980, Dec. 13, 1991; 58 FR 67660, Dec. 22, 1993; 65 FR 20345,Apr. 17, 2000; 68 FR 58806, Oct. 10, 2003] Services' Inc, • STATE OF WISCONSIN RADIOACTIVE MATERIALS LICENSE 071-1234-01 SEALED SOURCE LEAK TEST CERTIFICATE RAM ACCESSION NO 117908 HALLIBURTON ENERGY SERVICES-Sperry LOCATION 0190-PRUDHOE BAY-AK(LWD) CONTACT PERSON Craig Zawadzski/Brian PHONE 907-659-2805 Stephens HALLIBURTON ENERGY SERVICES Sperry 2805 Spine Road DEADHORSE,AK 99734 UNITED STATES LEAK TEST ANALYSIS EQUIPMENT NO. 11509081 DEVICE/TOOL NUMBER NOT AVAILABLE MODEL# CDC CY13 MANUFACTURER NOT AVAILABLE SOURCE SERIAL NO. 59435B MANUFACTURER S/N i I ISOTOPE Cs-137 SOURCE ORIGINAL ACTIVITY 2000 mCi 74 GBq I I DATE SOURCE WIPED 13 May 2014 REASON FOR TEST PERIODIC I I ANALYSIS DATE 29 May 2014 ANALYTICAL METHOD Liquid Scintillation Counting f i GROSS SAMPLE COUNT 10 cpm INSTRUMENT Perkin Elmer Tri-Carb 3110TR 130414 BACKGROUND 21 cpm COUNTING EFFICIENCY 95% I i NET SAMPLE COUNT -10.6526 dpm MINIMUM DETECTABLE 1.15E-05 iCl ACTIVITY 0.43 Bq i I SAMPLE ANALYSIS ACTIVITY -1E-05(XI PASS/FAIL CRITERION 0.005 NCI -0 19298 Bq ! 185 Bq SOURCE PASSES TEST I I ACTION LEVEL 0.001 (CI • 37 Bq ANALYST Don Jordan NOTES: ADDITIONAL SOURCE DESCRIPTION NOT AVAILABLE • 510 County Highway V Two Rivers.W'1 54241 Voice ,-I-920-686-3889 Services,Inc. Fax -4-920-686-3899 STATE OF WISCONSIN RADIOACTIVE MATERIALS LICENSE 071-1234-01 SEALED SOURCE LEAK TEST CERTIFICATE RAM ACCESSION NO. 116829 HALLIBURTON ENERGY SERVICES-Sperry LOCATION 0190-PRUDHOE BAY-AK(LWD) CONTACT PERSON Abd-alrzak Alshanta/Egor PHONE 907-659-2805 Shibalov HALLIBURTON ENERGY SERVICES Sperry 2805 Spine Road DEADHORSE,AK 99734 UNITED STATES LEAK TEST ANALYSIS EQUIPMENT NO. 11223799 DEVICE/TOOL NUMBER NOT AVAILABLE MODEL# AMN.CY17 MANUFACTURER NOT AVAILABLE SOURCE SERIAL NO. 5905NN/5906NN MANUFACTURER S/N ISOTOPE Am-241 Be SOURCE ORIGINAL ACTIVITY 8000 mCi 296 GBq DATE SOURCE WIPED 29 Apr 2014 REASON FOR TEST PERIODIC ANALYSIS DATE 05 May 2014 ANALYTICAL METHOD Liquid Scintillation Counting GROSS SAMPLE COUNT 25 cpm INSTRUMENT Perkin Elmer Tri-Garb 3110TR 130414 BACKGROUND 24 cpm COUNTING EFFICIENCY 95% NET SAMPLE COUNT 0.978947 dpm MINIMUM DETECTABLE 1.22E-05 pCI ACTIVITY 0.45 Bq SAMPLE ANALYSIS ACTIVITY 0 pCI PASS/FAIL CRITERION 0.005 pCI 0.01754 Bq 185 Bq SOURCE PASSES TEST ACTION LEVEL 0.001 pCI 37 Bq ANALYST Don Jordan NOTES: ADDITIONAL SOURCE DESCRIPTION: NOT AVAILABLE - Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday,July 31, 2014 11:33 AM To: 'Monty Myers' Cc: Paul Mazzolini Subject RE: Update on SCU 31-04(214-090) You have verbal approval to abandon the RA BHA submit a sundry ASAP and notify NRC as mentioned below. Regards, 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: Monty Myers [mailto:mmyers@ hilcorp.com] Sent:Thursday, July 31, 2014 10:24 AM To: Schwartz, Guy L(DOA) Cc: Paul Mazzolini Subject: Update on SCU 31-04(214-090) Guy, We have had no luck fishing the stuck BHA on SCU 31-04 and would like to spot cement and sidetrack.We are currently POOH with a fishing BHA that backed off at approximately 9850'.We will have the exact number as to where the top of the fish is once we are out of the hole.We then need to test our BOPE. I would like to ask for permission to proceed with plugging and sidetracking the BHA w/nuclear source and moving forward to completing the well. I will attempt to have least 500'of cement spotted on top of the fish where we sidetrack and I will also submit a sundry to you shortly.As per our discussion earlier I will also contact the NRC and fill out the appropriate paperwork. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, July 30, 2014 11:13 AM 1 - To: Monty Myers Subject: RE: Question on SCU 31-04(214-090) Monty, As we discussed if you end up having to leave the BHA in the wellbore a sundry will be required as there is a RA source involved. Contact the NRC also with your plan of abandoning the BHA. Good luck with the fishing operation. 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: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Wednesday,July 30, 2014 7:23 AM To: Schwartz, Guy L(DOA) Subject: Question on SCU 31-04(214-090) Good Morning Guy, We were drilling at 11867'and encountered lost circulation on this well.We pulled up to the window while spotting calcium carbonate pills. On the way back in the hole we became stuck at 11860'.We have been working on freeing the BHA but haven't had any success yet. Our BHA consists of Bit, Motor, MWD, LWD w/non retrievable nuclear source. If we are unable to free the fish what are my cementing requirements needed for this fish? Also, I guess there is the chance that we could cut the pipe above the BHA at"'11,715'and have room to run the liner on top of the fish.Would I need to do anything different for the cement job if I left this nuke fish in the hole? Talk to you soon. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 2 A• prO 2 /4--v qo Ferguson, Victoria L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday,July 23, 2014 10:20 PM To: Ferguson,Victoria L(DOA) Subject: Re: Mud Weight on SCU 31-04(PTD 214-090) Follow Up Flag: Follow up Flag Status: Flagged Thank you! Monty M Myers 907.538.1168 On Jul 23,2014,at 10:16 PM, "Ferguson,Victoria L(DOA)" <victoria.ferguson@alaska.gov<mai!to:victoria.ferguson@alaska.gov»wrote: Approval is granted to increase mud weight as outlined. Thanx, Victoria Sent from my iPhone On Jul 23,2014,at 2:47 PM, "Davies,Stephen F(DOA)"<steve.davies@alaska.gov<mailto:steve.davies@alaska.gov>> wrote: For you since Guy is out. Thanks, Steve D. From: Monty Myers (mailto:mmyers@hilcorp.com] Sent:Wednesday,July 23,2014 2:31 PM To:Schwartz,Guy L(DOA); Davies,Stephen F(DOA) Subject: Mud Weight on SCU 31-04(PTD 214-090) Guy and Steve, We are currently drilling the SCU 31-04 and had planned on not needing any mud weight higher than 10.5 ppg. Seems like most other well ended up with 10.2-10.5. The flow of water from the high pressure water sand is posing a little more of a challenge for us while drilling. At a 10.5 ppg MW.The well wants to flow water at 22 bbls/hr during connections.While drilling our ECD is keeping it at bay and we are not seeing any flow or gain. We are 100%sure it's only water, haven't see any gas at bottoms up, and it's the same phenomenon we have dealt with on ALL the other Swanson sidetracks. I would like to ask for your approval to raise the MW up to a max of 11.5 ppg(if needed),same as FIT test,so we may hold back some of the water during trips. 1 • If you have any additional questions, please let me know. Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 2 gv �\ I7i v FHE STATE f : s; J 1... E. ., r,. i j -= _,6 333 West Seventh Avenue Y,G C7(WI,R\OR SEAN P1112\1,I.I Anchorage, Alaska 99501-3572 K,.„..,,, STA' La� � Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-04 Hilcorp Alaska, LLC Permit No: 214-090 Surface Location: 2072' FSL, 2126' FWL, Sec. 4, T7N, R9W, SM, AK Bottomhole Location: 4131' FSL, 2895' 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, / r_20e..,,,v _ Cathy '. Foerster �,�( Chair DATED this day of July, 2014. RECEIVED STATE OF ALASKA i <A OIL AND GAS CONSERVATION COM N JUN 16 2014 2\4- OPERMIT TO DRILL p (('�� 20 AAC 25.005 AOGC`� la.Type of Work: 1 b. Proposed Well Class: Development-Oil 0• Service- Winj ❑ Single Zone ❑✓ • 1c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril Q • Reentry ❑ Exploratory El Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • SCU 31-04 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive ste 1400,Anchorage AK 99503 MD: 11,936' • TVD: 10,655' • Swanson River 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Hemlock . Surface: 2072'FSL,2126'FWL,Sec 4,T7N,R9W,SM,AK FEDA028997 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3989'FSL,2841'FWL,Sec 4,T7N,R9W,SM,AK NA within Swanson River Unit 7/15/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4131'FSL,2895'FWL,Sec 4,T7N,R9W,SM,AK 2560 4,908 ft to the Unit boundary . 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 188.6 feet 15.Distance to Nearest Well Open Surface: x-344442.005• y-2457991.129• Zone-4 GL Elevation above MSL: 170 feet to Same Pool: 990'(SCU 22B-04). 16.Deviated wells: Kickoff depth: 9,175 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 68 degrees Downhole: 2025 psi ' Surface: 960 psi ' 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 2,961' 8,975' 8,975' 11,936' 10,655' 462ft3/342sx 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): 11,140'MD 10469'TVD NA 11,140' 10,470' NA Casing Length Size Cement Volume MD TVD Conductor/Structural 28' 22" Driven 28' 28' Surface 1,413' 11-3/4" 1000 sx 1,413' 1,413' Intermediate 9,969' 7-5/8" 2000 sx 10,100' 10,100' Production 407' 5-1/2" 150 sx 10,100' 10,100' Liner 1,550' 3-1/2" none 11,096' 11,474' Perforation Depth MD(ft): Perforation Depth TVD(ft): 10,272'-10,367'MD 10,272'-10,365'TVD 20. Attachments: Property Plat Q BOP Sketch ❑✓ Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Janise Barrett Email jbarrett@hilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature —L , Phone 907-777-8431 Date 6/16/2014 Commission Use Only Permit to Drill �'y API ��. Permit Approval (, ( See cover letter for other 2���%� /Ofj bZ Q`, i� 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:Ef Other: 7C J S c6O psi._ rte}3` f /e5±— Samples req'd: Yes❑ No[/]' Mud log req'd:Yes❑ Ncf" H2S measures: Yes❑ No0 Directional svy req'd:Yes[1I/NCI (� Spacing exception req'd: Yes❑ No[ Inclination-only svy req'd:Yes❑ Naj' ‘4,., e crb,...re.4„,,C407 A__' 484( 1 a-6 , / APPROVED BY Approved by: `� COMMISSIONER THE COMMISSION Date:7—,jr/ci a, y 72./q r 6-Z.et. /k/ 9NSubmitsn Form and Form 10-401(Revised 10/2012) Thi r t t v fir m the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Hilcorp Alaska, LLC SCU 31-04 (SCU 22-04 ST) Drilling Program Soldotna Creek lLi Approved By: /3 Z c Revision 0 May 7, 2014 SCU 31-04 Drilling Procedure Rev 0 Meorp Ala.ka,IAA: 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 Liner 25 17.0 RDMO 28 18.0 BOP Schematic 29 19.0 Days vs Depth 30 20.0 Geo-Prog 31 21.0 Anticipated Drilling Hazards 32 22.0 Rig Layout 33 23.0 FIT Procedure 34 24.0 Choke Manifold Schematic 35 25.0 Casing Design Information 36 26.0 6-1/8"Hole Section MASP 37 27.0 Plot(NAD 27) (Governmental Sections) 38 28.0 Surface Plat(As Built) (NAD 27) 39 29.0 Surface Plat (As Built) (NAD 83) 40 30.0 Directional Program (P1) 41 SCU 31-04 Drilling Procedure Rev 0 lLilcorp Alaska,1.1.0 1.0 Well Summary Well SCU 31-04 Pad&Old Well Designation Sidetrack of existing well SCU 22-04(PTD#199-083) Planned Completion Type 4-1/2" 12.6#L-80 Liner Target Reservoir(s) Hemlock Planned Well TD,MD/TVD 11936' MD/ 10655' TVD PBTD,MD/TVD 11820' MD/ 10573' TVD Surface Location(Governmental) 2072' FSL,2126' FWL, Sec 4,T7N,R9W, SM,AK Surface Location(NAD 27) X=344442.005,Y=2457991.129 Surface Location(NAD 83) X=1484464.759,Y=2457752.387 Top of Productive Horizon (Governmental) 3989'FSL,2841'FWL, Sec 4,T7N,R9W, SM,AK TPH Location(NAD 27) X=345176.1,Y=2459904.1 TPH Location(NAD 83) BHL(Governmental) 4131'FSL,2895'FWL, Sec 4,T7N,R9W, SM,AK BHL(NAD 27) X=345230.9,Y=2460044.8 BHL(NAD 83) AFE Number 1411838M AFE Drilling Days 19 AFE Drilling Amount $3.36 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 March,2014 SCU 31-04 Drilling Procedure Rev 0 Hilcor�r Uaska,LL(: 2.0 Management of Change Information Hileorp Alaska, LLC Hilcorpp Changes to Approval Permit to Drill Date: May 16,2014 Subject Changes to Approved Permit to Drill for SCU 31-04 (SCU 22-04 ST) File#: SCU 31-04 (SCU 22-04 ST)Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be,c-omrnoilitated40 the ACGCC &BLM. Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 Ililcarp Alaska,LL1: 3.0 Tubular Program: Hole Section OD (in) Wt(#/ft) Coupl OD ID (in) Drift (in) Grade Conn Top Bottom Conductor 22 0 28 Surface 11-3/4" 47 11 J-55 8rd 0 1413 Production 7-5/8" 39 8.5 6.625 6.5 N-80 SpeedTite 0 131 Production 7-5/8" 33.7 8.5 6.765 6.640 N-80 XLine 131 3623 Production 7-5/8" 29.7 8.5 6.875 6.75 N-80 SpeedTite 3623 5654 Production 7-5/8" 33.7 8.5 6.765 6.640 N-80 SpeedTite 5654 6552 Production 7-5/8" 39 8.5 6.765 6.5 N-80 SpeedTite 6552 10100 6-1/8 4-1/2" 12.6 5 3.958 3.833 L-80 DWC/C 8975 11936 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension 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 March,2014 SCU 31-04 Drilling Procedure Rev 0 llileorp Alaska.1.I.0 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@hilcorp.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 March,2014 SCU 31-04 iniDrilling Procedure Rev 0 flikorp Alaska.1.1A: 6.0 Planned Wellbore Schematic Proposed SCU 31-04 t,`dellSTout ofSCU 22-34 PROPOSED SCHEMATIC PTD: 199-083 lir,.1.0.41.1.1.1.a l e API: 50-13?-10136-31 EXISTING CASING DETAIL Size V.:1- Grade Conn ID Top An 22" 28' 11-3/4" 47 .1-55 8rd 11" Surface 1,415' 7-5/8" 33 N-80 Speed rite 6-625" Surface 131' 7-5/8" 33.7 N-80 X-line 6.765" 131' 3,623' 7-5/8" 23.7 N-80 Speed rim 6.875" 3,623' 5,654' 7-5/8" 33.7 N-80 Speed Rte. 6.765" 5,654' 6,552' i 7-5/8" 39 N-SC Speed Tate 6.625" 6,552' 10,100' �.I f [i-. 5-1/2"Goer. 2 L N-80 arid 4.778" 9,693' 10,100' J 3-1/ "finer 1-80 Hxdril511 2.992" 9,546' 11,096' ABANDONED JEWELRY DETAIL No. Depth ID Item 6 9,494' Bake rSC-175/8"397ret.plcwith 1O'4"IDsealbore 7 9543' 3-1/2"buttress X nipple,2-813"ID 7a 9,546' 3-1/2"buttresssealas*55'long x4.0"OD ovr@6,983E 7b 9575' Baker 2XPGnertop packer,failed pressure test 8 95$9' 3.437" Knock-out Isolation valve,2.707"inner string deararxe3.437"Cvher flapper knocked cut 9 9,627' 2313" 3-1/2"tfydtiU511Xnipple,ID=2.813" 10 10,270' DPM Baker Bottom Tripltlbpstoodc,5.1/2" 11 10,276' ELM 5-112"DW_i packer with skt for whipstock Orertati=r. J I 12 11,108' Bottom of slotted liner 40 rPSOP USED EQUIPMEN1 r. Depth ID OD Item KOP @ 9175' 1 X200" - 6.625" 7-5.ig'3i Cast Iron Bridge Plug2 9175'-9193' 6.625" Bek,aO?n II 3itl ipAtgr-k SP 3.951" 6.625' 7-5:,'S x4.5"BakZXP 3 ► liner han >r> partes any. • e \ =a 3:7,75.-11936' 3.95S" 4.50"(5.0" 4-1#2"12.&L-S0DWC?C Conn) Lines 7 6 MI � 1.7.547b 1 IATION DETAIL NNW( . KOP: 9175'MD/9172'TVD 4 \ Build: 32/100' Hold: 632 from 10,032'-11,394'MD Drop: 62/100'to 45'2 at 11'756'MD iC '1 Inclination Drop: 452 at 11,936' GZ 14 Azimuth: 209 from KOP toTD H3 i_ 11 —�,i 0-2 Perfs 10,272'-10,3671.4D 12 10,272'-10,3557/1 _/CEMENT DETAIL 4 a. 6-1/B" Proposed to cement to inside window with 32.bk15cement(include; 50%excess on open holevolume)and 500'of cement above window. Page 6 Revision 0 March,2014 S SCU 31-04 Drilling Procedure Rev 0 liilcorp Alaska.IAA: 7.0 Drilling Summary SCU 31-04 is a development oil well planned to be re-drilled in a NorthEasterly direction from SCU 22-04 utilizing the existing casing program down to 9175' MD/9172' TVD. At 9175' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 2811' 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 (TCP) 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 July 15th, 2014. sr 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. 314-3�� sck az- °`1 General sequence of operations pertaining to this approved drilling procedure: 1. MOB Saxon Rig#169 to SCU 31-04,NU and test BOPE (5 days) / 2. Perform clean out run to plug(9200') and test casing. Displace to mud. (1 day) 3. Set Whipstock, mill 6.125"window at 9175'. Perform FIT to 11 ppg (2 Days) 4. Drill 6-1/8" production hole from 9175' to 11936' 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 March, 2014 SCU 31-04 la Drilling Procedure Rev 0 nilror1,: Ia.ka.LL(: 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 31-04. 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. V • 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. 't§t•-' o Hilcorp requests approval to install a 3-1/8" 5M HCR valve on kill line in lieu of a check valve. — Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. 77 o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. r— 1, �j c/L/ Z/,U Page 8 Revision 0 March,2014 0 SCU 31-04 Drilling Procedure Rev 0 Intern-I)Alaska. 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. 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Irileorp Alaska.LL1: Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.reggna,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_EnergySection Notifications@blm.gov Page 10 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 Ililcorp Alaska,1.1,1: 9.0 R/U and Preparatory Work 9.1 A separate sundry will be submitted that will include the following: • MIRU workover rig. • Set BPV, remove tree. • N/U and test BOP. �U l� 1`l/ • Pull existing production tubing. Plug back well with cmt. ' ���� • Tag &pressure test cmt plug. 3 • Run and set a CIBP at 9200' 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 March,2014 SCU 31-04 Drilling Procedure Rev 0 !mem p Ala,ka,1.1.1: 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 March, 2014 SCU 31-04 ini Drilling Procedure Rev 0 I hit orp Alaska.I.I.I: 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%KCl/PHPA fresh water based drilling fluid. Properties: MD btu Viscosity Plastic Viscosity Yield Point pH API Fluid `� Loss 9175'—11936' 9.5-10.5 ,, 40-53 15-25 15-25 8.5-9.5 <_6.0 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 March,2014 • SCU 31-04 Drilling Procedure Rev 0 Ililcos")Alaska.LLC 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 RIB. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (-9200' MD). 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 RIB & 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 March, 2014 • SCU 31-04 Drilling Procedure Rev 0 Ifilcorp Alaska, 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 1/2 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. Page 15 Revision 0 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Irilcorp Alaska, WindowMaster G2 System on TorqueMaster BTA 7-5/8"39#Csg—WindowMaster G2 On BTA BHA#1 Connection Length O.D. BOTTOM TRIP ANCHOR 31/2 IF-Box X Bottom Guide 3.21' 6.18" WINDOW MASTER WHIPSTOCK Shear Bolt X 3'/2 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Ililcorp Alaska.I,I.0 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 Gyro. 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 '/4 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 AA25 AZI INF Desired orientation of the Whipstock face is in 0 to 25 degrees azimuth. Hole Angle at window interval (9175' MD) is < 1 deg. The wellbore trajectory is also planned to 21 degrees azimuth. 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 r4,k shear value). y►�, 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.5 ppg 6%KCUPHPA drilling fluid. 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. 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. ! ✓ Page 17 Revision 0 March, 2014 SCU 31-04 Drilling Procedure Rev 0 nikurp,%Ia.ka.1.1.1: 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 11.5 ppg EMW. • (11.5 —9.5) * 0.052 * 9172' tvd= 954 psi Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 11 ppg FIT results in a 2 ppg kick margin while drilling the interval with a 9.5 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 '/ IF-B X 3 % REG-B 5.5 6.5 FLEX JOINT 3 '/ IF-B X 3 1/2 IF-P 6.5 4.75 UPPER WATERMELON MILL 3 %" 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 %" 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! Page 18 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 IIilcorp Alaska.I.I.1. 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 1.5 deg. Must keep up with 8 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Itileorp Alaska.t.l.c HALLIr'3URTDN 6-1/8" (156mm) MM55 PRODUCT SPECIFICATIONS Cutter Type SelectCutter w. IADC Code A1924 '+ Body Type MATRIX Total.Cutter Count 27 1 • nl Cutter Distribution ;jIll ill= i 44 4 Face 1 16 ' t - i Gauge 5 0 liNir' Up(hill 5 0 'umber of Large Nozzles 0 1 *, Number of Medium Nozyles 0 * Number of Small Nozzles 5 I . Number of Micro Nozzles 0 rttI op +_ , Number of Ports(Size) 0 .. Number of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 7.2 - �I Normalized Face Volume 39.813% 'U API Connection 3-1/2 REG.PIN a j dot Recommended Make-Up Torque* 5,173—7,665 Ft*lbs_ Nominal Dimensions" Make-Up Face to Nose 9.111 in-233 mm Gauge Length 2 in-51 mm Sleeve Length Oin-0nun • ~+z_.:` '. Shank Diameter 4.5 in-114 mm Break Out Plate(Mat.tiflegacl'it) 181+153`44030 ' ! Weight Shipping eight K0Lbs.-36Kg. z, : SPECIAL FEATURES Smaller cutters in center,1132"Relieved Gage Material#7802S4 *Bit specific nreirsu ndcd make-up torque is a function of the bit I.D.and actual bit sub 0.13.utilized as specified in API RP7G Section AU_ **Dcnign dimensions are nominal and may vary slightly on manufactured product Halliburtton Drill Bits and Services models are continuously mimed and refined. Product specifications may change without notice. 4}2014 Halliburton.All rights reserved.Saks of Halliburton products and services will be in accord solely with the tenni;and conditions contained in the contract between Halliburton and the customer that is applicable to the sato. www.halliburton.com Page 20 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 11ilcarp Alaska,1.I.0 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. J 14.10 Drill 6-1/8"hole to 11936' 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Irik•ori,Ala ka.LLC 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Iiik'orp Alaska,LLC Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-1/2 in 12.60 lb/ft(0271 in) L-80 standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 1111111111111111111MWUSA 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:VAMUSAsalesvam-usa.com 0.271 Nominal Wall Thickness(in) 12.60 Nominal Weight(lbs/ft) 12.25 Plain End Weight(lbs/ft) 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 ftj 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 ftikorp Alaska.LU 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Ifikorp Alaska,i.l.l: 16.0 Cement 4.5" Production Liner • 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 82 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 8675' TMD. 16.7 Displacement fluid will be produced water. —127 bbls of—8.6 ppg produced water Cement Calculations 7-5/8"x 4-1/2 DP"Overlap: (9200' —8900') x 0.023 = 6.9 bbls 7-5/8"x 4-1/2"Liner Overlap: (9175' —8975') x 0.023 = 4.6 bbls 6-1/8"OH x 4-1/2"Liner: (11936' —9175') x 0.01677 x 1.5 = 69.5 bbls Shoe Track: 80' x 0.01522 = 1.2 bbls Total Volume(bbls): 6.9 +4.6 +69.5 + 1.2 = 82.2 bbls Total Volume(ft3): 82 bbls x 5.615 ft3/bbl = 462 ft3 Total Volume(sx): 462 ft3 / 1.35 ft3/sk= 342 sx Page 25 Revision 0 March, 2014 SCU 31-04 Drilling Procedure Rev 0 11 Henri)Alaska. 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 l/ 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 1/2 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 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Ililcorp Alaska,1.1,C 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 March,2014 SCU 31-04 Drilling Procedure Rev 0 Iilcorp Alaska.I.1.0 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 mmyersAhilcorp.com -r- 3,,,u 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 March,2014 SCU 31-04 Drilling Procedure Rev 0 (Iilcorp Alaska,11.11: 18.0 130P Schematic ii i rft rflilfli rffi iffilnt. \a,d s 60 tf�r 11fi lil Iii iii r !a'Model 7;1S 11" 5300P>1---/13 l) ,ir ia6°a ,° ° lecc ILL 2.00' � � r.o ra ' • � ft$tII 1t1 lel tit tat lie • 2 1/1G SM Kill Side imot118 5M Choke Side 3 1.41' 411 ��. :I'JJ'i 1/ g/— 111 ISI 111111 III Grad 2.00' 1 lit III lit lil Ii 1 - rat 111110 , � ; . E1 Page 29 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 Ilikorp, Ia:ka.LLC 19.0 Days vs Depth Days Vs Depth 8000 8500 SCU 31-04(SCU 22-04 ST) 9000 - 9500 1a00a 0 10500 11000 11500 lz000 — — — — __ ♦ ♦ ♦ i 4 12500 — — 0 2 4 6 8 10 12 14 16 18 20 Days Page 30 Revision 0 March, 2014 SCU 31-04 Drilling Procedure Rev 0 filcorp Alaska.13.1 20.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: SCU 31-04 aka 22-04ST FIELD: Swanson River X Y Pad 11-22 SURFACE X: 345188.76- STATE: Alaska SURFACE Y: 2457989.10 BOTTOM HOLE X.• 345188.76- TVD REF DATUM KB BOTTOM HOLE Y: 2460011.16- TVD REF ELEV 170 18'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV 152 PROPOSED TO: 11800.00 MD PROPOSED TD: 10656.831 TVD Asidetrackwell out of the SCU 22-04 to infill the recently successful SCU 22B-04. This well will offset the ✓ Objective: 22B-04 to the east. Geo Summary/ Based on subsurface evaluation and reservoir modeling results Justification: • EXPECTED TOP Formation FORMATION FLUID MD TVD Est Pressure X Y +/. SSTVD -113-H2O_KRE_GRID 8920 8917 350376.78 2477822.31 -8747 E_HP-H2O_KRE_GRID 9136 9133 350285.43 2477828.67 20 -8963 KOP KOP 9175 9172 350112.65 2478200.11 20 -9002 SR_G2ST Hemlock Oil Oil 10879 10213 344905.11 2459273.26 25 -10043 SR_H1ST Hemlock Oil Oil/Gas 11101 10300 1000-1400# 344985.50 2459460.77 25 -10130 SR_H5ST Hemlock Oil Oil 11477 10451 1000-1400# 345121.42 2459777.70 25 -10281 SR_H7ST Hemlock Oil Oil 11647 10549 1000-1400# 345176.15 2459904.13 25 -10379 SR_H8ST Hemlock Oil Oil 11714 10596 1000-1400# 345195.56 2459948.63 40 -10426 TD -_ 11800 -, 350772.9 2479138.0 Primary Objective =Secondary Objective TARGET RADIUS 50 FT @ the Hemlock level DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 from KOP. LWD Data: Triple Combo LWD on Production hole section i E-Line Log 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 COMMENTS 1. The Tyonek Hi Pressure water sand will be above the KOP! I Page 31 Revision 0 March, 2014 SCU 31-04 Drilling Procedure Rev 0 Ililc•urp Alaska.1.1A. 21.0 Anticipated Drilling Hazards 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 solidscontrol equipment to maintain density and minimize sand content. Maintain programmed mud specs. t„.)ft' t3 it- Fl.w 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. No abnormal temperatures or pressures are present in this hole section. Y Page 32 Revision 0 March, 2014 SCU 31-04 H Drilling Procedure Rev 0 II k o•f,Alaska.r.i.c 22.0 Rig Layout fm1 mu .422 til_ ii ; r t 'r t R ' 3 p IIIIII I -.'? l'illitHWIlli.111 R l' 171 7 -7T.:::11' r:i k 1 au iT,3 =��. 1• 11.111 i Y • _ aen is odea' 1 iy 'I �nnne*o • i�u ... L . L , e H. ... ;1IJ .��. 1. ii _ :II'l Rim,:g !i 1, �II f ,-4 ..s IIIIIIIMIE: I., I . 1Ri!4111! rill' x i -. I ` 11 L ;PHI m iiiiKXC�: Illiin _ I 11"V IIA } iA� ,11�. ! n '- - 9i:1� ?11 1■1 [mml "1 ' illi ifil Vii:= 7 = IC�' r( lik I�_1 _ 0-0i= ; �� � ►7, .1 liliiiillil'i i, ii um . 111113111111 II Quill IIS l�'Sr:� 1 i,.1711 01 -...1:1;..r" iiuili ��,� I _- ::II ie:]I i7i. Mil I L'=" ' `-'' El I- gi t Y u . �� I 71 ITC"�'�• 1. i 1, 1 ,t f ,' IR 11011IIID'. fIIIIIIIIIII IIIGII l� YklIIIIIG �.. 1 0 1 rv, II I I i. II III I I► II II I -- —.11 IIIIIP IIIIIIIII '� IIIIPII�I, PI1IIIIII' LIII �! IIII. , I 1 I I I. I I I i. jIi _ � i un - ,rte . _ Page 33 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 Iritrorp Alaska,LLC. 23.0 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 34 Revision 0 March,2014 SCU 31-04 HDrilling Procedure Rev 0 Hilcor1,Alaska,L1.0 24.0 Choke Manifold Schematic .~r'r;: A n li iit , ,�_. : ' - 27.24 43.22 43.62 1 .O, 0 IN W�Q r6 `: .} ,g.' ta621843 -14.62 15_43- ..aft ' qy0.19 0.9h,. � 01, AA 0 . ra.i9 SCU 31-04 Drilling Procedure Rev 0 na<mpAlaska,ILL 25.0 Casing Design Information Calculation & Casing Design Factors Swanson River Unit DATE: 6/13/2014 WELL: SCU 31-04(SCU 22-04 ST) FIELD:Soldotna Creek Unit DESIGN BY:Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 6-1/8" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 2025 psi (See attached MASP determination& calculation) Production Mode MASP: 960 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 i 1 2 3 4 Casing OD f 4-1/2" Top (MD) j 9,175 Top(TVD) 9,172 Bottom (MD) 11,936 Bottom (TVD) 10,655 Length 2,761 Weight (ppf) 12.6 Grade L-80 Connection j DWC/C Weight w/o Bouyancy Factor(lbs) I 34,789 Tension at Top of Section (lbs) 34,789 Min strength Tension (1000 lbs) 288 0 i Worst Case Safety Factor(Tension) 8.28 Collapse Pressure at bottom (Psi) 4,326 Collapse Resistance w/o tension (Psi) 7,500 Worst Case Safety Factor(Collapse) 1.73 MASP (psi) 3,226 Minimum Yield (psi) 8,430 Worst case safety factor(Burst) i 2.61 Page 36 Revision 0 March, 2014 SCU 31-04 Drilling Procedure Rev 0 26.0 6-1/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hil corp 6-1/8"Hole Section "in 0`'°"' SCU 31-04(SCU 22-04 ST) Kenai,Alaska MD TVD Planned Top: 0 0 Planned TD: 11936 10655 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad SR_G2ST 10,213 2500 OIL/WATER 4.7 0.245 SR H1ST 10,300 2000 OIL 3.7 0.194 • SR_H5ST 10,451 2000 OIL 3.7 0.191 SR_H7ST 10,549 2000 OIL 3.6 0.190 SR_H8ST 10,596 2000 OIL 3.6 0.189 TD 10,668 2000 OIL 3.6 0.187 . Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date 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 9.5 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 9062'TVD=12.5 ppg EMW Fracture Pressure at 6"window considering a full column of gas from window to surface: 9172(ft)x 0.65(psi/ft)= 5962 psi 5962(psi)-[0.1(psi/ft)*9172(ft)]= 5045 psi MASP from pore pressure;entire wellbore evacuated to gas from TD 10655(ft)x 0.19(psi/ft)= 2025 psi 2025(psi)-[0.1(psi/ft)*10655(ft)]= 960 psi ' Summary: 1. MASP while drilling 6-1/8"production hole is governed by SIBHP minus entire wellbore evacuated to s gas from TD. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. Page 37 Revision 0 March, 2014 SCU 31-04 H Drilling Procedure Rev 0 IIikkorp tla,ka.1.1.4: 27.0 Plot (NAD 27) (Governmental Sections) Elf3/ a A028396 0 A028399 ,N028990 SRU 24-33 BHU* SOO8N009W •' scu44-33.pHi 1 f , max_ SCU 41-01;BHL4 i•`- / SCU 21-04 EH • Z4 21A-04 BHL+ SGU 31-0� BHL N. SCU 331-04 EMU% \ ISC�-U 31-04 TPH b - }'�.. .Cu 4t. 2r-ov BHLU ^'' SCU 41A-04 EiF4Li SCU 42-0S BH CLI 42 03RD BIC% • SCU 42-04BHLi s. 6 6 I8 .SCU 12-04 BHL J s f SCU i2A-04 BHL s SCU_22B-04(21A-15T)BHL � 6 SCU 332-04 EHLL' SCU 22-04PB BI-1 SCu 42-05X 1 ; e3 SCU 22-04 BM*_6! 1 42B-CIS E U 429-cHL ,SCU 42B-0 fS BHL SCU 33-03 SF0L4 I j S'—SCU 31-04 SHL SCU 43-0491-F,s SCU43-05E1* SCU•-3A-05 BHS A028996 SCU43A-04 BHL+ A028997 j SOO7NO09W SCU 41_04 51-:.J SCU 24-041,7ST)BHL$-____ - SCU 314-0!14, _ -- -- • Legend i- 5CU 21A-09 BHA--.... - sou 41• .B1-a- s SCU 31-04 SHL X SCU 31-04 TPH . -f- SCU 31-04 BHL 0 0 • Other Surface Well Locations • Other Bottom Hole Locators SWW 128-09 BHL, _ Well Paths SRF Unit Boundary 5CU 32-05 BHI/'C.aw-vc cnt ._ _ 0 1.043 _.-__ Soldotna Creek Unit Feet SCU 31-04 AL:tJo State Plane Zane 4,F3A027 l llilowp t1.j4...1.1.4 bap Data:312112014 Page 38 Revision 0 March,2014 SCU 31-04 HDrilling Procedure Rev 0 int.", %,lit,L a.I.1 A: 28.0 Surface Plat (As Built) (NAI) 27) Li \ \,,,,, 'f °a.I 2'ALCAP 4928.5 N-24561 -2-% E.149i34e €j: E_CV-212e93 1 I .,.—,y, it.. SGL122-0 ASSUILT SURFACE LOCATION NAD 27 ASP ZONE 4 N:2457991.129 . E:344442,005 ii im LAT:60°43'30..381N ' g I 2128'ION:150''2'07.920"W VL 0 207.2'SSL 4e IIELEV:152,49'NAVD8 0 1. 27-245 ran'Ma) , 2 IIcoU W ! I I an FSL INTS) l' i I 1 -___ -. ' .--.^'r SECTS a+J COR(00:4PLRED) N:24004 .518 E:3422zr2.355 SECTION LINE(NOT TO SCALE) /61 ...I(-- 1 • {,,,,_.. r_.... 111.1 11_11., 1 111,..„ _ NOTES e si=OF HORIZONTAL;Doan US.FEET POSITIC44(EPOCH 20101 ti x��rly4y 4T e,Nxg RTI4.AL OONTROL,(N VO80)IS Art 'US$01.4)1 ION FPt3M r' � NGS STATIONS T80N TSEA.ANDD AN 1 TO ESTABLRSH CP-2. THE M :-.,..3,-).--'��A�..;154,, ALASKA STATE PLANE COORDINATES NAD E3 ZONE 4 IN FEET .RE: ' c--v" 1�-. *I—2483$4.078 E-14I tG9-444 r ..:x ` �LL ELEV_•212_&50(ALAVC6B) .. ',tux I.1.4.1-Mit i 2.SECTION LINES SHOWN WERE ESTt4FLISF4ED FROM SURVEY e, 4 7 TTS TO 04 GiNAF.OLO MONUMENTATlON 004)1 SCALE �r? i.-., .3. DATUM TRANSFORMATIONS(NAD& ASPZ4 TO NA027 ASPZ4) 4 *[=' X11 t i'`4 WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. I t._ t , I 1l1\tom ... 1111. 1111.. _ _. ....__._ _111_1 i 1111 ILLI & - N1�,6cT HIyL�CORrP{ALA5SKA,LLC pc rsar 47MVANVS.f1'R 1 Y'LR.FIE9-D IMI* Y'1^d _Cora Irc S+VELL SCEs 22-04 6r.•,510k •:e {AS(r'84)JILT SURFACE LOCATION sc:ic: ,�wa ._ tl�]$ritik.`MESA..tal l4 1,1: it.rt6il.'. 0 '.:,..7 I:is...?: F 11 6,1.:a 5t1cR..N r..rwia ',Mt tea;.}- k re F.r,rr..;_ " SE:TION C4 TOT7N ROD'A' g4:2T sttv..clr...& _i 1..X40,.. I I 1 ll'Oirp LITT:-L i.LU. 1 " SEWARD MERIDIAN,ALASKA i Page 39 Revision 0 March,2014 SCU 31-04 Drilling Procedure Rev 0 I Iik•orp Alaska,LH: 29.0 Surface Plat (As Built) (NAD 83) Id . i CP-2 '..."'" ll.24Ai49yn I i;•1469Cs1FAM4 ELEv,•212 610 Ii1/41/4,,,,,,_____/ I SCU22-04 I ASBU1LT SURFACE LOCATION NAD 83 ASP ZONE 4 N:2457752387 _ E:1484464.769 tr2 I y LAT:0'4328.35114 ACI 6LOft 756`52'1 ,916"Yd In 2128"PAIL i Io 2072'FSL i ELEV: 152.49'NAVD88 i :0 z 2126 f3'ft1NTSj Di d _ Z1 0I F- U inI }dam I -.-m'-_" 2077 c$L IN/5J /I/ 3€EFC1TgevSC16 (CtIPlT€Q) N.24@07 ,% 4 SECTION LINE(NOT TO SCALE) e*-- NOTES F BASIS OF IIORIzc JTAL NADU JS FEET FCSITiCN(EPOCH 251 DI �14}� APfl VERTICAL L ON'TRCat(14.'sVNS1 ISAN�FII SIM U1I'N FHi:r.1 .4% OF tittAt le NGS STATIONS T6ON T EA AND AN[ TOESTABLISH CP-2. THE qi '"y �y+17 ALA STATE PLANE COORDINATES NA,D41ZONE 4INFEET ARE: :-4 +I/f N 24gdSrW6,9 .•rF ]Et ...%!..1`4 E=1,41K4550 444 =—' a �, ,.? ELEV.r 212 69C?NA DDE1) f-.,_ - -cot F.ild ti ,, r ♦ ayr-8 2.eC If N F INl 5$H wN LV Ff t qT l$F3 iJ FKtt}ti aUii'F Y SCALE �/+ ,......, ,. TIES TO OH OINAL OLO MONLIMENTATION.:1937) a 2 1. } 41a1t1�•.tN;. rerr P F#:u(LT I{ILCORP ALASKA,LLC anu�eF Oa m u(tin Icc S ANS(7P!12IV1 11 FIELC? rn.: :,u r, WELL$CLI 2.2-fJ4 r " +• •.• T ilho'!P Arai >4m AS NAL-) SURFACE LOCATION AD 8i Fupixr.u,uw yi,c FVTra:-.,r{srr.,; o_fl+:+t 1.!..:2 hY ice ,,x*•-a r+s rx�aar^ ioc�ir_a SECTION G4 T47N ROPAI xccF CY t SMiG:+V.}jisu••ii4L+_V 1 likutp M I'I.FF,I.faA• SEARD MERIDIAN,AlAF:;KA 4tl I ' Page 40 Revision 0 March, 2014 Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit Soldotna CK Unit 323-04 Plan SCU 31-04 Plan: SCU 31-04 WP2.0 Standard Proposal Report 16 June, 2014 HALLIBURTON Sperry Drilling Services WILL Utz IAIL : A'oiaoma UK Unit 3L;i-U4 HALLIBURTON Gr 152.49 +N/-5 +E/-W Northing Latittude Longitude Slot Sperry Chilling 0.00 0.00 2457991.13 3444'.,.u1 60.7251057 -150.8688684 SECTION DETAILS Hilcorp Energy Company Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Calculation Method: Minimum Curvature 1 9175.00 1.03 0.00 9172.00 0.00 0.00 0.00 0.00 0.00 Error System:ISCWSA 2 9195.00 3.43 0.00 9191.99 0.78 0.00 12.00 0.00 0.73 Scan Method: Closest Approach 3D 3 9215.00 3.43 0.00 9211.95 1.97 0.00 0.00 0.00 1.85 Error Surface: Elliptical Conic 4 10032.00 68.56 20.52 9838.48 429.93 149.94 8.00 21.04 455.25 Warning Method: Error Ratio 5 11393.72 68.56 20.52 10336.16 1616.99 594.35 0.00 0.00 1722.76 6 11786.44 45.00 20.52 10549.79 1922.51 708.72 6.00 -179.99 2048.99 SCU 31-04 SR_H7ST Tgt 2 7 12000.00 45.00 20.52 10700.80 2063.94 761.66 0.00 0.00 2200.00 CASING DETAILS TVD MD Name Size 10702.73 12000.00 4 1/2" 4-1/2 FORMATION TOP DETAILS Project: Soldotna CK Unit TVDPath MDPath Formation Site: Soldotna CK Unit 10213.49 11052.81 SR_G2ST Well: Soldotna CK Unit 323-04 10300.49 11290.85 SR_H1ST Wellbore: Plan SCU 31-04 10451.49 11631.47 SR_H5ST 10549.49 11783.28 SR_H7ST SCU 31-04 WP2.0 10596.49 11849.76 SR_H8ST SURVEY PROGRAM REFERENCE INFORMATION Date:2014-05-20T00:00:00 Validated:Yes Version: Co-ordinate(N/E)Reference: Well Soldotna CK Unit 323-04,True North Depth From Depth To Survey/Plan Tool Vertical(TVD)Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') 1063.49 9175.00 SCU 323-04(SCU 323-04) INC Measured Depth Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@18.0') 9175.00 9475.00 SCU 31-04 WP2.0(Plan SCU 31-04) MWD Interp Azi+sag Calculation Method: Minimum Curvature 9475.00 12000.00 SCU 31-04 WP2.0(Plan SCU 31-04) MWD+SC+sag - KOP Lgl Coords:2067 FSL 2130 FWL Sec 4 T7N R9W SM AK '- 9100- _---- ----- KOP in 7 5/8"Csg;Start Dir 12°/100':9175'MD,9172'TVD:30°TF 9275- End Dir :9195'MD,9191.99'TVD 9450- Start Dir 8°/100':9215'MD,9211.95'TVD 9625- - c - End Dir :10032'MD,9838.48'TVD = 9800_ -- o - C C") - Start Dir 6°/100':11393.72'MD, 10336.16'TVD c) 9975--9975_ `\ 0 \\ End Dir : 11786.44'MD, 10549.79'TVD - ‘ U ` i i 10150- \\ i SR_G2ST _ I 10325- S R_H 1ST'"- I - SCU 22-04 _ _ ----- N, SR HSST_ __ I I 10500- iSCU 31-04 SR_H7ST Tgt 2 i SR_H7ST _____ 4 1/2" • ,' SR_H8ST- 10675- SCU 22 04P61 SCU 31-04 WP2.0-__-- i vr - BHL Lgl Coords: 1149 FNL 2385 FEL Sec 4 T7N R9W SM AK I 10850- SCU 323-04 I - Total Depth:12000'MD, 10700.8'TV - 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 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 I I I i I I I I I I I i I I I -175 0 175 350 525 700 875 1050 1225 1400 1575 1750 1925 2100 2275 Vertical Section at 20.26° (350 usft/in) NN_A- >. C O d to NET) E coO co U O + H 0) ro r- c) 0 QUO 2U �� E<<-N 21 -ooh �tnH N(r c+ z co �� o Eywo 0+0 co CN coot 0-0 (n 9 o0 2 f�0WW z ,p u0-) v E-06-0 I- o I- 2' E O i J L.O.2 NL W N U N ^ Q NTdjd N o I- U M H (.02(02 > U W .60010)000 C '00 OO NOF. N U) ,Or--c0041--00 Y v.02.173',c- >- N W(n W N Y U ❑O (nOO�)ONNO > v O N UICAVO o J r Q O cG N ., • O N N N O a. U Q N 0 W 000.7000 O o 0 00 V d'v N 000000000 C7 N O� O 000 N O 0)O O N o 0 > M M F (n N fl DD co. o co.- >- o 00 J) 00000000 c- W o U U J N o o o 0 0 0 0 Q 3 2-4- > o 90 CO Q ❑ONONOt00 Q Q W D O 0'CO N n -I M (A 00 moo 0O 000A'ON<O Z OOO�MrtO J Nu O W as 00000 �'� o 3.-COON v cv J Lc- No T V' _ L 0 00 DD Orn - (n ONr MOr V z� N NMIhM - Z 0 -00cO0 V i0 20» ._0V Z000 N`-N0 N( n(n( n0) - ,r vN,NO..N - O i O - 0000NN00 W O -0000 _o 0000 NN 0000 -a- 'c.o.-novo co tD 6)O rON0MI0N �NNo - 0000000ti 0—v0 0 co - 0 0 0 N N N N Z O —- N <0000000 0 o O o 0 0 o 0 E 0 0 0 - N N N N O v coo -NN-r L O.-T - COvv�0000 00 0) _N _ N AMM NNl-, - -, m oav y _ 0 0 0 0 0 N v 0 o0-0-0 --. 0 - 0 • CO t0 I+)1V M N O _co \\\ rONoc°'i°r°o N C' 0001 0,-_-N _ m,_NM'13'@S 13SF • - co O co • L AI I-o c / o -- / 1 I (N - 0 O = / I N - _ o .M-. C)O/ I 1 U _ +..-... to I I V) C I o c`a 00 I 1 I —7 L�C.1 V. 1 - 1 I - � 1 I I .1- CD _ y - 3 NCI' b II N til o (�L? N bD I N ...... H O C Z GM o �_ ri v o U� U CID UUU01N m "I .�" " co to ca m' ^^ n �I cv 00 So .oS— '-� v .1- 9 ---S o u) o ::.,' � o ( M .--� / _ O- z v 7 U - o 2co c. �y� d WNN ��J M 0.. coSoa '~� _oo M y y N ....> ) C 0 0 DV.v Z O O o�� - o ovv En co c O 9-9'-- - LL yMcico - Z -»2 _o U co co W o -_ W U N C _o n� W y C'311 C� _ W w C` _ m y y MI �L �_rs o 0 J a qw : JU o I I I I I I III „ , I i I I I I l I I I I I I 1 m , „ „ 1 „ „ , „ „ 1 „ l l l l l l l l l l N-S. Q O O O O O O O o O 0 0 0 0 0 0 Lrt, P.8=0 O 0 N CO o co 0 N CO 7 O V NI - ��W O'E N O N o -N. G, CO r h N I wa 0> .,, (uisn ocE)(+)yuoi\i/()lhnog Halliburton HALLIBURTO' Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Company: Hilcorp Energy Company TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1E Project: Soldotna CK Unit MD Reference: SCU 31-04©170.49usft(GL@152.49'+Rig@1E Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 323-04 Survey Calculation Method: Minimum Curvature ~' Wellbore: Plan SCU 31-04 Design: SCU 31-04 WP2.0 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 ° I Well Soldotna CK Unit 323-04 Well Position +N/-S 0.00 usft Northing: 2,457,991.13 usf Latitude: 60.7251057 +E/-W 0.00 usft Easting: 344,442.01 usf'' Longitude: -150.8688684 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usf Ground Level: 152.49 usft ^' Wellbore Plan SCU 31-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 6/30/2014 17.04 73.71 55,502 Design SCU 31-04 WP2.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,175.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (0) 18.00 0.00 0.00 20.26 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (0) (0) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (0) I 9,175.00 1.03 0.00 9,172.00 9,001.51 0.00 0.00 0.00 0.00 0.00 0.00 j 9,195.00 3.43 0.00 9,191.99 9,021.50 0.78 0.00 12.00 12.00 0.00 0.00 9,215.00 3.43 0.00 9,211.95 9,041.46 1.97 0.00 0.00 0.00 0.00 0.00 10,032.00 68.56 20.52 9,838.48 9,667.99 429.93 149.94 8.00 7.97 2.51 21.04 I 11,393.72 68.56 20.52 10,336.16 10,165.67 1,616.99 594.35 0.00 0.00 0.00 0.00 11,786.44 45.00 20.52 10,549.79 10,379.30 1,922.51 708.72 6.00 -6.00 0.00 -179.99 12,000.00 45.00 20.52 10,700.80 10,530.31 2,063.94 761.66 0.00 0.00 0.00 0.00 6/16/2014 11:48:16AM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURTONi Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Company: Hilcorp Energy Company TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1E Project: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1 E Site: Soldotna CK Unit North Reference: True " Well: Soldotna CK Unit 323-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan SCU 31-04 Design: SCU 31-04 WP2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 9,001.51 9,175.00 1.03 0.00 9,172.00 9,001.51 0.00 0.00 2,457,991.13 344,442.01 0.00 0.00 KOP Lgl Coords:2067 FSL 2130 FWL Sec 4 T7N R9W SM AK-KOP in 7 5/8"Csg;Start Dir 12°/100':9175'MD,9172'TVD:30°TF 9,195.00 3.43 0.00 9,191.99 9,021.50 0.78 0.00 2,457,991.91 344,442.02 12.00 0.73 End Dir :9195'MD,9191.99'TVD 9,200.00 3.43 0.00 9,196.98 9,026.49 1.08 0.00 2,457,992.20 344,442.02 0.00 1.01 9,215.00 3.43 0.00 9,211.95 9,041.46 1.97 0.00 2,457,993.10 344,442.04 0.00 1.85 Start Dir 8°/100':9215'MD,9211.957VD 9,300.00 10.07 14.07 9,296.32 9,125.83 11.73 1.81 2,458,002.84 344,443.97 8.00 11.63 9,400.00 18.04 17.23 9,393.25 9,222.76 35.04 8.53 2,458,026.05 344,451.00 8.00 35.83 9,500.00 26.03 18.49 9,485.87 9,315.38 70.69 20.09 2,458,061.55 344,463.04 8.00 73.28 9,600.00 34.02 19.19 9,572.39 9,401.90 118.00 36.27 2,458,108.63 344,479.84 8.00 123.25 9,700.00 42.01 19.64 9,651.11 9,480.62 176.03 56.74 2,458,166.39 344,501.08 8.00 184.78 9,800.00 50.01 19.98 9,720.50 9,550.01 243.66 81.12 2,458,233.69 344,526.35 8.00 256.67 1 9,900.00 58.01 20.24 9,779.22 9,608.73 319.57 108.92 2,458,309.23 344,555.15 8.00 337.51 10,000.00 66.00 20.46 9,826.12 9,655.63 402.29 139.61 2,458,391.53 344,586.93 8.00 425.74 10,032.00 68.56 20.52 9,838.48 9,667.99 429.93 149.94 2,458,419.04 344,597.63 8.00 455.26 End Dir :10032'MD,9838.48'TVD 10,100.00 68.56 20.52 9,863.33 9,692.84 489.21 172.13 2,458,478.02 344,620.60 0.00 518.55 10,200.00 68.56 20.52 9,899.88 9,729.39 576.38 204.77 2,458,564.75 344,654.39 0.00 611.63 10,300.00 68.56 20.52 9,936.43 9,765.94 663.56 237.41 2,458,651.49 344,688.17 0.00 704.71 10,400.00 68.56 20.52 9,972.98 9,802.49 750.73 270.04 2,458,738.22 344,721.96 0.00 797.79 ' 10,500.00 68.56 20.52 10,009.52 9,839.03 837.90 302.68 2,458,824.96 344,755.74 0.00 890.88 10,600.00 68.56 20.52 10,046.07 9,875.58 925.08 335.31 2,458,911.69 344,789.53 0.00 983.96 10,700.00 68.56 20.52 10,082.62 9,912.13 1,012.25 367.95 2,458,998.42 344,823.32 0.00 1,077.04 10,800.00 68.56 20.52 10,119.17 9,948.68 1,099.42 400.59 2,459,085.16 344,857.10 0.00 1,170.12 10,900.00 68.56 20.52 10,155.72 9,985.23 1,186.60 433.22 2,459,171.89 344,890.89 0.00 1,263.20 11,000.00 68.56 20.52 10,192.26 10,021.77 1,273.77 465.86 2,459,258.62 344,924.68 0.00 1,356.28 11,058.08 68.56 20.52 10,213.49 10,043.00 1,324.40 484.81 2,459,309.00 344,944.30 0.00 1,410.34 SR_G2ST 11,100.00 68.56 20.52 10,228.81 10,058.32 1,360.94 498.49 2,459,345.36 344,958.46 0.00 1,449.36 11,200.00 68.56 20.52 10,265.36 10,094.87 1,448.12 531.13 2,459,432.09 344,992.25 0.00 1,542.44 11,235.35 68.56 20.52 10,278.28 10,107.79 1,478.93 542.67 2,459,462.75 345,004.19 0.00 1,575.35 SCU 31-04 SR_H1ST Tgt 1 11,296.12 68.56 20.52 10,300.49 10,130.00 1,531.91 562.50 2,459,515.46 345,024.72 0.00 1,631.91 SR_H1ST 11,300.00 68.56 20.52 10,301.91 10,131.42 1,535.29 563.76 2,459,518.83 345,026.03 0.00 1,635.52 11,393.72 68.56 20.52 10,336.16 10,165.67 1,616.99 594.35 2,459,600.11 345,057.70 0.00 1,722.76 Start Dir 6°/100': 11393.72'MD,10336.16'TVD 11,400.00 68.19 20.52 10,338.47 10,167.98 1,622.46 596.40 2,459,605.55 345,059.82 6.00 1,728.60 11,500.00 62.19 20.52 10,380.42 10,209.93 1,707.42 628.21 2,459,690.09 345,092.75 6.00 1,819.32 11,600.00 56.19 20.52 10,431.62 10,261.13 1,787.82 658.30 2,459,770.08 345,123.90 6.00 1,905.17 11,634.76 54.10 20.52 10,451.49 10,281.00 1,814.53 668.30 2,459,796.66 345,134.26 6.00 1,933.69 SR_H5ST 11,700.00 50.19 20.52 10,491.52 10,321.03 1,862.76 686.36 2,459,844.65 345,152.95 6.00 1,985.19 6/16/2014 11:48:16AM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTD1J Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Company: Hilcorp Energy Company TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1E Project: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1E Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 323-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan SCU 31-04 Design: SCU 31-04 WP2.0 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) 10,379.00 11,786.01 45.03 20.52 10,549.49 10,379.00 1,922.23 708.62 2,459,903.82 345,175.99 6.00 2,048.69 SR_H7ST 11,786.44 45.00 20.52 10,549.79 10,379.30 1,922.51 708.72 2,459,904.10 345,176.10 5.95 2,048.99 End Dir :11786.44'MD,10549.79'TVD-SCU 31-04 SR_H7ST Tgt 2 11,800.00 45.00 20.52 10,559.38 10,388.89 1,931.50 712.08 2,459,913.04 345,179.58 0.00 2,058.58 11,852.48 45.00 20.52 10,596.49 10,426.00 1,966.25 725.09 2,459,947.62 345,193.05 0.00 2,095.69 SR_H8ST 11,900.00 45.00 20.52 10,630.09 10,459.60 1,997.72 736.87 2,459,978.93 345,205.24 0.00 2,129.29 11,935.33 45.00 20.52 10,655.07 10,484.58 2,021.12 745.63 2,460,002.21 345,214.31 0.00 2,154.27 SCU 31-04 BHL Tgt 11,999.99 45.00 20.52 10,700.80 10,530.31 2,063.94 761.65 2,460,044.81 345,230.90 0.00 2,199.99 Total Depth:12000'MD,10700.8'TVD-BHL Lgl Coords:1149 FNL 2385 FEL Sec 4 T7N R9W SM AK 12,000.00 45.00 20.52 10,700.80 10,530.31 2,063.94 761.66 2,460,044.82 345,230.90 0.00 2,200.00 4 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) SCU 31-04 SR HIST Tgt 1 0.00 0.00 10,300.19 1,476.73 524.00 2,459,460.80 344,985.50 -plan misses target center by 28.87usft at 11235.35usft MD(10278.28 TVD, 1478.93 N,542.67 E) -Point SCU 31-04 SR_H7ST Tgt 2 0.00 0.00 10,549.79 1,922.51 708.72 2,459,904.10 345,176.10 -plan hits target center -Circle(radius 300.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 12,000.00 10,702.73 41/2" 4-1/2 6-1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (0) (0) 11,631.47 10,451.49 SR_H5ST 11,290.85 10,300.49 SR_HIST 11,052.81 10,213.49 SR_G2ST 11,849.76 10,596.49 SR_H8ST 11,783.28 10,549.49 SR_H7ST 6/16/2014 11:48:16AM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 323-04 Company: Hilcorp Energy Company TVD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1E Project: Soldotna CK Unit MD Reference: SCU 31-04 @ 170.49usft(GL@152.49'+Rig@1E Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 323-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan SCU 31-04 Design: SCU 31-04 WP2.0 Plan Annotations • Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 9,175.00 9,172.00 0.00 0.00 KOP Lgl Coords:2067 FSL 2130 FWL Sec 4 T7N R9W SM AK 9,175.00 9,172.00 0.00 0.00 KOP in 7 5/8"Csg;Start Dir 12°/100':9175'MD,9172'TVD:30°TF 9,195.00 9,191.99 0.78 0.00 End Dir :9195'MD,9191.99'TVD 9,215.00 9,211.95 1.97 0.00 Start Dir 8°/100':9215'MD,9211.95'TVD 10,032.00 9,838.48 429.93 149.94 End Dir : 10032'MD,9838.48'TVD 11,393.72 10,336.16 1,616.99 594.35 Start Dir 6°/100': 11393.72'MD, 10336.16'TVD 11,786.44 10,549.79 1,922.52 708.72 End Dir : 11786.44'MD, 10549.79'TVD 11,999.99 10,700.80 2,063.94 761.65 Total Depth: 12000'MD, 10700.8'TVD 11,999.99 10,700.80 2,063.94 761.65 BHL Lgl Coords: 1149 FNL 2385 FEL Sec 4 T7N R9W SM AK 6/16/2014 11:48:16AM Page 5 COMPASS 5000.1 Build 70 Z oN 0FL m a M3 2 SIM W FEa A QL L Ia N a E N a c In .4. 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Ct _- m W c2 0vt as I _ O 1 CZ o b - -o - N I- o N o Y Q g - R - o CO a -- - - - -- ,Ti 00 —o CL o i = N o R WO v c i c� N o c J co t I I I I i I 1 1 I l l l l I I I I I I I I I I I I I I I I I I I I I I 1 I I I I 0 J 0 O OLc-) N 0 N- u7 N 00 CO Qco R _ O co n O co N O ' ui ao oe uoi eieda I = /09 Z) i S Q U Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday, June 24, 2014 10:02 AM To: Davies, Stephen F (DOA); John Serbeck; Kevin Eastham Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA); Ferguson, Victoria L(DOA) Subject: RE: Digital Surveys for SCU 31-04 (SCU 22-04 ST) (PTD 214-090) Good Morning Steve. The High Pressure water has been mapped across the field so we have a general idea of where we will encounter the flow. The Top and Bottom were chosen by Kevin Eastham our geologist,and that's what the initials are on the geoprog. KRE_GRID is the map generated by Kevin. The KOP is chosen to be below the water sand so we do not have to fight it during our sidetrack operations.We have had pretty good success with this in the recent sidetracks we have done in swanson. In this case the KOP is ab 't 40' low the base of the high pressure water zone EXPECTED Formation FORMATION FLUID MD HP-H2Q KRE GRID 8920 BSE HP-H20 KRE GRID 9136 KOP KOP 9175 SR G2ST Hemlock Oil Oil 10879 SR HIST Hemlock Oil Oil/Gas 11101 SR H5ST Hemlock Oil Oil 11477 SRH7ST Hemlock Oil Oil 11647 SR H8ST Hemlock Oil Oil 11714 11800 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, June 23, 2014 12:53 PM To: Monty Myers Cc: Bettis, Patricia K (DOA); Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Subject: RE: Digital Surveys for SCU 31-04 (SCU 22-04 ST) (PTD 214-090) Monty, 1 Quick questions regarding the planned SCU 31-04 development gas well, which is a redrill of the existing SCU 22-04 well. I notice that the KOP will be at 9175' MD/9172'TVD. The geologic prognosis in the Permit to Drill application lists two markers that contain the characters "H2O KRE GRID" in their names listed at 8920' MD and 9136' MD. The left-hand portions of the names of these markers are truncated in the geologic prognosis. Could you please explain what these two markers represent? How far(in terms of TVD) will the base of the high-pressure Tyonek Water Sand be located above the KOP? How will Hilcorp be certain that the high-pressure Tyonek Water Sand will be isolated from the KOP? Thanks, Steve Davies AOGCC From: Monty Myers [mailto:mmyers@hilco p.com] Sent: Thursday, June 19, 2014 8:47 AM To: Davies, Stephen F (DOA) Subject: Digital Surveys for SCU 31-04 (SCU 22-04 ST) Good morning Steve! The PTD for SCU 31-04 was submitted recently and attached are the digital surveys for the well. If you need anything else please don't hesitate to give me a shout! Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 2 Bettis, Patricia K (DOA) From: Monty Myers [mmyers@hilcorp.com] Sent: Thursday, June 19, 2014 9:15 AM To: Bettis, Patricia K(DOA) Cc: Janise Barrett Subject: SCU 31-04: Permit to Drill Application Good morning Patricia! You have the correct well bore survey. A lot of times when we are planning the wells we will choose a nice round number to make a plan to. In this case 12000'was given to Halliburton by the geologist.After we get the plan built we then refine the depths as accurately as possible. The path would stay the same in either case, whether we stop drilling at 11936' or 12000'. According to the regulations we are allowed to drill 500' deeper without having to re-file the permit. I would say both are correct. We are only asking to drill to 11936' as per the permit, and the path to get there is the same as the one submitted. Let me know if this clarifies things? Thanks you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 Good afternoon Janise, On the Form 10-401, Box 6,the proposed depth is stated as 11,936' MD. The proposed Halliburton wellbore survey shows the total depth for the well as 12,000' MD (10,700.80'TVD). Do I have the correct wellbore survey or is the depth on the Form 10-401 incorrect? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, June 17, 2014 4:43 PM To: 'Janise Barrett' Subject: SCU 31-04: Permit to Drill Application Good afternoon Janise, On the Form 10-401, Box 6, the proposed depth is stated as 11,936' MD. The proposed Halliburton wellbore survey shows the total depth for the well as 12,000' MD (10,700.80'TVD). Do I have the correct wellbore survey or is the depth on the Form 10-401 incorrect? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 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 WELL NAME: Cl—0‘71 PTD: CJ/CJ Development Service _Exploratory _Stratigraphic Test _Non-Conventional FIELD: e�tX-e� �'�` L e"--t POOL: // b1Dc_h �' / 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 specifyty pes of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 f ❑❑ ToN C 0 N rn a) 0 L (0 — 7 N C Q o -o o = 0 `2 w E (O a 0) O .0 e E a C, U a) ,a2 t0 O O C .7 O O m coca -00 gI CD> r N- O .o .c 'O .0 rn •- W rn U c m 0 rn > c 3 as a c O co -c — 0 �' � o: N _ca E O < a) 3 3 C 0 a 4.4 �, 0 0 E rn a) 3 = Y. `0) ° W a`) - c o E v 45 a , p N LL O> 0) C a) •O a) N C, , 0- it Cl) 0) y O - 0 -O LE L, C, , 45 co > , to o 3 p 3 3 m: a) CC; .o w, , O 0 C r 14- y n N N. 4 C. .co y, c n p 7 co 3. °' G 0. °: 3 0 1i co aO1i ami - e) 1 CO. aa) a) c Co U cn O c 3 E ,n E m: �, a°i 3 Y o n o ui N 0 0 p) O Y C O i d a3 co V O. "� O Of L . .C. W 4 M _ O C D. 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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. Hilcorp Alaska, LLC Swanson River Field SCU 31-04 FINAL WELL REPORT DML LOGGING DATA Provided by: Approved by: John Serbeck Compiled by: Craig Silva Omar Hinostroza Distribution: 9/12/2014 TD Date: August 14, 2014 SCU 31-04 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Well Synopsis .................................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................9 3.1 Lithostratigraphy .............................................................................................................................9 3.2 Lithologic Details...........................................................................................................................10 3.3 Connection Gases ........................................................................................................................14 3.4 Trip Gases ....................................................................................................................................14 3.5 Sampling Program / Sample Dispatch..........................................................................................15 4 DRILLING DATA..................................................................................................................................16 4.1 Directional Survey Data................................................................................................................16 4.2 Bit Record.....................................................................................................................................19 4.3 Mud Record ..................................................................................................................................19 5 SHOW REPORTS ...............................................................................................................................21 6 DAILY REPORTS ................................................................................................................................22 Enclosures: 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD SCU 31-04 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Mudlogging Unit Computer System Canrig: 3 HP Compaq Workstations (DML, RigWatch, and Sample Catcher) 0 Ditch Gas Canrig: (2) QGM Gas Traps (with High RPM Electric-Powered Agitators) Canrig: E-Series FID THA Analysis and Chromatography. 0 Pason EDR All Drilling Parameters 0 Block Height / Depth Pason WITS Feed 0 Hookload / WOB Pason WITS Feed 0 RPM Pason WITS Feed 0 Torque Pason WITS Feed 0 Return Flow Pason WITS Feed 0 Pit Volumes Pason WITS Feed 0 Mud Gain/Loss Pason WITS Feed 0 Pump Pressure Pason WITS Feed 0 Pump Strokes Pason WITS Feed 0 Rate of Penetration Calculated from Block Position tracking 0 Mud Flow In Calculated from Pump Output/Rate tracking 0 1.2 Crew Unit Number : ML030 Unit Type : Arctic Steel Skid Unit SCU 31-04 PB1 Mudloggers Years*1 Days*2 Sample Catchers Years*1 Days*2 Technician Days James Adams 1 11 Justin Boutte 5 10 Dylan Muller 3 11 Seth Nolan 2 5 Trey Thrailkill 2 6 SCU 31-04 Mudloggers Years*1 Days*2 Sample Catchers Years *1 Days*2 Technician Days Robert Silva 35 11 Dean Kekaualua 2 13 Omar Hinostroza 6 17 Justin Boutte 2 13 *1 Years experience as Mudlogger. *2 Days at well site. SCU 31-04 3 2 WELL DETAILS 2.1 Well Summary Well Name: SCU 31-04 Operator Name: Hilcorp Alaska, LLC. Type of Work: Redrill / Recomplete Rig Name / Type: Saxon 169 / Land / Double Well Classification: Development Oil Spud Date // TD Date: 08/08/2014 // 08/14/2014 Field / Pool: Swanson River / Hemlock Drilling Days: 7 Borough / State: Kenai Borough / Alaska Total Depth: 11775’ MD / 10635.82’ TVD API Number: 50-133-10106-02-00 Total Subsea Depth: 10465.33’ SSTVD Permit to Drill: 214090 TD Formation: Hemlock Lease Number: AKA028997 Primary Target/ Depth: Hemlock H1 / 11114’ Surface Location: 2072’ FSL, 2126’ FWL, SEC 4 T7N R9W SM Secondary Targets: Depths: Hemlock H2, H3, H5, H6 11218’,11239’,11430’,11614’ Ground Elevation: 152.49’ AMSL Mud Engineering Halliburton Baroid RT Elevation: 170.49’ AMSL Directional Drilling Halliburton Sperry Drilling Completion Status: Set 5 1/2” Production Liner MWD/LWD Services: Halliburton Sperry Drilling 2.2 Hole Data Hole Section Dia ( “ ) Depth MD (ft) Depth TVDSS (ft) TD Fm. Mud Wt (ppg) Dev. (o inc) Csg/ Liner Dia (“) Shoe Depth MD (ft) Shoe Depth TVDSS (ft) FIT (ppg) 6.125” 11775 10465.33 Hemlock 10.90 59.77 5.500 11773 10464.32 n/a 2.3 Well Synopsis SCU 31 – 04 is a development oil well planned to be re-drilled in a North Easterly direction from SCU 22 -04 utilizing the existing casing program down to 9175’MD/9172’TVD. At 9175’MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 2811’ X 6-1/8” open hole section is planned. A 4-1 /2” 12.6# L-80 DWC/C production liner will be run, cemented and perforated (TCP) 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 July 15th, 2014. All waste and 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. SCU 31-04 4 2.4 Daily Activity Summary SCU 31-04 PB1 - Wellbore July 18, 2014: Continued RIH picking up DP F/2,696'-T/9,162' (tagged CIBP). Displaced wellbore from produced water to 9.5 ppg 6% KCl/PHPA drilling mud. Tested casing to 2500 psi for 30 minutes – good. TOOH to surface, P/U and orient whipstock and RIH. July 19, 2014: RIH with whipstock and mill bit. Set whipstock and began milling window at 9123’. Continue to mill window. July 20, 2014: Finished milling window, drilled 20’ new formation. Pumped hi viscosity sweep, no increase in cuttings. Performed FIT to 11.5 ppg, EMW was good. TOOH to surface lay down milling assembly, picked up directional tools. RIH to 7165’. July 21, 2014 Continued RIH to 9154’. Rig up wireline/gyro to orient motor until departure achieved. Rig down wire line and began drilling ahead. Drilling ahead to 9582’ at 2359 HRS. . July 22, 2014 Continued to drill ahead to 9591' flow check. Drilled to 9615' pumped Hi-Vis sweep and weighted up to 9.7ppg. Flow checked at 9806' well flowing, weighted up to 9.9ppg. Drilled to 9868' and flow checked (well flowing) weight up to 10.1ppg. Drilled to 9993', flow checked well still flowing, weighted up to 10.3ppg. Pumped Hi-Vis sweep at 10034'. Continue to drill ahead at time of report. July 23, 2014 Continued to drill ahead. Flow check during connection at 10, 180’: 20 bbls/hour flow. Gaining7-8 barrels while drilling/pumping. Flow check during connection at 10, 273’: 20 bbls/hour flow. Weighted up mud to 10.7 ppg and flow checked at 10,490’. Flow was 20 bph. Continued drilling ahead; no gains while pumping. Flow checked well at 10,644’; flowing at 15 bph. Pumped 36 bbls 11.3 ppg pill, weighted up with BARCARBS and chased to balance below window. Flow checked at 10 bph. TOH 10 stands. July 24, 2014 Continued drilling ahead from 10,973’ with a slight increase while drilling and 18 bph flow while static. Pumped a 15 bbl high viscosity sweep at 11359 with no increase in cuttings. Continued drilling ahead, 15- 20 bph flow on connections, no increase in volume while drilling. Drilling ahead at time of report at 11549'. July 25, 2014 Continued drilling ahead from 11549’. Flow check on connection at 20 bph, no increase in volume when drilling. Pumped high viscosity sweep at 11669’ with no increase in cuttings. Continued drilling ahead to 11967 and lost all returns. Pumped 15 bbl LCM pill at 40 ppb BARACARBs. Pump out of the hole to 11787’ and pumped 20 bbl LCM pill at 50 ppb BARACARBs. Tripped out of the hole on elevators to window to build more mud volume. July 26, 2014 Continue trip in the hole to 9105’, pumped remaining mud and 200 bbl, 50 ppb BARACARB pill down SCU 31-04 5 backside while tripping in. Built new mud volume with 50 ppb background BARACARBs (5, 25, 50). Added 162 bbl to annulus while building mud with no mud on backside. Mixed a total of 995 bbl and began trip in the hole. Drill string became stuck at 11865’. Began pumping and achieved as high as 20% flow rate but still losing 1668 bbl/hour while pumping at 4 bbl minute. Brought pump rate down to 3 bbl a minute and losses declined to 80 bbls/hour. Continued to work pipe and spotted a 6% NXS lube pill across open hole. July 27, 2014 Continued circulating well at 3 bpm and working pipe. Flow checked well at 100 bph. Pumped 40 bbl, 10 ppg cap pill, and chased to above window in annulus. Initial flow check was 50-80 bph, slowed to 10 bph. Began RIH with E-Line to free point, determined stuck at 9995’. POOH with E-Line and RIH with charges. Backed off at 9958 and pipe free. Rigged down wireline equipment. Circulated surface to surface and dumped 132 bbl water. Lots of coal at BU: mostly peas sized but a wide range from small grains to half dollar size. Flow checked well for 5 minutes on trip tank; well flowing at 97 bph. July 28, 2014: Continue TOH to surface. Picked up screw-in sub, jars & 4-3/4" collars to try to screw into fish, began running in hole. At 7,474', lost returns while RIH slowly. Up until 7,474', mud displacement was only 4.3 bbl over calculated. RIH T/TOW and established circulation while slipping and cutting drill line. RIH T/ 9,520’, CBU. RIH T/ 9,952' washed down last stand and screwed into fish. Pumped hi-vis sweep, 10% increase in cuttings (mostly fines and some small coal). Canrig Mudloggers - Released 7/26/2014 – Recalled 8/5/2014 to drill sidetrack. SCU 31-04 - Wellbore 8/08/2014: Finish running in hole with drill pipe out of derrick to 9060’. Wash down from 9,060' to 9,408', reaming as needed through ledges at 9,210’, 9,285’, 9,334’, and 9,370’. Trench hole from 9,408' to 9,438' (at 85-90º R). Start time drilling 6 1/8” hole from 9438’ and officially spud well. Ease off plug sliding at 9438’ (with 85 R toolface) at 2 ft/hr and 90% cement in cuttings. Increase WOB at 9443’ to 5k. Observe increased ROP to 6 ft/hr. Cement in samples is 80% at 9450’ and decreases to 30-40% at 9466’. Continue time drilling to 9482’, where survey indicates failure to build inclination. Notify drilling engineer and decisions made to trench to low side. Pick up and orient low side and trench from 9450’ to 9482’. Continue time drilling from 9482' to 9488' at 1-2 ft/hr at 160º R. Continue time drilling from 9,488' to 9494' at 1 ft/hr at 135º R. Cement in samples increases to 50-60% cement at 9488’, and then decreases to 30- 40% at 9490’ and 25% at 9490’. Continue. time drilling from 9494' to 9,495' at 2 ft/hr at 135º R. 8/09/2014: Continue time drilling from 9495' to 9,499' at 2 ft/hr at 135º R. Cement in samples decrease to 20% cement at 9498’. Continue time drilling from 9499' to 9,500' at 3 ft/hr at 135 º R. Cement in samples increase to 30% at 9500’. Continue time drilling from 9500' to 9,505' at 1 ft/hr at 160º R. Cement in samples increase to 80% at 9503’ and then decrease to 40% at 9505’. Pump around Hi-Vis sweep at 9505’ with very little increase in cuttings. Continue time drilling and sliding from 9505' to 9,518'. Cement in samples decrease to 10% at 9511’, and then the samples become 100% formation (of almost all ashy sandstone) by 9516’. Observed 100psi increase in differential pressure and 1.5º difference in inclination versus other leg at 9518’. Notified Drilling Manager and Engineer of parameters. Decision made to drill ahead as planned. Continue drilling (sliding and rotating) 6 1/8" hole from 9518' to 9620’. Check for flow (well flowing at 2.5 bph). Continue drilling (sliding and rotating) 6 1/8" hole from 9620' to 9785’. (Slide entire stand from 9721' to 9785’). Well flowing at connection at 9 bph. 8/10/2014: Continue drilling from 9785' to 9867' (sliding the entire stand). Service rig. Grease drawworks, top drive and blocks. Inspect and test crown saver actuator. Continue drilling from 9867' to 9918' (sliding the whole way). Check for flow (well flowing at 7 bph). Pull off bottom and pump around Hi- Vis sweep while rotating and reciprocating. Note 25% increase in cuttings with sweep to surface. Continue drilling from 9918' to 10026' in extended build section (sliding nearly the whole way). SCU 31-04 6 8/11/2014: Continue drilling from 10026' to 10060' (total slide time 54.45 hrs, rotating 0.93 hrs). Check for flow (well flowing at 6 bph). Continue drilling from 10060' to 10464' (all sliding). Check for flow (well flowing at 6 bph). Continue drilling from 10464' to 10605' (rotating). 8/12/2014: Continue drilling (rotating) from 10605' to 10613' (total sliding 61.06 hrs, rotating 10.17 hrs). Check for flow (well flowing at 9 bph). Pump Hi-Vis with nut plug sweep around to clean up wellbore. Rotating and reciprocate from 10,551' to 10,601' (top 50' of stand). Note 50% increase in cuttings on return of sweep. Pull out of hole from 10613' to 9115' (above 7 5/8” casing window). (Note: tight spots of 20-30k over at 10390’, 9851’, 9840’, 9812’, 9805’; able to pump through without issues; at 9230' rotated and pumped for 5' that acted like chunky cement). Cut and slip 95' of drill line. Observe well flowing at 9 bph. Service rig. Change oil in Allison transmission. Grease crown, drawworks, top drive and blocks. Run back in hole from 9115’ with no issue exiting 7 5/8" casing window at 9157'. Singled back in hole 4 joints and then tripped back in from derrick to tight hole at 9358'. Make up topdrive. Wash and ream through tight spot and then, without pumping or rotating, work through one more time with no problems. Continue running in hole from 9358’ to tight spot at 10081’. Make up topdrive. Wash down through tight spot to 10115’ and then, without pumping or rotating, work through two more times with no problems. Continue running in hole to 10551’. Wash down last stand of drill pipe from 10551’ to 10613’ (with 3’ of fill on bottom). Pump 20 bbl Hi-Vis sweep and work string while pumping around. At bottoms up, recorded 1037 units of wiper gas and dumped 17 bbls of (9.8 ppg) watered back mud. Continue drilling 6 1/8" hole from 10613' to 10946' (rotating). Begin control drilling at 50 to 55 ft/hr to allow adequate sampling by mudloggers. Circulate around Hi-Vis sweep and note 25% increase in cuttings (mostly fine sand) at surface. Continue drilling from 10946’ to 11020’ (rotating and sliding). Work through tight hole at 11020'. Pump 15 bbl Hi-Vis sweep and work pipe. Continue drilling (rotating) from 11020' to 11055’. 8/13/2014: Continue drilling (rotating) from 11055' to 11170'. Pump 20 bbl Hi-Vis sweep around to clean hole for short trip. Note no increase in cuttings at shakers. Pull out of hole from 11,170' to 10,552' on elevators with no problems. Run back in hole to 11,108' on elevators with no problems. Make up topdrive and wash last stand down from 11108’ to 11170’ with no fill on bottom. Pump 20 bbl Hi-Vis sweep and work string while filling pipe. Record 1047 units of wiper gas just prior to bottoms up. Continue circulating and observe gas dropping to 180 units in next 10 minutes. Continue drilling (rotating) 6 1/8" hole from 11170' to 11519’. 8/14/2014: Continue drilling (rotating) from 11519’ to 11700’. Stop drilling ahead at 11,700', but continue to circulate, rotate and reciprocate while notifying geologist and waiting for verification of total depth. Pump and circulate around 15 bbl Hi-Vis sweep. Decision made by geologist to drill and additional 75’. Continue drilling (rotating) from 11700’ to Total Measured Depth of 11775’. Circulate bottoms up and continue to circulate and clean hole. Begin pulling out of hole from 11,775'. Pumped and rotated out from 11,775' up to 11,478'. At 11,478' had to pump and rotate to break loose from tight spot, and then continued to pull with no rotation to 11,250'. At 11,250', again had to pump and rotate to break loose, and then continued to pull out with no pump and no rotation up to 10,969'. From 10,969' pulled out of hole with elevators to 9120’ and, other than some minor overpull getting the flex collars through the 7 5/8” window, experienced no significant problems. (Made up topdrive and rotated at 10rpm with idle pump while pulling collars through the window). Check flow (well flowing at 5 bph). Perform BOP and fire drills. Service rig and topdrive. Check oil levels in mud pumps, draw-works motor and generator sets. Check flow (well flowing at 6 bph). Run back in hole from 9120' and reach 9623', before well operations discussion with Drilling Engineer and subsequent updated decision to pull out of hole and lay down Directional and LWD assembly. Pull out of hole from 9623’ to 9120’, rotating one stand of flex collars at 10rpm to get back through 7 5/8" casing window. Monitor well at 9120’ while building a 35 bbl 13 ppg pill to spot in the casing as a weighted cap. Check flow (well flowing at 4 bph). Pump and spot 35 bbl weighted pill in casing, leaving 18 bbls in drill string. Pull out of hole from 9120'. 8/15/2014: Finish pulling out of hole from 9120', rack back HWDP and jars. Down load MWD, break off bit, lay down motor and MWD tools. Bit had no plugged jets and was graded at 2-5-BT-G-X-I-WT-TD. Clear and clean rig floor. Rig up test manifold and pump. Flush BOP stack. Pull wear ring. Install test plug. Purge air from stack, choke line and choke manifold. Install test joint. Perform shell test on stack. SCU 31-04 7 AOGCC Representative John Crisp on location to witness BOP test. Release sample catchers. Deliver samples to FedEx for shipping. Perform bi-weekly BOPE test at 250psi Low/2500psi High on annular and 250psi Low/2500psi High on all other BOPE at 10 minute intervals. Had initial failure on choke side HCR and CMV #9. Functioned HCR and re-test passed. Attempted to replace gate seals in CMV #9, and eventually changed out valve completely. Performed shell test on newly made up and resealed CMV and flange. Shell test passed, and then performed successful full test. Gas detection equipment passed all tests by Total Safety. Perform successful accumulator drawdown test. Schlumberger arrived on location and loaded the silo with 430 sx (90 bbls) of cement and spotted their batch mixer. Note that a 76 bbl gain from the annulus was recorded during the last 12 hours. Rig crew installed the wear ring during the test on CMV #9, and staged the bit and float sub on the rig floor in preparation for running in the hole. Service rig and topdrive. Rig down testing equipment and blow down choke. Pick up, make up and run in hole cleanout assembly (Smith 6 1/8" mill tooth bit jetted with 3 x 18's, bit sub with float, stabilizer, two flex DC's, HWDP, jars, HWDP) to 871’. Continue running in hole with drill pipe from 871’, filling pipe every 2500’. 8/16/2014: Continue running in hole to 7693', filling pipe every 2500'. At 7693' circulate out water from well bore. Dump 210 bbls water. Continue circulating until 11.0 ppg coming out. Check flow (well flowing at 10.2 bph). Record 339 units maximum gas. Continue running in hole from 7693' to 9115'. Circulate surface to surface. Returns changed from 11.0 ppg mud to water in a matter of minutes. Dump 70 bbls of water. Recorded 840 units maximum gas. Maintaining returns 10.8 ppg MW. Continue circulating at 9115' (just above casing window). Observe background gas decreasing from 52 units to 18 units. Check flow (well flowing at 8 bph). Single in 4 joints and exit through the 7 5/8” window into open hole without problems. Continue running in hole from derrick to tight hole spot at 9613’. Make up topdrive and wash and ream 20’ to 9633’. Continue running in hole and repeat same process at tight spots at 9830' and 9899'. Continue running in hole on elevators to 10320’. Make up topdrive and break circulation. While circulating at 10320’ recorded 1440 units of early trip gas. Wash and ream down remaining stands from 10320’ to bottom at 11775’. Pump 20 bbl hi-vis sweep as last single was being washed to bottom. Record 180 units of background gas. Observe 200% increase in cuttings (sand, fine coal and pea sized coal) with return of sweep to surface. Background gas dropped to 32 units. Release the two Sperry MWD representatives. Have Peak hands pre-construct containment and spot frack tank. Circulate hole clean and prep to pull out of hole. Rotate and pump out of hole from 11775’ to 11,030'. The hole immediately started sticking when not rotating or pumping. At 11,030' the pull on elevators was 200K up weight. Continue rest of the way out of hole on elevators. Stop and check for flow at 10,505' and observe no flow. Continue pulling out of hole to 9116' (just above 7 5/8" window) with only slight tight hole at 9332' and no problems. Check for flow and again observe no flow. Change crews. Slip and cut 150' of drill line with well on trip tank. Service rig. Run back in hole from 9115' to 9342'. Make up topdrive and ream from 9342’ to 9385’. Continue running in hole from 9385' to 10,800' on elevators. Fill pipe at 10,800' and then continue running in hole to 11547' on elevators. Makeup topdrive and wash and ream from 11547' to 11775'. Pump Hi-Vis sweep and circulate out. Record 772 units of wiper gas. Observe 30% increase in cuttings at return of sweep to surface. Check flow and observe well flowing at 3.5 bph. 8/17/2014: Cannot pull straight on elevators coming off bottom. Backream out of hole from 11775’ to 11458’. Pump 84 bbl Hi-Vis pill. Continue pulling out of hole on elevators from 11458’ to 9102’. (No problems pulling through window). Check flow and observe well flowing at 2.3 bph. Stage thread protectors and prep to lay down drill pipe. Pull and lay down 84 joints of 4 ½” drill pipe from 9102’ to 6510’. Monitor well at 6510’ while building a 30 bbl 13 ppg pill to spot in the casing as a weighted cap. Check flow and observe well flowing at 3.5 bph. Pump and spot 30 bbl weighted pill in casing. Pull full stands out of hole from 6510' to surface. Break and lay down clean out lower assembly. Clean and prep rig floor for running production liner. Rig up to run liner. Make up and run in hole 5 ½” production liner shoe tract (applying BakerLok on tract joints). Test floats. Continue running in hole 5 ½” production liner as per Hilcorp. 8/18/2014: Finish running in hole 5 ½” production liner as per Hilcorp. Cross over to 4 ½” drill pipe and continue running in hole to top of 7 5/8” window. Circulate surface to surface. Dump 145 bbls of mud diluted by water down to 9.1 ppg. Record maximum 749 units of gas. Condition drilling mud. Continue SCU 31-04 8 running in hole with production liner to 10401’. Circulate surface to surface. Dump 120 bbls of mud diluted by water down and gas cut to 8.3 ppg. Record maximum 1750 units of gas (highest gas recorded for all well operations). Condition drilling mud. Circulate gas down to 32 units. Continue running in hole with production liner to final set point at 11773’. Circulate, reciprocate pipe and condition mud for cement job. Record 653 units maximum gas and circulate down to 18 units. Prep, rig up and test cementing equipment. Build mud push. Hold pre-job meeting with all hands for cementing procedures. Line up Schlumberger cementers. Pump 15 bbls of 12.0 ppg mud push and follow with 85 bbls of 15.3 ppg cement. Drop dart and displace with 117.5 bbls produced water. Bump plug at landing collar at 162 bbls. Pump a total of 263 bbls (mud push, cement, displacement fluid). Circulate out approximately 10 bbls of mud push/cement and dump at shakers. Record 235 bbls of mud back from displacement at liner top. Circulate well clean. Pull out of hole with drill pipe. SCU 31-04 9 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops were provided by Hilcorp geologist John Serbeck. Projected Actual FORMATION MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Tyonek G1 - - - 10543 10091.63 9921.14 Tyonek G2 - 10213 10042.64 10862 10222.37 10051.88 Hemlock H1 - 10310 10139.51 11114 10328.52 10158.03 Hemlock H2 - - - 11218 10373.35 10202.86 Hemlock H3 - - - 11239 10382.56 10212.07 Hemlock H3 - - - 11395 10452.12 10281.63 Hemlock H5 - 10468 10297.51 11430 10468.16 10297.67 Hemlock H6 - - - 11614 10555.70 10385.21 Hemlock H7 - 10552 10381.51 11652 10574.36 10403.87 Hemlock H8 - 10598 10427.51 11722 10609.18 10438.69 SCU 31-04 10 3.2 Lithologic Details Tuffaceous Sandstone (9480'-9900') = Light gray to dominant medium light gray to medium gray; pervasive very faint yellowish gray to light brownish gray to light olive gray secondary hues; nearly all sandstone is matrix supported and most of the very ashy-very clayey sandstone is closely gradational to very sandy tuffaceous claystone or "ash-stone"; a significant component of the matrix material consists of very fine glass shards, while other very fine shards, previously winnowed from the original vitric ash, are a major fraction of the clastics; very fine upper to rare coarse lower and even larger; mostly moderately well to well sorted at fine lower to fine upper; abundant subtle micro-zoning, micro- layering; often displays diffuse lineations with increased black (darker) grains and/or pale reddish orange or pale greenish grains; “clayier” sandstone has partial soft clay-silt textures, and many cuttings pieces have "smushed" grains created by PDC Bit shearing; very ashy sublithic arenite to lithic quartz (silica) arenite; estimate 75-85% quartz, amorphous silica, crypto- silica and various undifferentiated silica; 5-10% feldspar, 10-20% lithics and mafic minerals; biotite and other micas, and probable augite are discernible, but all other mafics are undifferentiated; trace but distinctive reddish orange(volcanic) grains and variegated light green grains (greenstone meta-lithics); slightly calcareous. Tuffaceous Sandstone (9700'-9760') = Abundant loose grains; light gray; very fine to lower medium; ash matrix; friable;scattered loose angular sand grains; matrix supported; trace grain supported; moderate sphericity; angular to subangular; slightly calcareous. Coal (9500'-9900') = Black to brownish black; medium grade lignite to low grade bituminous; brittle and fragile to tough, to occasionally hard; very dominant irregular/hackly/flaky to platy cuttings habit, with minor blocky to splintery; smooth to very dense matte textures; dull to very dense earthy to minor resinous- vitreous lusters; no discernible cleating; dominant irregular to thin platy fracture; lesser blocky to sub- blocky, sub-conchoidal to conchoidal, and splintery fracture, and trace birdseye fracture; traces of vitreous dusky red and dark reddish yellow resinite (amber); abundant alternating micro-zoning of different coal grades; occasional coal micro-fractures filled with silica and/or calcite; some individual cuttings pieces display micro-thin interbedded coal and volcanic ash. Tuffaceous Claystone/Tuffaceous Siltstone/Volcanic Ash (9450'-10050') = Medium light gray to light gray to light brownish gray, with many secondary (mostly higher lightness value) gray, brown and light olive gray secondary hues; soft to slightly firm to slightly brittle; all local tuffaceous lithologies are directly derived from volcanic ash sources and then latently influenced by fluid transport and re-deposition; the exception is the specific log-indicated volcanic ash, which are air-fall deposits with minimal fluvial effects; all the tuffaceous mudrocks are closely gradational to each other and have many shared characteristics; soft to slightly firm or slightly brittle; hydrated soft rocks have poor adhesiveness and cohesiveness; clayey to silty to ashy to soft matte and various mixed textures; earthy to minor subwaxy to waxy (bentonite/smectite) lusters; occasionally soft glassy and/or gritty textures when larger shards are exposed; rare remnant vitriclastic textures are discernible in some the “fresher” volcanic ash cuttings fragments; massive to very thinly bedded; common cuttings pieces display overall homogeneous texture and gray/brown coloration, and also darker colored micro-thin laminae; abundant tuffaceous rocks have floating sand grains, and in part transition to very silty/clayey/ashy matrix supported sandstone; non to very slightly calcareous; only minor to rare cuttings pieces with micro-laminae or particles of coal and/or carbonaceous material; note traces of marginally hard calcite or silica-replaced tuff. SCU 31-04 11 Tuffaceous Sandstone (10050'-10300') = Light gray to dominant medium light gray to medium gray; abundant very faint yellowish gray to light brownish gray to light olive gray secondary hues; near 100% matrix supported and most is very ashy-very clayey sandstone that is closely gradational to very sandy tuffaceous claystone or "ash-stone"; a significant percentage of the matrix component is micro-fine glass shards, while a large percentage of the overall sandstone consists of fluvially distributed clastic glass shards (in the same and slightly larger size range as the matrix group); the clastic shards represent the bulk of the very fine grained sandstone; very fine upper to trace medium upper; rare larger grains, which range to granule (conglomerate), are mostly floating clasts in the soft clay-silt rocks; dominant moderately well to well sorted at very fine upper to fine upper; very homogeneous and massive-looking overall, but also very common subtle micro-zoning and thin layering; the zoning/layering indicates mix of massive sections and thin beds; note some rocks have very abundant diffuse lineations with increased black (darker) grains and/or pale reddish orange or pale greenish grains; “clayier” sandstone has partial soft clay-silt textures and many cuttings pieces have "smushed" grains; very ashy sublithic arenite to lithic quartz (silica) arenite; estimate 70-85% quartz, amorphous silica, various crypto-silica and undifferentiated silica; 5-10% feldspar, 10-20% lithics and mafic minerals; discernible biotite, muscovite mica and distinctive bronze-colored mica (possibly phlogopite), probable augite, other generally black mafics are undifferentiated; trace but distinctive reddish orange(volc) grains and well distributed trace of variegated green and light green greenstone metalithic grains; slightly calcareous. Tuffaceous Sandstone (10300'-10400') = all characteristics generally consistent with tuffaceous sandstone up section at 10050’-10300’; light gray to dominant medium light gray to medium gray; pervasive very faint yellowish gray to light brownish gray to light olive gray secondary hues; very fine upper to medium lower (and trace scattered grains in other size modes); rare coarse to granule size clasts floating in supporting mud rock; moderately well to well sorted at very fine upper to fine upper; near 100% matrix supported by volcanic ash and tuffaceous clay; note that the slightly calcareous sandstone does not have evident grain to grain cementation; generally equant grain dimensions, subrounded to subangular, subspherical to subdiscoidal; very ashy sublithic arenite to lithic quartz arenite. Sand/Tuffaceous Sandstone (10400'-10470') = Abundant loose grains; medium lower to very fine; light gray to medium light gray; spotty lithic fragments; some light greenish hues; angular to subangular; spotty vari-colored loose grains; tuffaceous ash/silt matrix; matrix supported. Tuffaceous Siltstone (10500'-10530') = Medium to light gray; some dark brownish hues; abundant cuttings display PDC bit metamorphism; irregular cuttings habit; dull to earthy to silty to waxy lusters; fine tuffaceous sandstone with very thin coal and carbonaceous laminations; variable silt fraction. Tuffaceous Sandstone (10560'-10600') = White to white gray to light gray; friable; fine grained; angular to subangular; low to moderate sphericity; dominant volcanic ash and minor tuffaceous clay/silt matrix support; moderately well sorted; spotty to locally common interbedded tuffaceous siltstone; trace coal. Tuffaceous Sandstone (10600'-10680') = Light gray to dominant medium light gray to medium gray; abundant very faint yellowish gray to light brownish gray to light olive gray secondary hues; near 100% matrix supported; very ashy- clayey sandstone closely gradational to very sandy "ash-stone"; glass shards are both matrix and clastic components; very fine lower to medium lower; trace scattered larger grains; moderately well sorted at very fine upper to fine upper; though very homogeneous and massive-looking overall, abundant thin diffuse zoning that displays lineations of distinctive black, pale reddish orange, and variegated green grains that are often “smushed” by PDC bit-cutter shearing; very ashy sublithic arenite to lithic quartz (silica) arenite; estimate 70-85% quartz, and various amorphous silica, crypto-silica and undifferentiated silica, 5-10% feldspar,10-20% lithics and mafic minerals. SCU 31-04 12 Tuffaceous Sandstone/Sand/Conglomeratic Sandstone (10680'-10760') = no significant change in overall characteristics from tuffaceous sandstone immediately up section, other than very slight overall coarsening of grain size, a significant increase in more strongly effervescent calcareous sandstone and greater disaggregation after hydration; note locally very common disaggregated sand grains that range from fine to spotty very coarse and granule (conglomerate); overall spotty/patchy to locally abundant dull to marginally bright yellow sample fluorescence; note that most of the dull background fluorescence is increased calcite, but the spotty brighter fluorescence appears to be oil; very faint to pale to trace marginally bright yellow cut fluorescence; dull yellow to moderately bright yellowish white residual ring fluorescence. Tuffaceous Siltstone/Tuffaceous Claystone (10760'-10830') = Medium light gray to light gray to light brownish gray, with many secondary gray, brown, and light olive gray secondary hues; soft to slightly firm to slightly firm or slightly brittle; massive and structureless; amorphous to subblocky; silty to clayey to ashy to soft matte textures; earthy luster; common carbonaceous micro-particles. Coal/Carbonaceous Shale (10830'-10860') = Massive section of mostly subbituminous coal, interbedded carbonaceous shale and variations of carbonaceous mudstone. Tuffaceous Sandstone/Sand/Conglomeratic Sand (10870'-10920') = Characteristics of sandstone and sand are consistent with minor show interval; fairly even dull to moderately bright yellow to yellowish white sample fluorescence; moderately translucent pale to marginally bright yellow cut fluorescence; instant very pale cut, which increases in intensity with time; bright white to yellowish white residual ring fluorescence with moderate to strong intensity; no visible staining or cuts in plain light; poor to moderate visible porosity due to matrix filling; no petroleum odor or pops from the drilling mud. Tuffaceous Sandstone/Conglomeratic Sand (10960'-10990') = continued poor show interval with no change in sand characteristics. Even dull to moderately bright yellow to white sample fluorescence; instant pale cut, which increases in intensity over time to marginally bright; moderate to strong intensity yellowish white to whitish yellow residual ring fluorescence; no visible cuts in plain light; poor visible porosity; no petroleum odor or pops from mud. Tuffaceous Siltstone/Tuffaceous Claystone (11020'-11050') = medium light gray to light gray to light brownish gray, with many secondary gray, brown and light olive gray secondary hues; soft to slightly firm or slightly brittle; massive and structure-less; amorphous to subblocky; silty to clayey to ashy to soft matte textures; earthy luster; common carbonaceous micro-particles. Tuffaceous Sandstone/Sand/Conglomeratic Sandstone (11070'-11110') = Light gray to medium light gray; common varicolored loose grains; trace large angular bit-broken coarse-conglomeratic fragments; dominantly lower to upper medium; volcanic ash and tuffaceous silt/clay matrix supported; low sphericity; poorly to moderately sorted; some thin interbedding with siltstone; even dull to moderately bright yellow to yellowish white sample flourescence; instant pale to marginally bright translucent yellow cut fluorescence with slightly increasing intensity over time; pale to moderately bright yellow to yellowish white residual ring fluorescence. Tuffaceous Sandstone/Sand (11140'-11165') = significant high quality oil show; abundant ash matrix; light gray to white; in part is sandy "ash-stone"; odd grain distribution with 3 distinct modes: 1)poorly sorted from fine upper to coarse upper, 2) fine only, with only minor transitioning to other grain sizes, and 3) very abundant very fine (fluvially-winnowed) clastic glass shards; note that the ash matrix is largely non- winnowed micro-shards and often displays trace residual vitric characteristics; angular to subangular, and discoidal to subdiscoidal; dominantly equant grain dimensions, but also abundant elongated; note minor mode of contrasting rounded, spherical grains; easily disaggregated; all ash appears non-devitrified; quartz arenite composition; 100% bright to very bright whitish yellow sample fluorescence; instant very bright bluish white cut fluorescence; very bright white residual ring fluorescence; all cuts are colorless, but suspect high-gravity oil. SCU 31-04 13 Tuffaceous Sandstone/Sand (11165'-11205') = continued same general characteristics from 11165', but matrix ash is slightly darker (lower lightness value) gray; sandstone texture appears slightly more homogeneous, with fewer angular grains, the overall matrix ash-clay is slightly more adhesive and sorting is slightly improved; sample fluorescence still 100% but color is more yellowish than whitish; instant cut fluorescence is no longer bluish white, but bright translucent white to yellowish white; bright yellowish white to white residual ring fluorescence. Tuffaceous Sandstone/Sand/Sandstone/Conglomeratic Sandstone (11240'-11340') = light gray to medium light gray; very abundant ash matrix supported; grades to very sandy ash-stone; very fine upper to fine upper; moderately well sorted overall; subangular to subrounded; local zones with interbeds of tuffaceous siltstone and other zones with very abundant volcanic ash; oil shows range from poor to fair; often near 100% sample fluorescence that ranges from dull to moderately bright yellow to whitish yellow; cut fluorescence is always instant and ranges from pale to marginally bright yellow to yellowish white to trace bright bluish yellowish white; dominantly bright yellowish white to white residual ring fluorescence. Tuffaceous Siltstone/Tuffaceous Claystone (11360'-11390') = medium light gray to light gray to light brownish gray, with many secondary gray, brown, and light olive gray secondary hues; soft to slightly firm or slightly brittle; massive and structureless; amorphous to subblocky habit; silty to clayey to ashy to soft matte textures; earthy luster; common carbonaceous micro-particles. Tuffaceous Sandstone/Conglomeratic Sand (11390'-11460') = continued show interval with no change in sand characteristics; even dull to moderately bright yellow to white sample fluorescence; instant pale cut fluorescence that gains moderate intensity over time; moderate to strong intensity yellowish white to whitish yellow residual ring fluorescence; no visible staining or cuts in plain light; poor to moderate visible porosity; no petroleum odor or pops from mud. Sand/Tuffaceous Sandstone (11490'-11520') = abundant loose grains; lower medium to very fine; light gray to medium light gray; trace to spotty lithic fragments, some with light greenish coloration; angular to subangular; trace vari-colored loose grains; volcanic ash/tuffaceous silt matrix supported. Tuffaceous Sandstone/Sand/Conglomeratic Sand (11550'-11605) = no significant change in overall characteristics of tuffaceous sandstone except for very slight overall coarsening and greater disaggregation of grains during hydration; note locally common disaggregated sand that ranges in size from fine to spotty very coarse and granule (conglomerate); overall spotty/patchy to locally abundant dull to marginally bright yellow sample fluorescence; some of the dull fluorescence is the presence of calcite, but all the brighter fluorescence is due to presence of oil; very faint to pale to trace marginally bright yellow cut fluorescence; dull yellow to moderately bright yellowish white residual ring fluorescence. Tuffaceous Sandstone/Sand/Conglomeratic Sand (11605'-11775') = light gray to medium light gray to localized very ashy white coloration with common faint pale yellowish gray secondary hues; size range from very fine lower to trace scattered very coarse and conglomerate fragments; dominantly fine, with localized shifts to near fine-medium boundary; also note very abundant volcanic ash-supported sandstone with very fine glass shards as both a matrix component and as winnowed clastics; sorting ranges from moderately well to poor (especially in basal zones); very angular to well rounded, but dominantly angular to subangular, sub-discoidal to sub-spherical, equant to elongate; most is slightly calcareous; note tuffaceous sandstone is often closely gradational to very sandy "ash-stone"; volcanic ash/tuffaceous clay- rich sublithic arenite to lithic quartz arenite to spotty quartz arenite; est 80-95% quartz and all other forms silica, trace-5% feldspar, trace-15% lithics and mafic minerals; note that nearly all of the volcanic ash appears non-devitrified; range from poor to fair shows; fair shows commonly display: 80-100% dull to moderately bright to spotty bright whitish yellow sample fluorescence; cut fluorescence is always instant, with wide range from pale to moderately bright to occasionally bright translucent yellow to yellowish white to white to trace bluish white; residual ring fluorescence ranges from very dull to very bright yellow to whitish yellow to slightly yellowish white to white. SCU 31-04 14 3.3 Connection Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) 9555 25 10735 71 9616 43 10797 125 9678 40 10860 71 9740 132 10922 169 9802 81 10983 139 9866 116 11046 143 9928 100 11108 145 9990 190 11170 Wiper Gas 1047 10052 80 11170 129 10114 33 11232 89 10177 202 11294 85 10240 152 11353 102 10302 152 11418 170 10364 60 11481 132 10427 77 11543 133 10488 187 11605 133 10551 119 11667 144 10613 Wiper Gas 1037 11728 77 10613 167 11759 123 10673 99 11775 Wiper Gas 772 3.4 Trip Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Trip to (feet) Maximum Gas (Units) Pumps Off Time (hours) Wiper Gas 10613 9109 1041 5.81 Wiper Gas 11170 10541 1057 1.08 Trip Gas 11775 Surface 1440 37.54 Wiper Gas 11775 9115 776 4.38 Trip Gas 11775 Surface 1750 30.05 SCU 31-04 15 3.5 Sampling Program / Sample Dispatch SCU 31- 04 PB1 - Wellbore Set Type / Purpose Frequency* Interval Dispatched to A, B Washed and dried reference samples 30 ft 10 ft 9180 ft – 10232 ft 10232 ft – 11967 ft Landon Ellison Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 (907) 777-8337 C Wet Samples 30 ft 10 ft 9180 ft – 10232 ft 10232 ft – 11967 ft Canrig New Iberia 1615 Jefferson Island Road New Iberia, LA 70560 Sample frequency may be locally altered according to drill rate constraints and zones of interest. SCU 31-04 - Wellbore Set Type / Purpose Frequency* Interval Dispatched to A, B Washed and Dried 30 ft 10 ft 9510’ – 10680’ 10680’ – 11775’ Landon Ellison Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 (907) 777-8337 Sample frequency may be locally altered according to drill rate constraints and zones of interest. Set Type / Purpose Frequency* Interval Dispatched to C Wet Samples 30’ Bottles 10’ W-Paks 9510’ – 10680’ 10680’ – 11775’ CANRIG Drilling Technology Ltd 1615 Jefferson Island Road New Iberia, LA 70560 Attn: Geoff Davison (337) 380-5298 Sample frequency may be locally altered according to drill rate constraints and zones of interest. SCU 31-04 16 4 DRILLING DATA 4.1 Directional Survey Data Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 8899.15 0.84 89.93 8898.36 42.24 20.11 46.76 0.23 8999.15 1.01 48.02 8998.35 42.83 21.50 47.86 0.68 9099.15 0.66 16.96 9098.34 43.97 22.33 49.24 0.56 9143.00 0.44 35.85 9142.19 44.35 22.50 49.65 0.64 9187.27 3.16 23.01 9186.43 45.61 23.07 51.04 6.17 9210.11 5.48 22.49 9209.20 47.20 23.74 52.76 10.16 9240.04 8.22 22.15 9238.92 50.50 25.09 56.33 9.16 9272.63 10.54 21.95 9271.07 55.43 27.08 61.64 7.12 9306.03 13.62 21.83 9303.72 61.91 29.69 68.62 9.22 9334.34 15.58 21.76 9331.12 68.54 32.34 75.75 6.92 9365.00 17.25 21.70 9360.53 76.58 35.55 84.41 5.45 9396.16 18.90 20.73 9390.15 85.60 39.04 94.07 5.38 9427.57 20.76 20.27 9419.70 95.58 42.77 104.71 5.94 9438.00 21.49 19.70 9429.42 99.11 44.05 108.46 7.27 9458.70 23.32 19.02 9448.56 106.56 46.67 116.33 8.93 9522.42 23.15 26.99 9507.13 129.65 56.47 141.41 4.94 9584.11 27.06 30.87 9562.98 152.50 69.18 167.45 6.88 9645.38 31.21 31.35 9616.49 178.03 84.59 197.02 6.78 9708.50 35.74 31.74 9669.13 207.69 102.81 231.49 7.19 9766.38 40.43 29.59 9714.67 238.41 120.98 266.92 8.42 9828.60 45.53 28.66 9760.18 275.46 141.60 309.13 8.26 9894.38 50.82 27.41 9804.03 318.72 164.61 357.99 8.17 9955.31 55.93 24.83 9840.37 362.62 186.10 406.82 9.05 10017.02 60.00 24.00 9873.10 410.25 207.71 459.12 6.69 10081.02 64.89 23.60 9902.70 462.15 230.60 515.84 7.65 10142.40 66.15 24.14 9928.13 513.23 253.20 571.70 2.21 10204.77 66.13 24.01 9953.36 565.31 276.48 628.74 0.19 10266.37 66.10 24.27 9978.30 616.70 299.51 685.07 0.38 10327.80 65.66 24.55 10003.4 667.76 322.68 741.13 0.84 10389.35 65.27 24.95 10028.97 718.61 346.12 797.11 0.87 10450.77 66.27 24.00 10054.18 769.58 369.32 853.11 2.16 10513.99 65.93 23.47 10079.79 822.49 392.58 910.91 0.94 10576.2 65.89 23.51 10105.18 874.58 415.22 967.70 0.09 10638.2 66.00 23.41 10130.45 926.51 437.76 1024.32 0.24 10700.22 65.82 23.17 10155.76 978.52 460.15 1080.93 0.46 10762.09 65.88 23.52 10181.08 1030.35 482.52 1137.39 0.53 10824.44 65.56 23.24 10206.71 1082.52 505.07 1194.22 0.66 10885.89 65.19 23.09 10232.32 1133.88 527.04 1250.08 0.63 10947.59 65.12 22.94 10258.24 1185.41 548.93 1306.07 0.25 SCU 31-04 17 11011.00 64.91 22.87 10285.02 1238.36 571.30 1363.54 0.35 SCU 31-04 18 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 11072.50 65.12 22.38 10311.00 1289.81 592.75 1419.27 0.80 11132.99 64.93 21.86 10336.54 1340.61 613.40 1474.09 0.84 11195.87 64.03 22.00 10363.63 1393.25 634.59 1530.81 1.46 11258.43 63.89 21.59 10391.09 1445.44 655.46 1586.98 0.64 11320.56 63.63 21.75 10418.57 1497.23 676.04 1642.68 0.48 11380.62 63.01 21.79 10445.53 1547.06 695.94 1696.31 1.03 11444.20 62.44 21.69 10474.67 1599.56 716.88 1752.79 0.91 11505.02 61.62 21.37 10503.19 1649.52 736.59 1806.47 1.43 11568.22 61.23 21.24 10533.42 1701.23 756.76 1861.92 0.64 11630.60 60.55 21.23 10563.77 1752.03 776.49 1916.38 1.09 11691.16 60.13 20.61 10593.74 1801.19 795.28 1968.94 1.13 11738.74 59.77 20.51 10617.56 1839.75 809.75 2010.06 0.78 * 11775.00 59.77 20.51 10635.82 1869.09 820.72 2041.35 0.01 * Projected SC U 3 1 - 0 4 19 4. 2 B i t R e c o r d SC U 3 1 - 0 4 P B 1 - W e l l b o r e Bi t Si z e ( “ ) Ty p e / Ma k e Se r i a l Nu m . Je t s / TF A De p t h In ( M D ) De p t h Ou t ( M D ) Fo o t a g e Dr i l l e d (f t ) Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (kl b s ) Av g . RP M Avg. PP (psi) Grade 1 6 . 1 2 5 ” HD B S / MM 5 5 12 4 8 4 8 0 7 5x 1 2 0. 5 5 2 2 91 7 8 ’ n / a 2 7 8 9 ’ n / a n / a n / a n / a n / a L o s t i n h o l e SC U 3 1 - 0 4 - W e l l b o r e Bi t Si z e ( “ ) Ty p e / Ma k e Se r i a l Nu m . Je t s / TF A De p t h In ( M D ) De p t h Ou t ( M D ) Fo o t a g e Dr i l l e d (f t ) Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (kl b s ) Av g . RP M Avg. PP (psi) Grade 3 6 . 1 2 5 PD C / HD B S M M 5 5 12 4 8 4 1 5 6 5x 1 2 / 0. 5 5 2 2 94 3 8 1 1 7 7 5 2 3 3 7 1 1 0 . 1 4 5 1 . 8 5 3 . 8 5 3 2 1 2 4 2-5-BT-G-X-I-WT-TD 3r r 1 6 . 1 2 5 Mi l l T o o t h / Sm i t h X R - P S P1 5 9 2 8 5x 1 8 / 0. 7 4 5 5 11 7 7 5 1 1 7 7 5 0 0 n / a n / a n / a n / a Clean-Out Run Only / 1-1-WT-A-E-I-NO-BHA 4. 3 Mu d R e c o r d SC U 3 1 - 0 4 P B 1 - W e l l b o r e Co n t r a c t o r : B a r o i d Mu d T y p e : K C l / P o l y m e r Da t e De p t h (f t ) M D MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Al k (P m ) Cl (mg/L) Ca (mg/L) 07 / 1 8 / 1 4 9 1 6 2 ’ 9 . 5 5 0 1 2 1 9 4 / 7 / 1 1 3 . 6 6 . 2 0 . 0 / 9 1 . 5 n / a 4 . 5 1 0 . 1 0 . 3 5 2 8 5 0 0 1 2 0 07 / 1 9 / 1 4 9 1 5 9 ’ 9 . 5 4 9 1 4 1 9 5 / 8 / 1 1 3 . 5 6 . 3 0 . 0 / 9 1 . 4 n / a 4 . 2 1 0 . 2 0 . 2 0 2 9 0 0 0 6 0 07 / 2 0 / 1 4 9 1 7 8 ’ 9 . 5 5 0 1 2 1 9 4 / 7 / 1 1 3 . 7 6 . 0 0 . 0 / 9 1 . 5 n / a 4 . 0 9 . 9 0 . 2 0 3 1 0 0 0 1 5 0 07 / 2 1 / 1 4 9 5 8 2 ’ 9 . 4 5 5 1 1 3 2 0 5 / 8 / 1 1 4 . 0 5 . 8 0 . 0 / 9 1 . 7 n / a 4 . 0 9 . 9 0 . 2 0 3 1 0 0 0 1 0 0 07 / 2 2 / 1 4 1 0 0 8 6 ’ 1 0 . 4 5 0 1 6 2 5 6 / 1 0 / 1 1 3 . 8 9 . 7 0 . 0 / 8 7 . 9 n / a 3 . 2 9 . 7 0 . 1 5 3 1 0 0 0 1 2 0 07 / 2 3 / 1 4 1 0 9 7 3 ’ 1 0 . 9 5 0 1 7 1 8 4 / 7 / 1 0 4 . 0 1 1 . 6 0 . 0 / 8 6 . 2 n / a 4 . 5 9 . 8 0 . 1 5 2 9 0 0 0 1 6 0 SC U 3 1 - 0 4 20 Da t e De p t h (f t ) M D MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Al k (P m ) Cl (mg/L) Ca (mg/L) 07 / 2 4 / 1 4 1 1 5 4 9 ’ 1 0 . 9 4 7 1 9 1 9 4 / 7 / 1 0 3 . 4 1 1 . 9 0 . 0 / 8 5 . 7 n / a 5 . 0 9 . 9 0 . 3 0 3 2 5 0 0 2 0 0 07 / 2 5 / 1 4 1 1 9 6 7 ’ 1 0 . 2 4 7 1 2 1 9 5 / 8 / 1 2 3 . 8 9 . 2 0 . 0 / 8 8 . 6 n / a 4 . 0 9 . 1 0 . 1 0 2 9 0 0 0 1 6 0 07 / 2 6 / 1 4 1 1 9 6 7 ’ 9 . 6 4 2 8 1 2 4 / 6 / 8 5 . 4 4 . 2 0 . 0 / 9 3 . 5 n / a n / a 8 . 8 0 . 1 0 2 8 5 0 0 8 0 07 / 2 7 / 1 4 1 1 9 6 7 ’ 9 . 5 5 4 3 8 1 4 6 / 8 / 1 1 6 . 3 5 . 5 0 . 0 / 9 2 . 2 n / a n / a 8 . 3 n / a 2 8 0 0 0 1 . 2 4 0 07 / 2 8 / 1 4 1 1 9 6 7 ’ 9 . 5 5 3 1 1 1 6 6 / 9 / 1 2 4 . 8 5 . 5 0 . 0 / 9 1 . 9 n / a n / a 8 . 1 n / a 3 3 0 0 0 6 0 0 SC U 3 1 - 0 4 - W e l l b o r e Co n t r a c t o r : H a l l i b u r t o n B a r o i d Mu d T y p e : K C L P o l y m e r Da t e De p t h (f t ) M D MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Al k (P m ) Cl (mg/L) Ca (mg/L) 8- 7 - 2 0 1 4 1 1 9 6 7 ’ 1 1 . 0 0 5 5 1 6 2 3 7 / 9 / 1 1 7 8 1 1 . 7 8 6 . 2 0 . 1 0 2 . 5 1 0 . 5 0 . 8 0 2 8 0 0 0 8 0 0 8- 8 - 2 0 1 4 1 1 9 6 7 ’ 1 1 . 0 0 5 0 1 6 2 3 7 / 9 / 1 1 1 0 0 1 0 . 7 8 7 . 0 0 . 1 0 2 . 5 1 0 . 5 0 . 8 0 3 0 0 0 0 4 8 0 8- 9 - 2 0 1 4 9 7 5 5 ’ 1 0 . 9 0 4 8 1 6 2 2 6 / 7 / 9 1 0 0 1 1 . 0 8 6 . 7 0 . 1 0 2 . 5 1 0 . 2 0 . 7 0 3 1 0 0 0 4 8 0 8- 1 0 - 2 0 1 4 1 0 0 1 1 ’ 1 0 . 9 0 4 5 1 5 2 1 6 / 7 / 9 1 0 0 1 0 . 7 8 6 . 6 0 . 1 0 2 . 0 1 0 . 2 0 . 5 5 3 3 0 0 0 2 0 0 0 8- 1 1 - 2 0 1 4 1 0 5 6 4 ’ 1 0 . 9 0 4 6 1 8 2 1 6 / 7 / 9 1 0 8 1 1 . 1 8 6 . 4 0 . 1 0 2 . 0 8 . 9 0 . 3 0 3 4 0 0 0 1 6 0 0 8- 1 2 - 2 0 1 4 1 1 0 1 9 ’ 1 0 . 9 0 4 8 1 7 2 2 6 / 8 / 1 0 1 0 7 1 1 . 3 8 6 . 4 0 . 1 0 2 . 5 9 . 5 0 . 7 0 3 0 0 0 0 1 2 0 8- 1 3 - 2 0 1 4 1 1 4 3 8 ’ 1 0 . 9 0 4 9 2 0 2 3 5 / 7 / 9 1 0 7 1 1 . 3 8 6 . 3 0 . 1 0 3 . 5 1 0 . 1 0 . 8 5 3 3 0 0 0 1 0 0 0 8- 1 4 - 2 0 1 4 1 1 7 7 5 1 1 . 1 0 5 3 1 9 2 0 5 / 7 / 9 1 0 5 1 2 . 3 8 5 . 4 0 . 1 0 3 . 0 8 . 9 0 . 6 0 3 1 0 0 0 1 0 0 0 8- 1 5 - 2 0 1 4 1 1 7 7 5 1 1 . 1 5 5 3 1 9 1 9 5 / 7 / 9 0 1 2 . 4 8 5 . 2 0 . 1 0 3 . 0 8 . 6 0 . 3 0 3 2 0 0 0 1 0 0 0 8- 1 6 - 2 0 1 4 1 1 7 7 5 1 1 . 1 5 4 6 1 5 1 8 5 / 7 / 9 9 2 1 2 . 1 8 5 . 6 0 . 1 0 3 . 0 9 . 3 0 . 3 0 3 1 0 0 0 8 0 0 8- 1 7 - 2 0 1 4 1 1 7 7 5 1 1 . 1 0 4 5 1 3 1 8 4 / 6 / 9 0 1 2 . 1 8 5 . 6 0 . 1 0 3 . 0 9 . 4 0 . 3 0 3 0 0 0 0 8 0 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s SCU 31-04 21 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:10862'MD 11114'MD Country:10222'TVD 10328'TVD Averages Before During After Maximum ROP (fph)51 41 34 73 WOB 15 10 14 32 RPM 225 81 101 225 Mud Weight 11 11 11 11 Chloride 34,000 33,000 30,000 34,000 Total Gas 13 34 26 62 C1 (ppm)2,400 4,648 1,890 20,969 C2 (ppm)83 581 394 3,585 C3 (ppm)25 552 335 3,514 C4 (ppm)- 437 235 2,437 C5 (ppm)- 193 178 1,267 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-100%Type instant Amount Amount None Distribution Even Intensity mod-strng Color Color None Intensity Moderate Color trnslu yel Residual Fluorescence Cut Color yel-yel wh Intesity Color None Color Oil Show Rating Free Oil in Mud Comments Report by: Saxon 169 Hilcorp Alaska, LLC 50-133-10106-02-00SCU 31-04 Sodotna Creek Unit 12-Aug-14 2:36 PM Mod-strng Kenai Borough Alaska USA Tuffaceous Sandstone/Sand/Conglomeratic Sandstone = light gray to medium light gray with pervasive very faint yellowish gray to light brownish gray and TR very faint light olive gray secondary hues; near 100% matrix supported; very ashy SS grades to very sandy tuffaceous claystone-"ash-stone"; major matrix component is micro-fine glass shards,and bulk of very fine clastics are fluvial-winnowed glass shards; very fine upper to fine upper to basal zone coarse to granule (conglomerate) grains/clasts; well sorted at vfU-fU to basal poor sorting; though homogeneous/massive-looking overall, note imperfect diffuse lineations of increased (PDC bit-"smushed") black, pale reddish orange, pale greenish grains; very ashy sublithic arenite to quartz arenite; est 75-90% quartz, amorphous silica and various crypto and undifferentiated silica; tr-10 feldspar, 5-20% lithics and mostly undifferentiated mafic minerals; discernible micas, augite, red volcanic grains, variegated greenstone metalithics; slightly calcareous. None Yel-yelsh wh Craig Silva, Omar Hinostroza Poor to moderate visible porosity overall (due to ash matrix volume), even though increasing disaggregated grains through show interval. Overall poor show. Patchy to fairly even dull to moderately bright yellow to yellowish white sample fluorescence; instant translucent pale to moderately bright yellow cut fluorescence that slightly increases in intensity with time; moderate to strong intensity bright white to yellowish white residual ring fluorescence; no staining or visible cuts in plain light; no visible oil, odor or pops from mud. 0.48 - 0.59 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11114 MD 11204 MD Country:10328 TVD 10367 TVD Averages Before During After Maximum ROP (fph)34 24 42 56 WOB 15 13 23 29 RPM 100 53 135 183 Mud Weight 11 11 11 11 Chloride 33,000 33,000 33,000 33,000 Total Gas 34 32 17 51 C1 (ppm)1,753 2,743 1,773 4,638 C2 (ppm)428 363 189 600 C3 (ppm)350 387 238 573 C4 (ppm)248 288 149 495 C5 (ppm)169 162 42 284 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 95-100%Type Instant Amount Amount None Distribution Even Intensity Strong Color Color None Intensity Strong Color Very bri Residual Fluorescence Cut Color Whitish yel bluish wh Intesity Color None Color Oil Show Rating Free Oil in Mud Comments Report by: Saxon 169 13-Aug-14 3:45 AM None Tuffaceous Sandstone/Sand/Conglomeratic Sandstone = Light gray to white overall; note many characteristics in common with tuffaceous sandstone in Report #1, but even more abundant ash matrix and closer to a sandy "ash-stone"; unsual grain distribution with three distinct size modes: 1) poorly sorted mostly angular grains from fine upper to coarse upper, 2) "less angular" fine only, with only minor transitioning to other grain sizes, and 3) very abundant very fine (fluvially-winnowed) clastic glass shards; ash matrix includes very abundant non-winnowed micro-shards and occasionally displays trace residual vitric characteristics; angular to subangular, and discoidal to subdiscoidal; dominant equant grains dimensions, but also abundant elongated and minor mode of contrasting rounded, spherical grains; easily disaggregated; all of the ash appears non-devitrified; quartz arenite; estimate 90-95% monocrystalline and polycrystalline quartz, amorphous glass (shards), undifferentiated silica. Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10106-02-00SCU 31-04 Sodotna Creek Unit Craig Silva, Omar Hinostroza Excellent to good show overall. Note 11140-11160: 100% bright to very bright whitish yellow sample fluorescence; instant very bright bluish white cut fluorescence; very strong very bright white residual ring fluorescence; all cuts in plain light are colorless, but possible high-gravity. After 11160: 100% bright yellow to whitish yellow sample fluorescence; instant bright yellowish white to white cut fluorescence; strong bright yellowish white to white residual ring fluorescence; no visible staining or cuts in plain light; no visible oil, odor or pops from the mud. 3.25 - 2.25 V bri whi None Strong Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11218 MD 11234 MD Country:10373'TVD 10380 TVD Averages Before During After Maximum ROP (fph)24 43 32 53 WOB 19 23 12 25 RPM 53 135 91 183 Mud Weight 11 11 11 11 Chloride 33,000 33,000 33,000 33,000 Total Gas 32 25 15 33 C1 (ppm)2,743 2,635 1,955 3,830 C2 (ppm)363 452 112 289 C3 (ppm)386 303 121 372 C4 (ppm)288 200 88 247 C5 (ppm)162 74 43 97 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 80%Type Instant Amount Amount None Distribution Even Intensity Mod Color Color None Intensity Moderate Color Mbri yel-Residual Fluorescence Cut Color Yel-whtsh yel whsh yel Intesity Color None Color Oil Show Rating Free Oil in Mud Comments Report by: Hilcorp Alaska, LLC 50-133-10106-02-00SCU 31-04 Sodotna Creek Unit Craig Silva, Omar Hinostroza Poor to marginally fair show overall. 80% even marginally bright to moderately bright yellow to slightly yellowish white sample fluorescence; instant translucent moderate strength moderately bright whitish yellow cut fluorescence; moderately strong bright yellowish white residual ring fluorescence; no staining or cuts in plain light; no visible oil, odor or pops in the mud. 1.32 13-Aug-14 11:24 AM none Kenai Borough Alaska USA Saxon 169 Tuffaceous Sandstone = light gray with pervasive very faint yellowish gray secondary hue; 100% matrix supported; continued very ashy SS grading to very sandy tuffaceous "ash-stone", matrix component of micro-fine glass shards,and bulk of very fine clastics are fluvial-winnowed glass shards; very fine upper to fine upper; mostly well sorted; homogeneous/massive-looking; very ashy sublithic arenite to quartz arenite; est 80-90% quartz, amorphous silica and various crypto and undifferentiated silica; tr-10% feldspar, 5-15% lithics and mostly undifferentiated mafic minerals; discernible micas, augite, red to reddish orange volcanic grains and variegated greenstone metalithics; slightly calcareous. bri yelsh wh none mod strong Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11239'MD 11390'MD Country:10382'TVD 10445'TVD Averages Before During After Maximum ROP (fph)34 32 50 65 WOB 12 15 20 21 RPM 135 55 55 179 Mud Weight 11 11 11 11 Chloride 33,000 33,000 33,000 33,000 Total Gas 16 21 32 61 C1 (ppm)2,002 3,047 4,732 9,103 C2 (ppm)127 128 239 476 C3 (ppm)145 132 172 351 C4 (ppm)102 113 162 320 C5 (ppm)47 42 47 91 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 70-100%Type Instant Amount Amount None Distribution Ptchy-Even Intensity mod-strng Color Color None Intensity Mod-Strong Color Mbri trnsl Residual Fluorescence Cut Color M bri yel yel-yelwh Intesity Color None Color Oil Show Rating Free Oil in Mud Comments Report by: Hilcorp Alaska, LLC 50-133-10106-02-00SCU 31-04 Sodotna Creek Unit Craig Silva, Omar Hinostroza Poor to moderate visible porosity due to ash matrix volume. Overall poor/marginally fair to marginally good show range. 70-100% patchy to even moderately bright to bright yellow to yellowish white sample fluorescence; instant translucent moderately bright to bright yellow cut fluorescence that locally may very slightly increase in intensity with time; moderately strong to strong intensity bright white to yellowish white residual ring fluorescence; no staining or visible cuts in plain light; no visible oil, odor or pops from mud. 1.15 - 2.05 13-Aug-14 12:19 PM None Kenai Borough Alaska USA Saxon 169 Tuffaceous Sandstone/Sand = light gray to medium light gray with very faint yellowish gray to light brownish gray secondary hues; near 100% matrix supported; very ashy sandstone grades to very sandy tuffaceous claystone-"ash-stone"; major matrix component includes micro-fine glass shards, while bulk of very fine clastics are fluvial-winnowed glass shards; very fine upper to fine upper to trace medium lower to coarse lower grains; well sorted to moderately sorted; homogeneous/massive-looking overall, with imperfect diffuse lineations of increased (PDC bit-"smushed") black, pale reddish orange, pale greenish grains; very ashy sublithic arenite to quartz arenite; est 75-95% quartz, amorphous silica and various crypto and undifferentiated silica; tr-10% feldspar, 5-20% lithics and mostly undifferentiated mafic minerals; discernible micas, augite; well distributed traces of red to reddish orange volcanic grains and variegated greenstone metalithics; slightly calcareous. Yel-yelsh wh None Bright Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #5 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11430 MD 11607 MD Country:10468 TVD 10552 TVD Averages Before During After Maximum ROP (fph)52 41 53 78 WOB 7 11 7 18 RPM 42 50 44 128 Mud Weight 11 11 11 11 Chloride 33,000 33,000 33,000 33,000 Total Gas 38 55 25 93 C1 (ppm)5,542 6,655 2,432 13,832 C2 (ppm)283 454 235 717 C3 (ppm)214 501 251 1,076 C4 (ppm)202 376 227 803 C5 (ppm)64 161 122 311 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 70-100%Type instant Amount Amount None Distribution Ptchy-Even Intensity Mod-strng Color Color None Intensity Mod-strng Color Pl-v bri Residual Fluorescence Cut Color Mod bri yel yel-whi Intesity Color None rr blu wh Color Oil Show Rating Free Oil in Mud Comments Report by: Hilcorp Alaska, LLC 50-133-10106-02-00SCU 31-04 Sodotna Creek Unit Craig Silva, Omar Hinostroza Poor to moderate visible porosity due to ash matrix volume. Overall poor to dominantly fair to locally good show range. 70-100% patchy to even moderately bright to bright yellow to yellowish white sample fluorescence; instant translucent moderately bright to bright yellow to spotty very bright yellowish white cut fluorescence; moderately strong to strong intensity moderately bright to trace very bright white to yellowish white residual ring fluorescence; no staining or visible cuts in plain light; no visible oil, odor or pops from the mud. 0.9 - 2.9 13-Aug-14 20:38:00 PM None Kenai Borough Alaska USA Saxon 169 Tuffaceous Sandstone/Sand/Trace Conglomeratic Sandstone = mottled white to even light gray with very faint yellowish gray and light brownish gray secondary hues; ash matrix supported; very ashy sandstone grades to very sandy tuffaceous "ash-stone"; major matrix component includes micro-fine glass shards, while most very fine clastics are fluvial-winnowed glass shards; very fine upper to fine upper to trace/spotty medium lower to very coarse lower grains; well sorted to moderately sorted; homogeneous/massive- looking overall, with imperfect diffuse lineations of increased black, pale reddish orange, pale greenish grains; very ashy sublithic arenite to quartz arenite; est 80-95% quartz, amorphous silica and various crypto and undifferentiated silica; tr-10% feldspar, 5-15% lithics and mostly undifferentiated mafic minerals; discernible micas, augite; well distributed traces of red to reddish orange volcanic grains and variegated greenstone metalithics; slightly calcareous. mod bri-bri None Pale-strng Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #6 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11614 MD 11631 MD Country:10556 TVD 10564 TVD Averages Before During After Maximum ROP (fph)50 55 50 67 WOB 5 4 4 5 RPM 45 45 44 45 Mud Weight 10.9^ 10.9^ 10.9^ 10.9^ Chloride 33,000 33,000 33,000 33,000 Total Gas 18 42 41 60 C1 (ppm)1,793 4,022 3,838 5,716 C2 (ppm)168 399 398 578 C3 (ppm)206 455 502 679 C4 (ppm)174 380 369 542 C5 (ppm)91 211 218 307 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 40-90%Type instant Amount Amount None Distribution ptchy-even Intensity mod-strng Color Color None Intensity mod Color m bri yel- Residual Fluorescence Cut Color Mod bri yel yelsh wh Intesity Color None Color Oil Show Rating Free Oil in Mud Comments Report by: bri yelsh wh Craig Silva, Omar Hinostoza Poor visible porosity and permeability due to high volume ash matrix. Fair show overall. 40-90% patchy to even moderately bright to spotty bright whitish yellow sample fluorescence; instant moderately strong translucent marginally bright to bright yellow to yellowish white to white to trace bluish white cut fluorescence; moderately bright to very bright yellow to whitish yellow to slightly yellowish white to white residual ring fluorescence. No staining or cuts in plain light. No oil, odor or pops in the mud. 1.6 strong Hilcorp Alaska, LLC 50-133-10106-02-00SCU 31-04 Sodotna Creek Unit Saxon 169 14-Aug-14 4:18 AM none none Tuffaceous Sandstone/Sand = light gray to medium light gray with patchy very ashy white coloration and very faint pale yellowish gray secondary hue; very fine lower to fine upper; trace "floating" very coarse and conglomerate fragments; moderately well sorted in fine range; very fine glass shards are both component of abundant ash matrix and winnowed sand clastics; dominant angular-subangular, subdiscoidal to subspherical; equant to elongate dimensions; dominantly slightly calcareous; very ashy sublithic arenite to quartz arenite; note that nearly all ash appears non-devitrified; estimate 85-95% qtz and all other forms silica, trace-5% feldspar, trace-10% lithics and mafic minerals. Kenai Borough Alaska USA Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:10928'MD 11278'MD Country:10225'TVD 10330'TVD Averages Before During After Maximum ROP (fph)77 130 WOB 4.1 11.0 RPM 38.5 110 Mud Weight 10.9 Chloride 29,000 Total Gas 36 66 C1 (ppm)26,987 104,238 C2 (ppm)956 4,117 C3 (ppm)1,419 6,094 C4 (ppm)290 998 C5 (ppm)- 365 1,261 Lithology Cuttings Analysis Odor 0 Fluorescence Cut Fluorescence Residual Cut Stain Amount 50%Type Slow Amount Amount 0 Distribution Intensity Mod Color Color 0 Intensity Dull Color Bl/Wh Residual Fluorescence Cut Color Yellow Intesity Color White/Yellow Color Show Rating Free Oil in Mud Comments Report by: 1223AM Kenai Borough Alaska Hilcorp 50-133-10106-71-00SCU 31-04 PB1 Swanson River Field Saxon 169 7/23/2014 Mod Yellow USA James Adams 1 Yellow Mod Tuffaceous sandstone. Medium grey, upper fine to to medium grained, moderate sphericity. Subangular t subrounded, moderately well sorted, unconsolidated to to easily friable, ash and tuff matrix. Grain supported, translucent to to transparent quartz grains. Glauconitic, black and light brown clasts, trace biotite and muscovite. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11198'MD 11294'MD Country:10335'TVD 10372'TVD Averages Before During After Maximum ROP (fph)42 57 WOB 4.1 6.4 RPM 98.0 105 Mud Weight 10.9 Chloride 29,000 Total Gas 27.2 43 C1 (ppm)3,473 7,374 C2 (ppm)293 637 C3 (ppm)321 702 C4 (ppm)138 294 C5 (ppm)126 264 Lithology Cuttings Analysis Odor 0 Fluorescence Cut Fluorescence Residual Cut Stain Amount 50%Type Slow Amount Amount 0 Distribution Intensity Mod Color Color 0 Intensity Dull Color Bl/Wh Residual Fluorescence Cut Color Yellow Intesity Color Yellow Color Show Rating Free Oil in Mud Comments Report by: James Adams 11270' MD, 11330' MD, 11370' MD have strongest show. 11290' MD shows no flourescence. Sheen on shakers0.6 - 2.0 Hilcorp Tuffaceous sandstone. Light to medium grey, fine to medium grained, poor to fair sorting, subangular to subrounded, moderate sphericity. Unconsolidated to friable, tuft and ash matrix, grain supported. Transparent to white quartz grains with some reddish brown clasts. Trace coal, muscovite, and carbonaceous shale. Aproximately 10% - 20% tuffaceous silstone throughout. Kenai Borough Alaska USA Saxon 169 Bl/Wh Mod Mod Yellow 50-133-10106-71-00SCU 31-04PB1 Swanson River Field 7/23/2014 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11302'MD 11325'MD Country:10375'TVD 10384'TVD Averages Before During After Maximum ROP (fph)34 64 WOB 4.8 6.1 RPM 98.0 99 Mud Weight 10.9 10.9 Chloride 29,000 29,000 Total Gas 17.0 24 C1 (ppm)2,171 3,071 C2 (ppm)175 247 C3 (ppm)190 270 C4 (ppm)86 122 C5 (ppm)81 114 Lithology Cuttings Analysis Odor 0 Fluorescence Cut Fluorescence Residual Cut Stain Amount 50%Type Slow Amount Amount 0 Distribution Intensity Mod Color Color 0 Intensity Bright Color Bl/Wh Residual Fluorescence Cut Color Yellow Intesity Color Blue/White Color Show Rating Free Oil in Mud Comments Report by: James Adams Sheen on shakers2 Hilcorp Tuffaceous sandstone. Light to medium grey, fine to medium grained, poor to fair sorting, subangular to subrounded, moderate sphericity. Unconsolidated to friable, tuft and ash matrix, grain supported. Transparent to white quartz grains with some reddish brown clasts. Trace coal, muscovite, and carbonaceous shale. Aproximately 10% - 20% tuffaceous silstone throughout. Kenai Borough Alaska USA Saxon 169 Bl/Wh Mod Mod Yellow 50-133-10106-71-00SCU 31-04PB1 Swanson River Field 7/23/2014 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11543'MD 11753'MD Country:10468'TVD 10550'TVD Averages Before During After Maximum ROP (fph)39 58 WOB 4.8 8.4 RPM 89.0 109 Mud Weight 10.9 Chloride 32,500 Total Gas 23.0 38 C1 (ppm)2,970 5,068 C2 (ppm)188 307 C3 (ppm)196 318 C4 (ppm)118 200 C5 (ppm)124 215 Lithology Cuttings Analysis Odor 2-Jan Fluorescence Cut Fluorescence Residual Cut Stain Amount 50%Type Slow Amount Amount 0 Distribution 20%-50%Intensity Mod Color Color 0 Intensity Bright Color Bl/Wh Residual Fluorescence Cut Color Yellow Yellow Intesity Color Blue/White Color Show Rating Free Oil in Mud Comments Report by: 7/23/2014 Mod Yellow Hilcorp 50-133-10106-71-00SCU 31-04PB1 Swanson River Field Mod Tuffaceous claystone and siltstone grading to tuffaceous sandstone below 11580' MD. Medium light grey to medium grey, soft to unconsolidated. Poor to very poor induaration, fining coarser with depth. Malleable to purverulent, silty clayey texture. Earthy luster, pasty. Sandstone is medium to light greay, soft to unconsolidated, upper fine to lower coarse grained. Moderate to low spehericity, subrounded to rounded, poor sorting, frialble to unconsolidated with a few well consolidated clasts. Grain supported with a tuft matrix. Kenai Borough Alaska USA Saxon 169 Bl/Wh James Adams None0-1 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 SCU 31-04 22 6 DAILY REPORTS Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: R Pedersen / J Grubb DATE: Jul 21, 2014 DEPTH 9592' PRESENT OPERATION: Drilling ahead TIME: 2359 YESTERDAY 9179' 24 HOUR FOOTAGE 413' CASING INFORMATION 7.625" @ 9123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9583.41' 32.50 20.85 9558.89' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5x12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 113.9 @ 9565' 2.3 @ 9212' 49.8 58.97594 FT/HR SURFACE TORQUE 6105 @ 9403' 444 @ 9234' 1282.0 0.00000 FT-LBS WEIGHT ON BIT 158 @ 9311' 0 @ 9471' 10.2 6.67000 KLBS ROTARY RPM 192 @ 9308' 0 @ 9377' 11.5 0.00000 RPM PUMP PRESSURE 2575 @ 9239' 2025 @ 9496' 2025.4 2139.76001 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9800 / 9578 MW 9.45 VIS 51 PV 13 YP 20 Gels 5/8/11 FL 4.0 FC 1/2 SOL 5.8 NAF/W 0.0/91.7 SD 0 MBT 4.0 pH 9.9 ALK 0.20 Cl- 31000 Ca+ 100 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 450 @ 9577' 1 @ 9264.00000 71.4 TRIP GAS CUTTING GAS 0 @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 110929 @ 9577' 1 @ 9212' 15288.3 CONNECTION GAS HIGH 450 ETHANE (C-2) 299 @ 9394' 0 @ 9245' 59.6 CONNECTION GAS: AVG 200 PROPANE (C-3) 181 @ 9405' 0 @ 9245' 26.4 CONNECTION GAS: CURRENT BUTANE (C-4) 104 @ 9395' 0 @ 9245' 8.7 CURRENT AVG BACKGROUND PENTANE (C-5) 45 @ 9394' 0 @ 9245' 2.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Continued to TIH. R/U wireline/gyro to orient downhole tools. LD wireline/gyro. Drilling ahead at time of report. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: REPORT BY: S Nolan Hilcorp Alaska LLC Swanson River DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: R. Pederson / J. Grubb DATE: Jul 22, 2014 DEPTH 10086' PRESENT OPERATION: Drilling Ahead TIME: 00:40:43 YESTERDAY 9592' 24 HOUR FOOTAGE 494 CASING INFORMATION 7.625" @ 9123' MD SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10016.59' 64.28 19.17 9846.64' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 X 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 168.3 @ 9743' 0.8 @ 9798' 53.2 59 FT/HR SURFACE TORQUE 6762 @ 9989' 1 @ 9887' 1797.1 5407 FT-LBS WEIGHT ON BIT 161 @ 9805' 0 @ 10011' 13.6 2.8 KLBS ROTARY RPM 178 @ 9989' 2 @ 9595' 14.0 41 RPM PUMP PRESSURE 2502 @ 10080' 1970 @ 9797' 2200.4 2400 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.4 VIS 50 PV 16 YP 25 Gels 6/10/11 FL 3.8 FC 1/2 SOL 9.7 NAF/W 0.0/87.9 SD n/a MBT 3.2 pH 9.7 ALK 0.15 Cl- 31000 Ca+ 120 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 954 @ 10056' 26 @ 10068' 145.6 TRIP GAS CUTTING GAS 0 @ 10086' 0 @ 10086' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 304788 @ 9743' 11174 @ 9929' 38562.7 CONNECTION GAS HIGH 341 ETHANE (C-2) 1252 @ 9989' 34 @ 9634' 133.5 CONNECTION GAS: AVG 210 PROPANE (C-3) 303 @ 9989' 0 @ 9890' 33.4 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 217 @ 9989' 0 @ 9634' 12.4 CURRENT AVG BACKGROUND 50 PENTANE (C-5) 95 @ 9995' 0 @ 9945' 3.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Continued to drill ahead to 9591' flow check. Drilled to 9615' pumped Hi-Vis sweep and weighted up to 9.7ppg. Flow checked at 9806' well flowing, weighted up to 9.9ppg. Drilled to 9868' and flow checked (well flowing) weight up to 10.1ppg. Drilled to 9993', flow checkd well still flowing, weighted up to 10.3ppg. Pumped Hi-Vis sweep at 10034'. Continue to drill ahead at time of report. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465.00 REPORT BY: Seth Nolan Hilcorp Alaska LLC Swanson River DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: J. Greco / J. Grubb DATE: Jul 23, 2014 DEPTH 10954' PRESENT OPERATION: Drilling Ahead TIME: 00:38:14 YESTERDAY 10095' 24 HOUR FOOTAGE 859' CASING INFORMATION 7.625" @ 9123' MD SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 X 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 155.7 @ 10556' 1.6 @ 10493' 83.9 94.64 FT/HR SURFACE TORQUE 13130 @ 10492' 5242 @ 10177' 6796.3 7249.64 FT-LBS WEIGHT ON BIT 156 @ 10429' 0 @ 10107' 15.5 3.36 KLBS ROTARY RPM 114 @ 10830' 37 @ 10160' 59.7 39.25 RPM PUMP PRESSURE 2622 @ 10356' 2092 @ 10366' 2454.9 2460.89 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.9 VIS 50 PV 17 YP 18 Gels 4/7/10 FL 4.0 FC 1/2 SOL 11.6 NAF/W 0.0/86.2 SD n/a MBT 4.5 pH 9.8 ALK 0.15 Cl- 29000 Ca+ 160 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 914 @ 10926' 1 @ 10683' 64.3 TRIP GAS CUTTING GAS 0 @ 10954' 0 @ 10954' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 227696 @ 10126' 256 @ 10682' 17067.8 CONNECTION GAS HIGH ETHANE (C-2) 4726 @ 10460' 9 @ 10583' 370.4 CONNECTION GAS: AVG PROPANE (C-3) 1525 @ 10460' 0 @ 10785' 106.9 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 632 @ 10653' 0 @ 10785' 34.5 CURRENT AVG BACKGROUND 20 PENTANE (C-5) 285 @ 10408' 0 @ 10102' 18.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous Sanstone DAILY ACTIVITY SUMMARY Continued to drill ahead to 10180' and flow checked, well flowing. Drilled to 10273' flow checked, well flowing. Weighted up to 10.7ppg MW. Drilled to 10490', flow checked, well flowing. Drilled to 10582', flow checked, well still flowing, weighted up to 10.9 ppg MW. Drilled to 10644', flow checked, pumped pill, POOH to window, TIH back to bottom. Drilling ahead at time of report. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465.00 REPORT BY: Seth Nolan Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: J. Greco/ J. Grubb DATE: Jul 24, 2014 DEPTH 11536' PRESENT OPERATION: Drilling Ahead TIME: 00:30:02 YESTERDAY 10954' 24 HOUR FOOTAGE 582' CASING INFORMATION 7.625" @ 9123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 X 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 180.3 @ 11412 1.7 @ 11194 51.6 47.08103 FT/HR SURFACE TORQUE 18362 @ 11352 6168 @ 11050 9428.8 8079.39990 FT-LBS WEIGHT ON BIT 173 @ 11483 0 @ 11105 14.0 11.33000 KLBS ROTARY RPM 110 @ 11014 29 @ 11420 68.7 89.22000 RPM PUMP PRESSURE 2541 @ 11369 2169 @ 11048 2356.8 2236.78003 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.9 VIS 47 PV 19 YP 19 Gels 4/7/10 FL 3.4 FC 1/2 SOL 11.9 NAF/W 0/85.7 SD MBT 5 pH 9.9 ALK 0.18/2 Cl- 32,500 Ca+ 200 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 339 @ 11156 5 @ 11484 52.4 TRIP GAS CUTTING GAS 0 @ 11536 0 @ 11536 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 104238 @ 10990 198 @ 11430 11470.9 CONNECTION GAS HIGH 282 ETHANE (C-2) 6208 @ 11287 5 @ 11428 591.1 CONNECTION GAS: AVG PROPANE (C-3) 4979 @ 11344 10 @ 11427 437.1 CONNECTION GAS: CURRENT BUTANE (C-4) 3829 @ 11344 9 @ 11427 332.6 CURRENT AVG BACKGROUND 20 PENTANE (C-5) 882 @ 11287 0 @ 11430 52.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous siltstone/sandstone DAILY ACTIVITY SUMMARY Drilled ahead from 10,973' w/ slight increase in drilling and 18 bph flow while static. Pumped 15 bbl high viscosity sweep at 11,359'; no increase in cuttings. Drilled ahead with 15-20 bph flow while static. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465.00 REPORT BY: Trey Thrailkill Hilcorp Alaska LLC Swanson River DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: J. Greco/ J. Grubb DATE: Jul 25, 2014 DEPTH 11966' PRESENT OPERATION: Building up mud TIME: 2400 YESTERDAY 11536' 24 HOUR FOOTAGE 430' CASING INFORMATION 7.625" @ 9123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11877.76 67.36 19.32 10598.27 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 x 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 83.1 @ 11929 2.0 @ 11750 39.0 57.83388 FT/HR SURFACE TORQUE 18085 @ 11896 6498 @ 11586 10878.6 8673.20996 FT-LBS WEIGHT ON BIT 165 @ 11733 0 @ 11783 15.0 1.80000 KLBS ROTARY RPM 112 @ 11877 43 @ 11585 95.0 88.12000 RPM PUMP PRESSURE 2510 @ 11723 2071 @ 11731 2269.5 2350.40991 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.2 VIS 47 PV 12 YP 19 Gels 5/8/12 FL 3.8 FC 1/2 SOL 9.2 NAF/W 0.0/88.6 SD MBT 4 pH 9.1 ALK 0.05 Cl- 29000 Ca+ 160 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 418 @ 11809 1 @ 11941 47.4 TRIP GAS CUTTING GAS 0 @ 11966 0 @ 11966 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 80021 @ 11809 887 @ 11541 6487.9 CONNECTION GAS HIGH ETHANE (C-2) 3049 @ 11876 20 @ 11541 292.6 CONNECTION GAS: AVG PROPANE (C-3) 3346 @ 11876 23 @ 11541 310.6 CONNECTION GAS: CURRENT BUTANE (C-4) 4059 @ 11756 17 @ 11541 252.7 CURRENT AVG BACKGROUND 0 PENTANE (C-5) 944 @ 11876 0 @ 11792 56.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Drilled ahead from 11,549', flow check on connection at 20 bph with no increase in volume while drilling. Pumped hi-vis sweep at 11,669' with no increase in cuttings. Continued drilling ahead til 11,967', lost all returns. Pumped 15 bbl LCM pill @ 40 ppb and again at 11,787'. Pumped out of hole to 11,413' and pumped 20 bbl LCM pill @50 ppb. Continued TOH on elevators to window to build more mud. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465.00 REPORT BY: Trey Thrailkill Hilcorp Alaska LLC Swanson River DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: J. Greco/ J. Grubb DATE: Jul 25, 2014 DEPTH 11966' PRESENT OPERATION: Rigging up wireline TIME: 2400 YESTERDAY 11966' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 9123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 x 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 9.2 VIS 42 PV 8 YP 12 Gels 4/6/8 FL 5.4 FC 1/2 SOL 4.2 NAF/W 0/93.5 SD MBT pH 8.8 ALK 0.05 Cl- 28500 Ca+ 80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 600 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY TOH to 9,105' and pumped 20 bbl 50ppb pill while tripping Built new mud volume with 50 ppb background BARACARBs. Added 162 bbl of mud to anulus while building, never saw mud on backside. Mixed total of 985 bbl and began TIH to drill. Drill pipe became stuck at 11,865'. Began pumping and saw as high as 20% flow but still lost 168 bbl/hr pumping at 4 bbl/min. Brought pump rate down to 3 bbl/min- losses @ 80 bbl/hr. Continued to work pipe and spotted 6% NXS Lube pill across open hole, losses had decreased to 25-30 bph at 3bbl/min pump rate, increased pump rate to 6.1bbl/min and losses increased to 136 bph. Shut down pumps to soak pill and monitor well. Well was flowing @ over 100 bph while static CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465 REPORT BY: Trey Thrailkill Hilcorp Alaska LLC Swanson River DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: Joe Grubb, Jimmy Greco DATE: Jul 25, 2014 DEPTH 11966' PRESENT OPERATION: TOH for fishing tools/jars TIME: 2400 YESTERDAY 11966' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 9123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 x 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 9.55 VIS 43 PV 8 YP 14 Gels 6/8/11 FL 6.3 FC 1/2 SOL 5.5 NAF/W 0.0/92.2 SD MBT pH 8.3 ALK 0/1.6 Cl- 28000 Ca+ 1240 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued circulating well at 3 bpm and working pipe, flow checked at over 100 bph. Pumped 40 bbl 10 ppg cap pill and chased to above window in annulus. Initial flow check was 50-80 bph and slowed to 10. Began RIH with E-line to determine free point, stuck at 9,995'. Ran back in with charges, pipe freed. Circulated surface to surface and dumped 130 bbl H2O. Lots of coal at BU. Flow-checked well for 5 minutes on trip tank- well flowing @ 97 bph. Decision made to weight up from 9.2 ppg to 9.5 ppg. Initial losses @ 250 gpm were 38 bph. Losses @ 150 gpm were 12 bph. Unable to weigh up full system to 9.5 due to losses and influx, TOH T/ window, flow changed during trip to losing 10 bph. Monitored well at window and continued to lose @ 10 bph. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465 REPORT BY: Trey Thrailkill Hilcorp Alaska LLC Swanson River DAILY WELLSITE REPORT SCU 31-04 REPORT FOR: Joe Grubb/ Jimmy Greco DATE: July 28, 2014 DEPTH 11967' PRESENT OPERATION: Jarring on fish TIME: 2400 YESTERDAY 11967' 24 HOUR FOOTAGE 0' CASING INFORMATION 7.625" @ 9123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 6.125" HDBS MM55 12484807 5 x 12 9178' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11967' MW 9.5 VIS 53 PV 11 YP 16 Gels 6/9/12 FL 4.8 FC 1/2 SOL 5.5 NAF/W 0/91.9 SD MBT pH 8.1 ALK 0/0.7 Cl- 33000 Ca+ 600 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue TOH to surface. Picked up screw-in sub, jars & 4-3/4" collars to try to screw into fish , began running in hole. At 7,474', lost returns while RIH slowly. Up until 7,474', mud displacement was only 4.3 bbl over calculated. RIH T/TOW and established circulation while slipping and cutting drill line. RIH T/ 9,520', CBU. RIH T/ 9,952' washed down last stand and screwed into fish. Pumped hi-vis sweep, 10% increase in cuttings (mostly fines and some small coal). CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3465 REPORT BY: Trey Thrailkill Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: Hilcorp Alaska LLC DATE: Aug 09, 2014 DEPTH 9785 PRESENT OPERATION: DRILLING AHEAD TIME: 00:38:47 YESTERDAY 9495 24 HOUR FOOTAGE 290 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9645.38' 31.21 28.11 9617.43 9584.11' 27.06 30.87 9563.92 9522.42' 23.15 26.99 9508.06' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS 12484156 5X12 9438 262 36 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 129.2 @ 9705 1.2 @ 9498 40.7 21.09878 FT/HR SURFACE TORQUE 5536 @ 9709 1346 @ 9780 611.9 0.00000 FT-LBS WEIGHT ON BIT 24 @ 9669 3 @ 9712 13.2 19.380 KLBS ROTARY RPM 65 @ 9595 2 @ 9733 5.5 0.00000 RPM PUMP PRESSURE 2323 @ 9719 1548 @ 9496 2059.7 1896.330 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.98 VIS 89 PV 15/120 YP 21 Gels 5/7/9 FL 96 FC SOL 10.9 NAF/W SD 0.01 MBT 2.0 pH 10.2 89 ALK 0.75 Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 49 @ 9613 0 @ 9527 7.8 TRIP GAS CUTTING GAS 0 @ 9785 0 @ 9785 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9822 @ 9613 60 @ 9499 1425.6 CONNECTION GAS HIGH 132 ETHANE (C-2) 160 @ 9674 1 @ 9518 37.1 CONNECTION GAS: AVG 35 PROPANE (C-3) 0 @ 9785 0 @ 9785 0.0 CONNECTION GAS: CURRENT 81 BUTANE (C-4) 0 @ 9785 0 @ 9785 0.0 CURRENT AVG BACKGROUND 5 PENTANE (C-5) 0 @ 9785 0 @ 9785 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE/ COAL PRESENT LITHOLOGY TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Oriented low side and slide drilled from 9452' to 9482' Timed drilled at 1 ft hr to kick off cement plug. Time drilling / Sliding 1-3 ft hr while drilling through the build section. currently at 9798' at report time. CANRIG PERSONNEL ON BOARD: 4 PERSONNEL __DAILY COST: 3465.00 REPORT BY: HINOSTROZA Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: DATE: Aug 10, 2014 DEPTH 10025.00000 PRESENT OPERATION: DRILLING AHEAD TIME: 00:41:45 YESTERDAY 9785.00000 24 HOUR FOOTAGE 240 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10017.02' 60.00 24.00 9874.03' 9955.31' 55.93 24.83 9841.30' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS 12484156 5X12 9438 262 36 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 89.4 @ 9883 1.7 @ 10025 22.4 1.72067 FT/HR SURFACE TORQUE 9768 @ 9980 928 @ 9998 253.9 0.00000 FT-LBS WEIGHT ON BIT 30 @ 9975 12 @ 9810 20.9 22.150 KLBS ROTARY RPM 125 @ 9978 2 @ 10010 2.0 0.00000 RPM PUMP PRESSURE 2111 @ 9876 1578 @ 10009 1915.3 1897.68 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.98 VIS PV 15/120 YP 21 Gels 5/7/9 FL 96 FC SOL 10.9 NAF/W SD 0.01 MBT 2.0 pH 10.2 ALK 0.75 Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 23 @ 10009 0 @ 9985 6.5 TRIP GAS CUTTING GAS 0 @ 10025 0 @ 10025 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4706 @ 10009 132 @ 9983 1258.7 CONNECTION GAS HIGH 190 ETHANE (C-2) 99 @ 9811 1 @ 9985 20.9 CONNECTION GAS: AVG 65 PROPANE (C-3) 32 @ 9892 0 @ 9985 4.1 CONNECTION GAS: CURRENT 80 BUTANE (C-4) 0 @ 10025 0 @ 10025 0.0 CURRENT AVG BACKGROUND 4 PENTANE (C-5) 0 @ 10025 0 @ 10025 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE/ COAL PRESENT LITHOLOGY TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Oriented low side and slide drilled from 9452' to 9482' Timed drilled at 1 ft hr to kick off cement plug. Time drilling / Sliding 1-3 ft hr while drilling through the build section. currently at 9798' at report time. CANRIG PERSONNEL ON BOARD: 4 PERSONNEL __DAILY COST: 3465.00 REPORT BY: HINOSTROZA Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: Hilcorp Alaska LLC DATE: Aug 11, 2014 DEPTH 10605 PRESENT OPERATION: SHORT TRIP TIME: 00:45:36 YESTERDAY 10025 24 HOUR FOOTAGE 580 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10513.99 65.93 23.47 10079.79 10450.77 66.27 24.00 10054.18 10389.35 66.27 24.95 10028.97 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS 12484156 5X12 9438 554 58.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 116.5 @ 10199 1.1 @ 10530 51.8 52.54111 FT/HR SURFACE TORQUE 12074 @ 10192 1423 @ 10130 8396.2 10383.85 FT-LBS WEIGHT ON BIT 22 @ 10032 3 @ 10134 11.9 8.860 KLBS ROTARY RPM 191 @ 10243 7 @ 10122 50.5 62.310 RPM PUMP PRESSURE 2256 @ 10592 1830 @ 10052 2124.8 2179.10 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.90 VIS 98 PV 15 120 YP 20 Gels 5/7/9 FL 106 FC SOL 11.0 NAF/W SD 2.0 MBT 2.0 pH 8.5 98 ALK 0.29 Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 43 @ 10334 1 @ 10086 8.6 TRIP GAS CUTTING GAS 0 @ 10605 0 @ 10605 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 17804 @ 10526 229 @ 10086 2174.4 CONNECTION GAS HIGH 77 ETHANE (C-2) 443 @ 10537 7 @ 10518 48.2 CONNECTION GAS: AVG 50 PROPANE (C-3) 129 @ 10599 0 @ 10479 9.1 CONNECTION GAS: CURRENT 27 BUTANE (C-4) 7 @ 10567 0 @ 10539 0.2 CURRENT AVG BACKGROUND 2 PENTANE (C-5) 0 @ 10605 0 @ 10605 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/TUFFACEOUS SANDSTONE/COAL PRESENT LITHOLOGY SAND/TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Drilled from 10060' to 10440' pumped 20 bbls hi-vis sweep 15-10% increase in cuttings. Drilling ahead at report time, planing on making a short trip to the window around 10600+/- ft. CANRIG PERSONNEL ON BOARD: 4 PERSONNEL __DAILY COST: 3465.00 REPORT BY: HINOSTROZA Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: Hilcorp Alaska LLC DATE: Aug 12, 2014 DEPTH 11055 PRESENT OPERATION: DRILLING AHEAD TIME: 00:38:11 YESTERDAY 10605 24 HOUR FOOTAGE 450 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11011.00 64.91 22.87 10285.02 10947.59 65.12 22.94 10258.24 10885.89 65.19 23.09 10232.32 10824.44 65.56 23.24 10206.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS 12484156 5X12 9438 1508 98.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 78.0 @ 10617 2.0 @ 10944 48.6 35.78640 FT/HR SURFACE TORQUE 13093 @ 10801 2593 @ 11020 11284.7 11614.730 FT-LBS WEIGHT ON BIT 32 @ 11020 3 @ 10861 9.2 15.150 KLBS ROTARY RPM 168 @ 11042 15 @ 11019 76.3 107.20 RPM PUMP PRESSURE 2304 @ 10882 2018 @ 10936 2195.5 2233.820 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.90 VIS 96 PV 16/120 YP 19 Gels 5/7/10 FL 106 FC SOL 10.9* NAF/W SD 0.10 MBT 2.5 pH 10.0 ALK 0.36 Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 87 @ 11046 4 @ 10613 29.6 TRIP GAS CUTTING GAS 0 @ 11055 0 @ 11055 0.0 WIPER GAS 1037 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 19085 @ 11000 657 @ 10947 3834.2 CONNECTION GAS HIGH 184 ETHANE (C-2) 1372 @ 10843 23 @ 10613 228.5 CONNECTION GAS: AVG 85 PROPANE (C-3) 1435 @ 11012 9 @ 10613 162.7 CONNECTION GAS: CURRENT 161 BUTANE (C-4) 1170 @ 11012 0 @ 10783 104.4 CURRENT AVG BACKGROUND 10 PENTANE (C-5) 409 @ 11012 0 @ 10831 43.6 HYDROCARBON SHOWS Over all the highest gases is from 10900'-10605' show zone. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10900'-10605' Total interval higher gas zone 10960-11000 Mix of matrix supported tuff SS, grain supported lightly calc cemented SS, conglomeratic sand and minor conglomerate; overall coarser. Max gas 58u at 10965', 10 avg thru (10900'- 10605') TUFF SS/SAND/CONGLOMERATIC TUFFACEOUS SANDSTONE OTHER THAN VERY SLIGHT OVERALL COARSENING AND MORE RAPID SEPARATION OF GRAINS WHEN HYDRATED; NOTE OCCASIONALY COMMON DISAGGREGATED SAND GRAINS THAT RANGE FROM FINE TO SAND GRAINS LITHOLOGY TUFFACEOUS SANDSTONE/SAND/CONGLOMERATIC/COAL PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/SAND DAILY ACTIVITY SUMMARY Circulate Hi-Vis sweep around to clean wellbore at 280 GPM = 2060 PSI. Pump up survey, flow check was 9 BPH, POOH FR: 10613'-9115', tight spots at 10,390', 9,851', 9,812', 9,805' and 9,230'. CANRIG PERSONNEL ON BOARD: 4 PERSONNEL __DAILY COST: 3465.00 REPORT BY: HINOSTROZA Hilcorp Alaska LLC Soldotna Creek Unit DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: Rance Pederson Jimmy Greco DATE: Aug 13, 2014 DEPTH 11519 PRESENT OPERATION: Drilling ahead TIME: 24:00 YESTERDAY 11055 24 HOUR FOOTAGE 464 CASING INFORMATION 7 5/8" Casing window at 9443' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11011.00 64.91 022.87 10285.02 11132.99 64.93 021.86 10336.54 11258.43 63.89 021.59 10391.09 11380.62 63.01 021.79 10445.53 11505.02 61.62 021.37 10503.19 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS MM55 12484156 5x12/0.5622 9443 102.12 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 78.4 @ 11510 0.6 @ 11075 33.5 45.1 FT/HR SURFACE TORQUE 15452 @ 11384 6927 @ 11479 11082.9 7914.21 FT-LBS WEIGHT ON BIT 170 @ 11357 5 @ 11420 15.6 14.31 KLBS ROTARY RPM 264 @ 11217 31 @ 11246 63.2 56.1 RPM PUMP PRESSURE 2653 @ 11327 2134 @ 11077 2422.8 2303.2 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11438 / 10471 TVD MW 10.90 VIS 49 PV 20 YP 23 Gels 5/7/9 FL 3.5 FC 2 SOL 11.3 NAF/W 0.0/86.3 SD 0.10 MBT 3.5 pH 10.1 ALK 0.85 Cl- 33000 Ca+ 1000 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 141 @ 11446 0 @ 11466 30.9 TRIP GAS CUTTING GAS @ @ WIPER GAS 1047 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 69992 @ 11444 15 @ 11466 6448.2 CONNECTION GAS HIGH 170 ETHANE (C-2) 3316 @ 11446 1 @ 11466 386.0 CONNECTION GAS: AVG 122 PROPANE (C-3) 2721 @ 11452 1 @ 11466 361.3 CONNECTION GAS: CURRENT 132 BUTANE (C-4) 2675 @ 11452 1 @ 11466 325.9 CURRENT AVG BACKGROUND 19 / 62 PENTANE (C-5) 8351 @ 11452 1 @ 11401 440.1 HYDROCARBON SHOWS At least trace to fair shows through entire report interval. Very good shows at massive tuffaceous sandstone section from 11144' to 11200' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11144'-11200' Massive tuffaceous sandstone. Three discernible size modes. Volcanic ash-tuff clay matrix but no devitrification of ash. Dominantly angular grains. Visual porosity not differentiated. Not that gas readings are NOT high. High: 41u Avg: 36u Bkgrnd: 20u Before/After: 29/13 Tuff SS: wh-v lt gry; dom vf-f; mod w srtd i/p and p srtd i/p; abnt ash mtrx, grad to v sdy ashst; mostly ang-sbang, discoid- sbspher; V GOOD SHOW; v bri whtsh yel spl flor, v bri inst bluish wh cut flor, v bri wh resid ring. LITHOLOGY Dominant Tuffaceous Sandstone with minor inclusive fractions of disaggregated Sand, Non-Differentiated Sandstone and Conglomeratic Sandstone. Matrix of sandstones is Volcanic Ash, and minor zones of volcanic ash-derived Tuffaceous Siltstone and Tuffaceous Claystone PRESENT LITHOLOGY TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY Drill from 11055' to 11170'. Begin CBU. Circulate around Hi-Vis and Nutplug sweep. Check for flow and observe well flowing at 7.0 bbls per hour. Do wiper trip from 11170' to 10854'. Had 30K overpull at several tight spots on first 3 stands out of hole, and work through tight spots at 11079' and 10704'. Run back in hole from 10584' to 11108'. Break circulation and wash down from 11108' to 11170'. Begin drilling ahead from 11170' and record 1047 units of Wiper Gas. Continue drilling ahead to 11519'. CANRIG PERSONNEL ON BOARD: C Silva O Hinostroza J Boutte D Kekaualua __DAILY COST: 3465 REPORT BY: Craig Silva Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: Hilcorp Alaska LLC DATE: Aug 13, 2014 DEPTH 11515 PRESENT OPERATION: DRILLING AHEAD TIME: 24:00:00 YESTERDAY 11055 24 HOUR FOOTAGE 460 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11505.02 61.62 21.37 10503.19 11444.20 62.44 24.69 10474.67 11380.62 21.79 21.79 10445.53 11320.56 63.63 21.75 10418.57 11258.43 63.89 21.59 10391.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS 12484156 5x12 9438 1920 96.89 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 78.4 @ 11510 0.6 @ 11075 33.4 49.49328 FT/HR SURFACE TORQUE 15452 @ 11384 6927 @ 11479 11111.3 8036.140 FT-LBS WEIGHT ON BIT 170 @ 11357 5 @ 11420 15.6 14.5200 KLBS ROTARY RPM 264 @ 11217 31 @ 11246 63.3 56.74000 RPM PUMP PRESSURE 2653 @ 11327 2134 @ 11077 2423.6 2349.0400 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 10.90 VIS 96 PV 18 120 YP 21 Gels 5/7/10 FL 106 FC SOL 11.1 NAF/W SD 0.10 MBT 3.0 pH 9.6 ALK 0.68 Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 141 @ 11446 0 @ 11466.00000 30.6 TRIP GAS CUTTING GAS 0 @ 11515 0 @ 11515.00000 0.0 WIPER GAS 1047 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 69992 @ 11444 15 @ 11466 5997.6 CONNECTION GAS HIGH 160 ETHANE (C-2) 3316 @ 11446 1 @ 11466 378.1 CONNECTION GAS: AVG 50 PROPANE (C-3) 2721 @ 11452 1 @ 11466 352.0 CONNECTION GAS: CURRENT 157 BUTANE (C-4) 2675 @ 11452 1 @ 11466. 308.8 CURRENT AVG BACKGROUND 7 PENTANE (C-5) 8351 @ 11452 2 @ 11401 414.8 HYDROCARBON SHOWS Overall highest oil shows 11150' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION Highest Flour 11150'-11200 MATRIX ASH IS LOWER LIGHTNESS VALUE GRAY; SAND IS SLIGHTLY MORE HOMOGENEOUS, WITH FEW ANGULAR GRAINS;MATRIX IS SLIGHTLY "STICKIER" SORTING IS SLI IMPROVED; SAMPLE FLUOR STILL 100% BUT COLOR IS MORE YELLOWISH; EVEN DULL TO MOD BRIGHT YELLOW TO WHITE SAMPLE FLOUR;INSTANT PALE CUT, HIGHER INTENSITY OVER TIME; YELLOWISH RESIDUAL RING MOD TO STRONG INTENSITY; NO VIS CUTS; POOR TO MOD VISIBLE POROSITY; NO ODOR OR POPS FROM MUD. LITHOLOGY TUFFACEOUS SANDSTONE/SAND/SANDSTONE/CONGLOMERATIC SANDSTONE PRESENT LITHOLOGY TUFFACEOUS SANDSTONE/SAND DAILY ACTIVITY SUMMARY Did flow check well flowing @ 7 bbls per hour, wiper trip out of hole F/11170'. Had 30k over pull thru spots first three stand off BTTM Continued drilling ahead T/ 11444' pumped hi-vis sweep, 20 % increase, ''sweep came back on time." Drilling ahead at r CANRIG PERSONNEL ON BOARD: eport time __DAILY COST: 4 PERSONNEL REPORT BY: 3465.00 Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: DATE: Aug 14, 2014 DEPTH 11775 PRESENT OPERATION: POOH TIME: 24:00 YESTERDAY 11519 24 HOUR FOOTAGE 256 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11568.22 61.23 21.24 10533.42 11630.6 60.55 21.23 10563.77 11691.16 60.13 20.61 10593.74 11738.74 59.77 20.51 10617.56 11775' 59.77 20.51 10635.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS 12484156 5x12 9438 11775 2337.00 110.14 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 70.5 @ 11742 4.6 @ 11775 43.6 4.58196 FT/HR SURFACE TORQUE 8934 @ 11546 6897 @ 11609 7881.9 7355.810 FT-LBS WEIGHT ON BIT 16 @ 11685 1 @ 11760 9.6 6.060 KLBS ROTARY RPM 198 @ 11668 39 @ 11744 53.5 41.300 RPM PUMP PRESSURE 2508 @ 11742 2262 @ 11627 2418.5 2329.640 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 11.10 VIS 96 PV 19 YP 20 Gels 5/6/9 FL 105 FC 2 SOL 12.1 NAF/W 0.0/85.3 SD 0.10 MBT 3.0 pH 10.0 ALK 0.75 Cl- Ca+ 1000 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 138 @ 11684 18 @ 11610 60.2 TRIP GAS CUTTING GAS 0 @ 11775 0 @ 11775 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 33843 @ 11529 1302 @ 11558 7614.0 CONNECTION GAS HIGH 144 ETHANE (C-2) 1223 @ 11542 56 @ 11545 296.5 CONNECTION GAS: AVG 122 PROPANE (C-3) 2230 @ 11542 62 @ 11702 408.0 CONNECTION GAS: CURRENT 123 BUTANE (C-4) 1750 @ 11542 42 @ 11702 340.8 CURRENT AVG BACKGROUND PENTANE (C-5) 1602 @ 11519 16 @ 11697 218.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE/SAND/CONGLOMERATIC/SAND PRESENT LITHOLOGY None DAILY ACTIVITY SUMMARY Well flowing @ 7 BBLS Hr gained 36 BBLS this tour, Circ hi vis sweep, pulling out of hole at 11775' to 10969 pumping and rotating. Had to pump and rotate thru window at 9124 9143, build 35 bbl 13.0PPG pill. CANRIG PERSONNEL ON BOARD: C Silva O Hinostroza J Boutte D Kekaualua __DAILY COST: 3465 REPORT BY: Hinostroza Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: DATE: Aug 14, 2014 DEPTH 11775 PRESENT OPERATION: R.I.H TIME: 24:00 YESTERDAY 11775 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.125 HDBS MM55 12484156 5x12/0.5622 9443 11775 9438 110.14 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 11.15 VIS 53 PV 19 YP 19 Gels 5/7/9 FL 0 FC 2 SOL 12.4 NAF/W 85.2 SD 0.10 MBT 3.0 pH 8.6 ALK 0.30 Cl- 32000 Ca+ 1000 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY None PRESENT LITHOLOGY None DAILY ACTIVITY SUMMARY Cont to POOH F/ 3777'-T/BHA L/D Dir tools,down load mwd data.Lay out Tested BOPs. M/U clean-out BHA and TIH w/same. RIH at report time @5281, plan to circulate out produced water at the window. TIH for clean out, run liner and Cement. Test 4CM,#7,9,11,13, inside kill, TIW valve @ 250&3500psi for 10 min each. Test #4 Failed due to bad CM valve #9. Test 4 CM.7,10,11,13 inside kill TIW @ 250&3500psi for 10 min each. Testing CM #6,7,12 due to breaking apart to change valve #9 @250&3500psi for 10min. Pass&Fail retest CM valve #9 @250&3500 PSI for 10min each. R/D all test equip /blow down choke lines P/U and M/u bha. R.I.H F/6922'-T/4597'. Cont R.I.H F/4597'-T/ CANRIG PERSONNEL ON BOARD: C Silva O Hinostroza J Boutte D Kekaualua __DAILY COST: REPORT BY: Hinostroza Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: DATE: Aug 16, 2014 DEPTH 11775 PRESENT OPERATION: POOH TIME: 24:00 YESTERDAY 11775 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3RR1 6.125 XR-PS P15928 3X13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 11.15 VIS 46 PV 15 YP 18 Gels 5/7/9 FL 92 FC 2 SOL 12.1 NAF/W 85.6 SD 0.10 MBT 3.0 pH 9.3 ALK 0.30 Cl- 31000 Ca+ 800 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1414 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 30 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY None PRESENT LITHOLOGY None DAILY ACTIVITY SUMMARY Circulateing water out of well bore(mw 10.0,spp-730, gpm-234) dumped 210 bbls of h20 cont RIH F-7693-T/9115(P/U -170k,S/O-170K) Weighting up to 11.1 PPG pump high vis sweep, Pooh F/1775 T/10950 pump and rotated out of hole. Flow checked and slip and cut 150' of drill line. RIH F?9121'-T/11775'. Pumped hi-vis sweep & circulate out. Flow checked well flowing 3.5 bbls hr. Pooh F/11775' CANRIG PERSONNEL ON BOARD: C.Silva, O.Hinostroza __DAILY COST: 2585.00 REPORT BY: Hinostroza Hilcorp Alaska LLC DAILY WELLSITE REPORT SCU 31-04 (post plug-back) REPORT FOR: DATE: Aug 17, 2014 DEPTH 11775 PRESENT OPERATION: Running In Hole TIME: 24:00 YESTERDAY 11775 24 HOUR FOOTAGE 0 CASING INFORMATION 7.625 SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3RR1 6.125 XR-PS P15928 3x13 3 6.125 HDBS 12484156 5x12 9438 11775 2337.00 110.14 2-5-BT-G-X-I-WT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW 11.10 VIS 45 PV 13 YP 18 Gels 4/6/8 FL 0 FC 2 SOL 12.2 NAF/W 85.6 SD 0.10 MBT 3.0 pH 9.4 ALK 0.30 Cl- 30000 Ca+ 800 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued POOH while L/D 84 joints of DP. Flow-checked well @ 6,510'- well flowing @ 3.5 bph. Spotted 30 bbl, 13.0 ppg weighted cap @ 6,510'. POOH on stands T/surface. L/D BHA and prepped floor for running liner. R/U and RIH with 4.5" production liner on 4.5" DP. CANRIG PERSONNEL ON BOARD: C.Silva O.Hinostroza __DAILY COST: 2585.00 REPORT BY: O,Hinostroza
