The URL can be used to link to this page

Home My WebLink About2017-10-16_317-490THE STATE Alaska Off and Gas Of ALASKA ,li Conservation Commission GOVERNOR BILL WALKER Hanna Sylte Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-22 Permit to Drill Number: 217-089 Sundry Number: 317-490 Dear Ms. Sylte: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.olaska.gov 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, /4--,,, 4ay. oerster Commissioner Y& -- DATED this day of November, 2017. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED OCT 111//s11 � 7 AOGC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑r • Repair Well ❑ Operations shutdown ❑ - Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ After Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Exploratory ❑ Development 0 • Stratigraphic ❑ Service ❑ 217-089 3. Address: 6. API Number: P. O. Box 100380, Anchorage, Alaska 99510 50-103-20759-00-00 , 7. if perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing In this pool? G';]q13 CRU CD5-22 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): , 10. Field/Pool(s): ASRC-NPF14 ASRC-NPR4, ASRC-NPR3, ASRC-NPRi Colville River Unit, Alpine Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 28000 7338 24000 7372 7000 psi Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 10" 115' est. 115' est. Surface 2190' 10.75" 2226' est. 2185' est. Intermediate 9988' 7.625" 10709' est. 7462' est. Production Liner 14200' 4.5" 24000' est. 7372est. Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 19980, See Attached Schematic • See Attached Schematic 3 1l2" L80 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Production Packer Packer at 9,717' MD/7369' TVD 12. Attachments: Proposal Summary Wellbore schematic J./I 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑., . Service ❑ 14. Estimated Date for vrlV �7/ //.ZD/i`� 15. Well Status after proposed work: Commencing Operations: 9111 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown [] Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Hanna Sylte, 907-265-6342 Emall Hanna.Sylle@ConocoPhillips.com Printed Name Hanna Sylte Title Completions Engineer — 1G k f Signature Phone 907-265-6342 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 l,qqb Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. Post initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes [INo Subsequent Form Required: I %� -1o4 �r APPROVED BY 1_ 5— Approved by: COM MMISSION Date: 11-15- 7qT f 1 jg f1 � i [ 1 �] L V /"% 1 — Submit Form anfi Form 10-408 "ise 1112015 Approved application Is iYp�'Mt m�irt s7rom tha date p� approvals ,,; r Attachments in Duplicate C. TIN f�(;a-�!a � a^P r e� rr :_I^ _.w �IA'I�IrMlig CDS -- 22 Alpine A Producer Schematic Actual Depths 11113/2017 SLB Downhole Gauge 9504° MD Upper Completion: 20" 94# H-40 Welded 1) 4-:W 12.6#/ft TXP Tubing (1 jts) Conductor to 110' XO to 3-W EUE tubing 2) Shallow nipple profile 3) 3-%7 x 1" Carrico KBMG GLM (xx°) w/ DV 10-14" 45.5# L-80 Hyd 563113TC Surface Casing cemented to surface 2.813" X Nipple 2,028' MD Cameo KBMG GLM, 3 Wx1,. 3 82' MD Cameo KBMG GLM, 3-,/6" x I" 6864' MD Cameo KBMG GLM, 3-1/6" x 1" ' MD 4) 3'W' x 1" Carrico KBMG GLM (xx°) w/ DV 4) 3'h" x 1" Camco KBMG GLM (xx°) w/DCK2 pinned for 2500 psi casing to tbg shear 5) BHP Gauge, Encapsuiated I -Wire 1.5' w/cannon clamps on every joint 6) Baker Premier Packer 7) XN nipple 2.812" ID 8) WLEG Lower Completion: 9) Flexiock Liner Hanger 37' XO 5" Hydril 521 Box X 4-W' TXP pin 10) 414", 12.6#tft, L-80 TXP Liner w/ 17 ball actuated frac ports every until 24,000' MD 11) Perforated pup C toe 7 518" 29.7# L-80 HYD 563XBTCM Intermediate Casing 10,709' VA" 9.3# EUE L-80 Production Tubing 9,706' Production Packer above Alpine C sand 9,562' MD 2.813" XN Nipple 9,61 T MD ZXP Liner Top Packer and Hanger 9,691' MD 4-'A" 12.60 L-80 TXP Production Liner a 6 3/4' Hole TD 24,933' MD CD5 — 22 Alpine A Producer Proposed Schematic iV 7 5M" 29.7 LM HYD S8310OM 1. Inlemiedkde Caifffig 1%709 3 347 SM E L -OD Produ - Tubing '00W PFOdUCti Packer above Al no C sand 5fr Ifir x7-518'Tandem VVbdU4 2.31r XN 9,90WMD - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 11 11 T" 10 Z813'X Nipple T o 1 0 1 1 0 1 1 000 O'Gow .. — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — - j 6 3w Hole TO ZXP Liner Top 4-%012 L410 Padwr and Hanger UP %W PMduction Liner UpperComptation: Lens 2W'9W R40 Welded 1) V12" 12.6#iEt TXP Tubing (I Its) Conductor to 910' XO to 3-Y." EUE futdro 2) Shailm nipple profile �h jai 3) 3 -!/Tx I" Cameo KSMG GLI JxX) W DV r 4) Vq x 1" Cameo KBM3 GLM (xx*l wl DV T 4) 3-Y7 x I' Cameo KBM3 OW w)DCK2 T 1 OmW 46M L-80 pkkned for 25W psi casing to tiro shear Hyd 56INTC 5) SHP Gauge, Encapsulated Mire 1.9 surlace Casing wicannon dafnpr, on everyjobt cemenled to surface 6) Balser Piernfer Packer 7) X nipple 2.81.2" 10 1.9 8) Tandem Wedge 9)WLE(3 2AIT' X Nipple Law Completion: 2,100' MD 9) Floftck Liner Hanger 37' Xi? 5" Hydfil 521 Box X 4-Yj* UP pin 10) 4 7.0,12-6n L-80 TXP Liner w/ 17 W91 scluatedfrac ports every urff, 24.009 MD Perforated pup @too iV 7 5M" 29.7 LM HYD S8310OM 1. Inlemiedkde Caifffig 1%709 3 347 SM E L -OD Produ - Tubing '00W PFOdUCti Packer above Al no C sand 5fr Ifir x7-518'Tandem VVbdU4 2.31r XN 9,90WMD - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1 11 11 T" 10 Z813'X Nipple T o 1 0 1 1 0 1 1 000 O'Gow .. — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — - j 6 3w Hole TO ZXP Liner Top 4-%012 L410 Padwr and Hanger UP %W PMduction Liner Section 1 -Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Jason E. Lyons Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-22 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) herein. Jason E. Lyons, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Jason E. Lyons. I am over 19 years old and have personal knowledge of the matters set forth 2. 1 am Staff Landman for the well operator, ConocoPhiliips Alaska, Inc. ('CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On October 16, 2017, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 1 Bth day of October, 2017. f Jason _LyQn STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 16th day of October, 2017, by Jason E. Lyons. f I;otaryublic, State of Alaska My Commission Expires: ---------------------- $TATS OF ALASKA NOTARY PUBLIC .� lacy � W 12.4W9 CQf occ'iPhilli s Alaska October 16, 2017 To: Operator and Owners (shown on Exhibit 2) Jason Lyons Staff Landman Alaska Land & BD ConocoPhillips Company 700 G Street, ATO -1478 Anchorage, AK 99501 Office: 907-265-6002 Fax: 916-662-3472 jason.lyons@cop.com VIA CERTIFIED MAIL Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for CD5-22 Well AA -92347 (ASRC), ASRC-NPR1, ASRC-NPR2, ASRC-NPR3, and ASRC-NPR4 Colville River Unit, Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit ("CRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the CD5-22 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about October 16, 2017. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on Ieases, AA -92347 (ASRC), ASRC-NPRi, ASRC-NPR2, ASRC-N1'K3, and ASRC:-NPR4 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 415' 2842' T11N R4E 18 Umiat Top Open Interval 4971' 4611' T11N R4E 6 Umiat Bottomhole 1 5271' 2657' 1 T12N R3E 23 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, (7Jason Ly Staff Landman Attachments: Exhibits 1 & 2 ASRC-l4PR1 35 III ASRC-N-PR3 Exhibit I AOL38{ 24 i _.._..__. .�.. _ ADUS72ti Aoi.ase466 k� A DL388466 5 ASRC-NPR2 .�� ASRG•.NP4d ; Gomme River Unit w Frac Points R Tralectory Open interwai Half Mile Frac Point Radius [ r Halt Mile Trajectory Radius ASRC-AAOP2344 a faults within Frao Porta Radjus LI N Wells wtthin Frac Point Radius Alpine PA 24 +h - AK Unit ,..� 0 0.2 0.4 0.8 0.8 1 1.2 1.4 CPAI Leases Miles ASRC-NPR4 15 AOL387206 ,Owc0PhiIIiix Alaska GDS -22 Frac Plat Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, NS Development Manager Owner (Non -Operator): Anadarko E&P Onshore LLC P.O. Box 1330 Houston, TX 77251-1330 Attention: Frank D. Meyer, Director Land - Alaska Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage, Alaska 99503-5963 Attention: Teresa Tram, Resource Development Manager Surface Owner: Kuukpik Corporation P.O. Box 89187 Nuiqsut, AK 99789-0187 Attention: Joe Nukapigak, President Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: Wells within .5 miles 2� A§RC-KARL Colville River gnit Frac Points Trajectory Open Interval Half Mile Frac Point Radius Half Mile Trajectory Radius Wells within Trajectory Radius Alpine PA AK Unit CPAI Leases Alp irie PA ADL386466 NR� jR4 FNAA \ADL3801 ADL367211 ADL388466 ASRC-NPR2 N Conoco fillips 24 0 0.2 ASRGIL923" 1 0.4 0.6 0.8 1 1.2 1.4 CD j_22 Lease Plat Miles 10/1212017 Table 1: Wells within .5 miles Wells within 1/2 mile buffer of well track * Data from SDE layer: AK -WELL -BOTTOM -TD ATDB_DD83 API Well Name Well Type - Status 501032071100 CD5-04 PROD ACTIVE 501032071200 CD5-05 PROD ACTIVE 501032071470 CD5-313PB1 EXPEND PA 501032073600 CD5-01 INJ ACTIVE 501032073700 CD5-02 SVC PA 501032071670 CD5-315PB1 EXPEND PA 501032073400 CD5-07 INJ ACTIVE 501032074100 CD5-08 INJ ACTIVE 501032074861 CDS-99AL1 PROD INACTV 501032074460 CD5-06L1 INJ ACTIVE 501032070700 CD5-314 PROD PA 501032073800 CD5-21 PROD SUSP 501.032074801 CD5-99A PROD ACTIVE 501032072600 CD5-11 PROD ACTIVE 501032075600 CD5-316 PROD ACTIVE 501032071800 CD5-03 PROD ACTIVE 501032072300 CD5-09 PROD ACTIVE 501032072400 CD5-10 PROD ACTIVE 501032075000 CD5-18 PROD ACTIVE 501032075060 CD5-18L1 PROD ACTIVE 501032074800 CD5-99 PROD PA 501032073701 CD5-02A ]NJ ACTIVE 501032071600 CD5-315 INJ ACTIVE 501032074200 CD5-12 INJ ACTIVE 501032074400 CD5-06 ]NJ ACTIVE 501032075200 CD5-20 PROD ACTIVE 501032075260 CD5-20L1 PROD ACTIVE 501032075404 CD5-17 INJ ACTIVE 501032075460 CD5-17L1 INJ ACTIVE 501032071400 CD5-313 PROD ACTIVE 501032075500 CD5-314X PROD ACTIVE SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." 1 SECTION 4 - PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. J SECTION 5 -- DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10 &3/4" casing will be cemented to surface with 271 sx 15.8 ppg class G cement. The 7 & 518" casing will be cemented with 293 sx 15.8 ppg class G cement. summa C All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. C135-22 Updated Frac Pressures -11113/2017 SECTION 7— PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) The 10-3/4" casing was pressure tested to 3,500 psi on rig on 10/20/2017. The 7-518" casing was pressure tested to 3,850 psi on rig on 11/13/2017 The 3.5" tubing was pressure tested to 4,500 psi on rig on 11/13/2017. The 3.5" tubing will be pressure tested to 4,500 psi priorto frac'ing. The 7-5/8" casing will be pressure tested to 3,850 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maadmum Predicted Treating Pressure (MPTP) 7,400 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7 518" Annulus pressure test 3,850 31 /2" Tubing pressure Test j 4,500 Nitrogen PRV 8,500 Highest pump trip 8,000 SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) The 10-314" casing will be pressure tested to 3,500 psi on rig. The 7-518" casing will be pressure tested to 3,850 psi on rig. The tubing will be pressure tested to 4,100 psi on rig. The 3.5" tubing will be pressure tested to 4,100 psi prior to frac'ing. The 7-518" casing will be pressure tested to 3,850 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7 518" Annulus pressure test 3,850 3 112" Tubing pressure Test 4,100 Nitrogen PRV 8,740 Highest pump trip 8,240 h�� SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4' 45.5 L-80 2,090 psi 3,580 psi 7 & 518" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Wellbore pressure ratings Stimulation Surface Rig -Up • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3,600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. Pap.D1f T®tic PUMPTru.* WU" WU cm Stimulation Tree Saver OPEN POSITION CLOSED POSITION JPMOR TO MANDRE. F#d5ERTION) M MN Mr.%Ma ALVE OPERATED AUT (MANWR€L iNSH TFUI • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 41/2 tubing and 1.75" down 3 1/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm VENT VALVE MEN Alpine Wellhead System ILIM01- -- i ,a s AN! PLO Aoflooua weguo� ar ow tom IIV0661A�IBYS7iM N/ AJIIfi�A! 7fFE _ fN1N I L[TIL WRGT S@ALS .. y. SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD thick at the heel of the lateral, generally maintaining the same thickness to approximately 26,000 ft MD. At the toe of the well to the north, the Alpine A sand may become truncated by the UJU as it cuts down section. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 10,709' MD/7,392 TVDSS. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of greater than 400' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ is estimated to be at 9,031' MD17,020' TVDSS. The underlying confining zone consists of approximately 1800' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15.18 ppg. Fracture gradient increases don section. The top of the Kingak interval ranges from 7,460' TVDSS at the heel to 7,340' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-22 wellbore). SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casina & Cement assessments for all wells that transect the confining zone: CDS-09: The 7-518" casing cement report on 12/5/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement jobw as pumped with 15.8 ppg class G cement, displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug did not bump, pressure was held on the casing. The floats were checked and they held. CD5-12: The 7-518" casing cement pump report on 6/26/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.8 ppg LSND. Full returns were not seen throughout the job. The plug bumped at 470 psi and the floats held. CDS-20: The 7 & 518" casing cement report on 2/5/2017 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. Full returns were not seen throughout the job. The plug bumped at 510 psi, and the floats were checked and they held. CD5-22 Fracture Stimulation Area of Review Top of A -Sand WELL NAME STATUS Casing Size Top of A send all Pool Top of Cement Top of Cement Top of Cement Reservoir5tatus Zonal Isolation Cement Operations Mechanical Integrity OilPool(MD) (fYD55) (MDj (TVDSS] Determined By Summary Calculated TOC 12,392' & Packer 12/10/2105, 7-5/8" CD5M ACTNE 7-5/8" 13,252' 7,346' 12,392' 6,810' calculated open hole 11ner for prod uctlon 397 sx 15.8 ppg class G cssing pressure tested to 12,545' 3,50D psi for 30 mins. CD5-12 ACTIVE 7-3/8' 9,059' 7,498' 7,350' 6,829' Sonlc lag Open hole for injection TOC @ 7,350'@ Packer @ 8,274' 95,5 hbls 15.8 PPS Class G j 9128116, passing M171A Cement to 2120 pal CDS-20 AME 7-5/8" 12,962' 7425' 10,742' 6967' Sonic Lag open hole liner for production TOC 019.742' & Packer @ 116 six 15.8 ppg class G 3/12/17, passing MMA I 11284' cement to 3000 nal SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that 2 faults or fracture systems transect the Alpine A formation or enter the confining zone within one half mile radius of the wellbore trajectory for CD5-22. Neither of the two mapped faults intersect the CD5-22 wellbore. The two faults systems were interpreted from seismic data. One fault is mapped to the west of the CD5-22 latera[ and one south of the heel location and confirmed by the CD5-20. The fault in the CD5-20 is single fault plane with 9' of throw. None of the faults that are within the half mile radius of the wellbore extend up through the confining interval and fracture gradients within the top sea[ intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. We do not expect any of our hydraulic fractures to intersect faults seen in this wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage Immediately. Plat 2: CD5-22 Fault Analysis 22 ADL3$4095 1 ADL387211 Alpine PA ADL38846ADL388466 .._�� 6 LP i i ASRC-NPR1 _ ASRC-NPR2 j Ti,R4E ASRC-NPR4 ASRC-NPR3 I AA087888 AA092347� I Colville River Unit 1 ASRC-NPR4 r YM i_1 Frac Points ADL387208 Trajectory 17 Open Interval C Half Mile Frec Point Radius fie' a Half Mile Trajectory Radius 4 ASRC-RA092344 Faults within Free Point Radius N �ocoP may. fillips AJaska Wells within Frac Point Radius --••'Alpine PA 19 CD5-22 — •�AKUnit p 0,2 0.4 0.8 0.8 1 1.2 1.4 Frac Plat CPAI Leases Miles 10/1 S, .-d Fdn F, ja --Fl+ _�'l.1}_F'KJ'�S§e ur_�n:; :d3,. Vtr"'.'u.C::c- R e"e,.. ,. SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-22 will be completed in 2017 as a horizontal producer in the Alpine A formation.The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 11t stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton_ Pumping Services: (Alpine A Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 19,000 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 310 bbl breakdown stage (25# Hybor G) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following attached HES schedule @ 25bpm with a maximum expected treating pressure of 7,000 psi. • 17 stages, — 1,360,00 lbs of 20/40 Wanli proppant • Note due to time constraints the hydraulic fracturing treatment will get split into 2 or 3 days of pumping. 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). "dddq saes ssgssa-1 �� a $�xj 5 d d a d in v� d d v� d d 'n ri d "c1 v� d d o o d a m °i d d '.� .h d d d d h d .m�, d o y o d d d d d d 6 .1 d d m ti a u2 o d '-d 4d d a �.{°�{$� Q C d �8 � li a .vi d d d c d d o d d d �m $s oa ss$��4 asses �� as asaosa �� g pKiggqNqqqqYi g$ gass8 a$ g a$ qq" as PJ 5 � � vv�� N �pq ub¢� v� :`J �eJ �S!�Sp yyq u�q9� ��qpp ��qpo u�qn� uue�f b` m` y�S4p y�qp� �q�qpp YqJ mmSS �S] VqVq�� vqvq�� 1g1qryry q.qpp eqeq�� u`u`�� @@ yqyq�� yqyq Ell 0 0 d H.29 IRI d Stj 81 d d d o I� ISq $ $ d d d d 61 d d d d 5t d R a a S g d d d d R B$ B d d d d d d o� d a a a d d d d d d d a d d d d d �a $$ag$ ?sa$a$1$$a$� $saA.5 s$$ aSBa$as s$s a$$$a$$sss � $§Nassa� aa$saaa$5$�saaaaagaa�a�� as�$g$aase�$aaaaaaaaa��$s $agas$a� F�?:��aoog�a�aBoa a 8� ooEa`a oa$8aaaS�bo "' m a o�ooS' m m x d n��.:t mq m •m1 �'. •mi 4 m FyI Ha Y .°qi mq Ro R mq m Rm g gH� SE 8 m q T! T1 qgm� N •mi •�, ii 51 gg !L �.$�i ti .moi m �q� �BbI 8 ,'pj cm! d !t o S $d O O 8 d 0 d o O 8 !i ti O o$ 0A a3 517i$�� p��g"��n�R A .ggqqm ggql�qqqqqqq.rpqPMAA,nqq4 ggqqqnqqqqqqqqqqqqqqqqqlCq ggqqqqqq ..g BBS B SS SBS aa$ $ URI 1111 BSS -- •• —S c-- g7 SS ¢6g --SyS ^ 4G fiS S Lt—SS �' L Styye a9 Sy �'a "S5 $$gg S d—" SS_ e e e e YI e 2 g 4 C o e L e e q a LL g e e 8 S m o a m m n o m m n m m m m n m a m a o o m n m m m Yo a a m m cu a oy m m n e a o 0 0 m w p m m n n n m o a o m n 03i Cm �iJiJ�� eJ i3n�R tq i1 FS�iF�ed'�'��niJ "��ry i4 C:dn�rip it z .5411 j�rt� Srvh i��A * d 333i ij 2 axd 2$2 T tinen��eP.� �6I2Y z% d dd11 �j I d E 3.99E Lf 19�-99&tL ® d' �.99L l.99L' d.981 .WL A.99L d. Puri tl' 41919Z'99YCd0 uL994L•099GEa Nmm-9999E® uWON -8899C0 .L W06$-WMM RLMI-OMU' I]LC911'009RL� PunW�GV A��Y P-8vPurBtl 3.99E , O1999L-99991 5 L —` iMdBtl Puc6Y P�7Y L n� u u enwLu 884 a oda e o` n � Isl �SaSS$a8a n n 8 n ri d ri a r1 B ni 8a d ri S88$oS8SSa�8.4AA n n n n n n n n of a n e n n TI, n n n n n r1 d o ci 4 d d d d d d d d o o ij�d d d d d d d ri d a d d d d d d d d d d d d d a d d d d n d �� nsasary Hans��sn�n�n��rv�a��s� � a 3 1 1 1 2pjgjsjg 1312 g EIg I g 11 gI 2 1 1 o 9 1 1 ill 2 3 g 3 1 s 2 o a a d d d d o a d d a e d h asa� o �65 e d d o d d d aasas d Is d d d all INm$S$aA.4.44 " $ ba ' Ba a" aa.Ram ."a. _ n as nn n n n nnnnnnn .00n a e n s�� as �¢�RaRx$r�iin °aas 'd o�Nsaa mr„ 6 F T � n t✓J in d m A � N 51 51n rrs-��4 I.. 0� ��Q�N! i in rr� aui rti% "itperrS8i ��R i °§ I O'P 0r p r gSr t ggr n g p p a a grAgrrr r r Arrrrrrr grrrvrnr A:9 IQAAIQAIQ MrrArP AIQAAAnA9A 5 SS 9EW S 9S9S Bn HIM aaSnS� g S MIN a M I��) MUM, 3 3� 3�, M11,51 1 1 3 1 3 1 �--z 611141111 3 13 p3 3# 3 911 �� g 3 <<< 3 3 3 3 3 --. 9 v 5 v 9 v—--— m>>> 9 3 SaQz 4 3 9 5 a a v - p a LL Y SE 5fi5fifi5m S 8fi 6 � 8 ed999933C� fi LL us'¢' fi G S ¢ ¢ g9� i'e ggfig 3 ap _ 1 i fir �3 >vc� �5d 99 m3 5 "L c d t! c t! co 7 ¢ p n `° ca yi. -. c c'2 � >:a 1= itt< 1:v v t pP■ It: d p p p . "d 6 r 6 SL � d k . "a U' tl tl VI l9 N tl tl tl tl O tl tl lA tl@ b tl tl tl b tl p'a°aaa U' tl l7 tl V' tl tl tl tl m tl tl tl i7 b tl tl tl a tl tl tl tl O tl tl tl tl tl tl tl [7 10 tl tl tl tl LS an° !� l9 s AM [' 79 57 M 7L LOOeL"OOOGL® d•SBLL LOS1-ooLSL� w 3.emm"L-OWL$ wmv 3.BBLLLODWOMD Puaev i. ifLL IOCdL•OOR4®4.59411 Waev LOOSl-OOOLL®d.i9La ;Nmv MN;t-OOulti POaev dA%ULOPWOOLOLo PU"11 — Pkv LL Imalu� u Wj-M t4 I"j%u kBJ�I SL la�ul e4Panryl LL lan1�°� QTR$ 6 r -I L—I O Ln R..a I L.i C Ln h � aCL C °I s zn a a p ]p31366 CUSTOMER LEASE FORMA71oN C ophilllp.Almkkine 003-22 Asend API So -i }=199 SALES ORDER DATE- RFD iYblg f1 864 6HSTr'F) 165 Max pressure rp. HALLIEWRTM I— -]SI.2227 l 3Yd3DD0 MOd7 CL -22 UL CL I Prop Stxley Cla. QGN slury Prop Svje SM9. FRIId stege Prappont Gone Rate volume Vafume V k— Total Time lumber De vlptlon OeseN m D..,ptIon (ppgJ mpa row rb6q im" rlhq fhbyam w er 1O�Sswent) 0.2 20140 1,366,356 rlMll 0.0 rpeu Tr 756,792 InItIel DeOp Material Volume 767A 7562 fitO,S 340.3 deck 1p,9DD 278 x17 m 98 6OW '"hie. 34 445 SR 24nee"Chemicals ]p31366 -]SI.2227 l 3Yd3DD0 MOd7 CL -22 UL CL I LV7-2m WC-Sfi tIFS OPdFltrlll SP Inteml AdoYDvaOrvAddWm LnSnrL3DD0 MOIR CL-12UL CL -31 LVF-= %%-WW�.7.11 fvpml m Time sman.ee arra D Wbo 0-11m. FrtmNx- Cm CL9 0,5 rfdl:mmar} mpa row (ball im" hwu Min Additive Rate 0.2 0.2 0.2 mo 9Prr rlMll 0.0 rpeu m, InItIel DeOp Material Volume 767A 7562 fitO,S 340.3 18,900.0 19.2x11 278 ConocclPhillips Alaska, Inc. CDS-011 Planned Design 3 l 3Yd3DD0 MOd7 CL -22 UL CL I LV7-2m WC-Sfi tIFS OPdFltrlll SP (trPml 4PR11 fop.) fvpml m PPm ppm Mae Addltbm Hatel 1.1 LS I CL9 0,5 1,05QA 26-5 0.2 2.1 0.5 Min Additive Rate 0.2 0.2 0.2 0.1 21D.0 5.3 0.0 0.4 0.1 Zona Sidl fc.b 278 x17 m 98 6OW '"hie. 34 445 SR 24nee"Chemicals II -Al ConocclPhillips Alaska, Inc. CDS-011 Planned Design 3 Hydraulic Fracturing Fluid Product Component Information Disclosure FIX-b"DAI awl ivaar G.W.Hwft-My Ak NM,d-. 601032679¢ NORTH R"E Openly Y EWB FMv—as4N wa W. C0642 161=4 LMOWa' TR91 I. -R" vftd-:*o"pM Tr,wpr9.fLepth a TotrllYst6rVesen my Me HydmWID Fr6dRdn4 FTM CmepoMl : Chamled Idadmlfal pintraat MaxIMnrr tlgradlant fwoment ; Trade Nairn SuppWr Pulp— fr1BlYadlall� Se:rtr9e CgermhagenM AddlYps Cealsantralimnm hk9rM-sM Masa Censors Company F7rat Name Lost Name Email Phone Member {CAS 01 1% by Manor KP Ffwd (-Aly Blow, Not en Mier O Baas FkAd IGS 1aa 0..001 7].eeal'e 92917£7 =LS40 FIA-. BRING HdhW n Buffer Lhhdaegar tined aebw hrr B NA -E-6 CROMCIDE HeNb""' Bhrdde akw Bdow t.kWd Below 0 NA 11G HhEbnlmh r'JMr6nk6f LmwBd- Lbled Beaw 0 NA CROSBLINKER Hatdal0n Che.Ilni. LNWB.Wa LKWIRd- O NA LOSWRF_ HaabhrWn MN6fxye eeefed6ni Lhkd Woo, LWbtl Below 0 tlF M047 Kditftn CawdAdllFre Wad Below LMW Belga 0 NA OPTFL0 4U ELAYED RELEASE kfiYWnn Brayer taw Bamrr Lh14d B619e- p NA MIMEER— SP BREAKER HeRmNh Breaker Law R.W. Leled Stlew O NA OEL"M HWII*n GOVAG-A tkadee6a LYWdBeWw aEwr O NA LVr@OD AMO,. 0,4d BeW6r LBled Below 0 NA ZOAIBVHM hbaaa tkkd 4.Ww Mod arab- B NA 'er _ WnU ruaw Ahme i Lm dAhem 1 06543-6 1.40` O.eCNTl4 as _ 4-Bronn3a0ro-1 6257 7 100.001 O.Oorva4 11 6 A.Iluar2d 944017 —.0- ,.496'_3• 529 Omuta 71¢9, HBt6uMMMUM N. AaykM POlinar PmpWWry 1.00! 0.000491 81 81, Hd P b r- Mrk. N* a—W ee*$Tt- 231$71$720 77090, . sac A1naWAT efeWH 101-01-B lad. dW tl.tlu17[.4 1799 Amnenkn .,*Fele TIW-54-0 100.001 0.918994 ism Bmyh eeL Fmp%wry P.M1 0.039191 4ra8 Hiereltn Dory. to* � �1e14r71� CalAte. 1302-745 55. WL 9.21966¢ 761520 eaa 14BOB4I07 sa. W. 0.90.004 47t Guretlaoyleh.hr P.~ary 30.006 0. 00.5]06 4B2 H.0—Ion ai. ck DenWw 7u kdb.4.— $l1$Sfa Elland 5}17.4 6P.M, 4.P-lTs; 6757 Guo, 800030-0 ]00.005 0.2313:1 is= elalaN6 Ha 84743445 30.W1 .. 021)9. 1793 DFNYW R•10 04742-47-0 100.001 1.612616 t3am WAR. 18034&6 43.00• 7.59235+ 614BOD Nn 1-205 .5.000. 0_00307% 299 O"UMOMWOranh Pmw" 30.04. 0.020£3. 1711 H.M. n Dwft Task 0 -M -Tl 1471 = PoppoYp-1 ,apWa{4- n014p1a1yd14nK95hhIE[e4r} 17/097-07-0 5.00\ 0.0935], 28o M pelsajurebm�. 90-204 60.90. 0_059-0 4802 Pw."M mrd. 310z" 5.006 0. 00230, tar pm.rummlwwaito 19709448 W.om O.OL'7'6!ZM Sndhmce .]M— BC09524 1.004 O.00asbe 81 Sedkl d*,We W7,146 4.0W 3.23070, 66dWm .M 2BSBffi-0 —OM30,009 1.00+ 0.00099% 51 ¢00Th. it O.UwbS 2.412 aWm mm 77?EV4 100.006 0.000-16 38 &Wkim dhb -a" 4.10. 0.000001 1 Y12.7aa 300.00* 0.163000 1=3 • TorekWater Vblume sources may include fiesh water, produced water, ardfw recycled wale, "11 almatenla based an ihemmamum potential for concaMnam andthem the teal maybe ever 10M Nuts: For Ftdd alopment Products(pr0o51cls that badn 1Mtr FDP), Mfi0.S level D*Srdormsten has been provided. AU cumporreld In ormstIm llatealwas 0bmined from the mppllers Material Safety Data Shod. JMSDS). As own, the Opmatar is nct reopmolbia for lnamuats adler in—pt to lrdmmaNan, Any qusatl9rhe reperang the content orme MSDs shadd be areried m the auppferw00 provided It ThaOxupa0eh1el Safely and Helm AdmlNehatlolh'a(DSHA}re9"17 h70ram the cdteda for to rladasue of IHIs WwmaNan. Pima note that Fedmal Law pato.1a•proprlOW,"trade serrer,ehd-carldaltal business lnformaBorr and the eWhmfa for howthta Ihlfarmad0n Is 1 tad am an MSDS is eat m 2t CFA 1910.1200 I and M& D, CD5-22 Alpine A Multi -stage Frac Model Frac Design Stage 1 Stage Number Fluid Description Stage Description Prop Conc (ppg) Proppant Description Design Clean Volume (gal) 1-1 Freeze Protect 2,100 1-2 Load Well 1,000 1-3 25# Linear Spacer and Drop Ball 630 1-4 25# Hybor G Flush 12,117 1-5 25# Hybor G Mini -Frac 13,000 1-6 25# Hybor G Flush 12,117 1-7 Shut-in Shut In 1-8 25# HyborG Pad 12,600 1-9 25# Hybor G Proppant Laden Fluid 1.00 Wanli 20/40 9,300 1-10 25# Hybor G Proppant Laden Fluid 2.00 Wanli 20/40 8,900 1--11 25# Hybor G Proppant Laden Fluid 3.00 Wanli 20140 8,600 1-12 25# HyborG Proppant Laden Fluid 4.00 Wank 20140 4,700 1--13 25# Hybor G Spacer and Drop Ball 630 Frac Design Stage 2-9 Stage Number Fluid Description p Stage Description gp Prop Conc (ppg) Proppant Description Design Clean Volume (gal) 2-1 25# Hybor G Pad 12,600 2-2 25# Hybor G Proppant Laden Fluid 1.00 Wanli 20140 9,300 2-3 25# Hybor G Proppant Laden Fluid 2.00 Wanli 20140 8,900 2-4 25# Hybor G Proppant Laden Fluid 3.00 Wanli 20140 8,600 2-5 25# Hybor G Proppant Laden Fluid 4.00 Wanli 20140 4,700 2-8 25# Linear Spacer and Drop Ball 630 Frac Design Stages 10-17 Stage Number Fluid Descripfion Stage Description Prop Conc (ppg) Proppant Description Design Glean Volume gal 10-1 25# Hybor G Pad 12,600 10-2 25# Hybor G Proppant Laden Fluid 1.00 Wanli 20/40 3,024 10--3 25# Hybor G Proppant Laden Fluid 2.00 Wanli 20140 3,024 10-4 25# Hybor G Proppant Laden Fluid 3.00 Wanli 20140 3,192 10-5 25# Hybor G Proppant Laden Fluid 4.00 Wanli 20140 6,006 10-6 25# Hybor G Proppant Laden Fluid 5.00 Wanli 20140 4,452 10-7 25# Hybor G Proppant Laden Fluid 6.00 Wanli 20/40 4,200 10-8 25# Linear Spacer and Drop Ball 630 Totals (17 stages) 25# Hybor G - 756,792 gal 25# Linear -- 10,583 gal 20140 Wanli - 1,366,356 lbs CD5-22 Stages Job Size . I Top TVD Btm TVD Propped Fracture Avg (Ib) (ft) (ft) Half- Height (ft) Fracture length (ft) width (in) 1-9 70,000 7432 7562 500 130 0.249 10-17 90,000 7422 7562 380 1140 0.286 Disclaimer Notice: • This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) Loepp, Victoria T (DOA) From: Sylte, Hanna<Hanna.Sylte@conocophillips.com> Sent Monday, November 13, 2017 2:49 PM To: Loepp, Victoria T (DOA) Subject: CDS-22 (PTD#217-089) Update Attachments: CDS-22 Schematic.pdf, CD5-22 Updated Frac Pressures.pdf Fallow Up Flag: Follow up Flag Status: Flagged Victoria, We set the completion and successfully pressure tested the tubing and IA of CD5-22 this morning. i have attached the schematic showing the final depths of the completion equipment and tubing. One change I'd like to make from the original sundry application is to increase the maximum treating pressure from 7000 psi to 7400 psi, updated pressure tables attached. Please let me know if you have any questions or need more information to review the sundry application. We are expecting to be ready to frac by this Thursday, 11/16. 1 am currently on the slope so please call me on my cell, 713-449- 2197, with any questions. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office: (907) 265-6342 Mobile: (713) 449-2197 Loe , Victoria T (DOA) From: Loepp, Victoria T (DOA) Seft Wednesday, November 08, 2017 9:01 AM To: 'Alexa, Kurt J' Cc: Sylte, Hanna Subject: RE: COP C135-22 (PTD 217-089) Top of Cement Analysis Thanx for the cementing and TOC information. It was very complete. Victoria From: Alexa, Kurt [mailto:Kurt.J.Alexa@conocophillips.com] Sent: Tuesday, November 07, 2017 3:39 PM. To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Subject: RE: COP CD5-22 (PTD 217-089) Top of Cement Analysis Victoria, Just wanted to follow up with you to see if you got everything you needed with respect to Top of Cement. Any questions or concerns, let me know. Cheers Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) From: Alexa, Kurt J Sent: Saturday, November 04, 2017 2:09 PM To:'Loepp, Victoria T (DOA)' <yi_ctoria.loepp@alaska.gov> Cc: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Subject: COP CD5-22 (PTD 217-089) Top of Cement Analysis Victoria, We had our sonic data processed for the CD5-22 well when we tripped out of the hole for a new BHA and it is attached in this email. Schlumberger (email attached) believes top of cement to be located at 8,778' MD / 6,932' TVD and I would agree as the TOC is clearly indicated by the drop in amplitude at that depth on the logs. I have put together a quick couple powerpoint slides in case you didn't want to comb through the entire log. The Intermediate casing shoe is at 10,708' MD / 7473' TVD. Attached are the various versions of the Schlumberger job report, the ConocoPhillips Wellview Cementing Report, FIT test results and the processed recorded -mode sonic log as required for Condition of Approval in the PTD 217-089 Please let me know if you have any questions or concerns, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska Loepp, Victoria T (DOA) From: Sylte, Hanna<Hanna.Sylte@conocophiilips.com> Sent: Wednesday, November 01, 201712:35 PM To: Loepp, Victoria T (DOA) Subject: CD5-22 (PTD #217-089) Proposed Schematic Attachments: CD5-22 Schematic.pdf Victoria, I've attached the proposed completion schematic for CDS-22. As discussed on the phone, i will re -submit this with final depth information when the well is complete in about two weeks, and will let you know if anything else has changed from the information that was submitted in the original sundry application. Please let me know if you have any other questions before then. Thank you, Hanna Sylte Associate Completions Engineer ATO 1712 Office: (907) 265-6342 Mobile: (713) 449-2197 CD5 — 22 Alpine A Producer Proposed Schematic Upper Completion: Lenoth 2W'940 H-40 Welded 1) 4.:W 12.6#/ft TXP Tubing (1 its) Conductor to 11a XO to 3-W EUE tubing 2) Shallow nipple profile 3) 3-'h" x 1" Cameo KBMG GLM (xx') w/ DV 7' 4) 3'W x 1" Cameo KBMG GLM (xx°) w/ DV 7' 4) 3-'," x 1" Cameo KBMG GLM (xx°) w/DCK2 7' 10414" 45.5# L-80 pinned for 2500 psi casing to tbg shear Hyd 5Mi3TC 5) BHP Gauge, Encapsulated I -Wire 1.5' Surface Casing w/cannon clamps on every joint cemented to surface 6) Baker Premier Packer 7) X nipple 2.812" ID 1.5' 8) WLEG 2.813" X Nipple Lower Completion: 2,900' MC 9) Flexiock Liner Hanger 37' XO 5" Hydril 521 Box X 4-11V TXP pin 10) 4'f", 12.6#fft, L-80 TXP Liner w/ 17 ball actuated frac ports every until 24,000' MD 11) Perforated pup @ toe 5W'29.7# L-80 HYD 563XBTCM Intermediate Casing 10,709' 2.813" XN Nipple 9,600' MD 3=/2' 9.38 EUE L40 Production Tubing 9,690' Production Packer above Alpine C sand 9,550, ZXP Liner Top 4-W' 12.60 L.80 Packer and Hanger TXP 680` Production Liner 24.00' MD 6 3/4" Hole TD --26,000' MD __- Paragraph 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CD5-22 (PTD No. 217-089; Sundry No. 327-490) Sub Paragraph Section----�— ------ Complete? AOGCC Page 1 November 14, 2017 Dated 10/16/2017. Provided with application. On (a) Application for 10/16/2017, operator sent Notice of Operations (Notice) to Sundry Approval (a)(1) Affidavit all owners, landowners, surface owners, and operators PKB _ within one-half mile radius of proposed well trajectory. _ (a)(2) Plat Provided as Exhibit 1 and Plat 1 within application PKB (a)(2)(A) Well location Legal description of well, (surface, target and bottomhole PKB j locations) provided in Notice dated 10/16/2017. (a)(2)(B) Each water well within X mile— None per DNR Water Estate Map (10/19/17) PKB (aJ(2)(CJ Identify all well types within 7�I1 Wells within % miles radius of CRU CDS-22 wellbore (dile trajectory. Wells identified, as wells as well type and well PKB !status iNo freshwater aquifers or underground sources of drinking (a)(3) Freshwater aquifers: geological ! water within a Y2mile radius of proposed wellbore name trajectory. (See Conclusion number 3 of the Area Injection PKB Carder AIO 018.000 -Colville River Field.) (a)(3) Freshwater aquifers: measured andNA true vertical depth _ PKB (a)(4) Baseline water sampling plan _- NA PKB (a)(5) Casing and cementing information provided VrL (a)(6) Casing and cementing operation assessment provided VTL _ (a)(6)(A) Casing cemented below lowermost freshwater aquifer and ; per AEO 018.000 and current AIO 0180, no freshwater aquifers present. PKB conforms to 20 AAC 25.030 (a)(6)( B) Each hydrocarbon cone is !Cementing records provided. VfL _ isolated _ _ (a)(7) Pressure test: information and I -test plan to test casing to 3850 psi and tubing to 4500 psi prior pressure plans for casing and tubing l installed to frac. As per email 11/13/17 CDW in well AOGCC Page 1 November 14, 2017 Well 20 AAC 25.283 Hydraulic Name No. CRU CDS-22 Fracturing Application — Checklist (PTD No. 217-089; Sundry No. 317-490) Section.---._-.___T_� Sub-Paragraph 6890 psi, tubing 10160 psi, surface piping 10000 psi, tree (0)(8) Pressure ratings and schematics: SIA wellbore, wellhead, ROPE, treating head saver 15000 psi._ CDW (a)(9J(A) Fracturing and confining zones: i-racturing zone will be the Alpine A sandstone. It is - 30' i litholagic description for each cone thick, true vertical thickness. Upper confining zones are !the Miluveach, Kalubik and HRZ shales, 400+ feet thick. PKB (a){9}{8) Geological name of each zone The lower confining zone consists of approximately 1,800' E of Kingak shales. (a)(9)(C) and (a)(9)(D) Measured and true ! 1-op Alpine A is estimated at 10,709' MD (7,392' TVDss), vertical depths Top HRZ is estimated at 9,031' MD (7,020' TVDss). PKB Kingak shale not penetrated by CDS-12. Alpine A est. fracture gradient is 12.5 ppg. a 9 E Fr p f ( )( )() acture pressure for each zone Miluveach est. fracture gradient is 15 ppg and KalubIVHRZ PKB fractureradient is 1fi g ppg. Kingak est. fracture gradient is 15-18 ppg. (a)(10) Location, orientation, report on mechanical condition of each well _ Provided CDW (a}(11) Sufficient information to determine u wells will not interfere with containment Provided CDW within X mile — Operator identified two northwest trending fractures or ' faults within the AOR. Neither of the two mapped faults (a)(11) Faults and fractures, Location, transect the Alpine A formation within Y2 mile radius of the orientation CDS-22 wellbore trajectory. One fault that transects the wellbore above the Alpine has a throw of 9 feet. (a)(11) Faults and fractures, Sufficient PKB j information to determine no interference Principal stress direction in the Alpine A formation, along with containment within X mile I with the well path, is northwest-southeast. All of the fractures will be longitudinal, running parallel to the wellbore. AOGCC Page 2 . November 14, 2017 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CDS-22 (PTD No. 217-089; Sundry No. 317-490) Paragraph Sub -Paragraph Section Complete? ----�_ _ ___._�1�—_-- . - _ --- �_--- _-_----------- _ _-_----------- __ J -__— AOGCC Page 3 November 14, 2017 Mitigation: If there are indications that a fracture has intersected a fault during fracturing operations, the operator would flush and terminate the stage immediately. (a)(12) Proposed program for fracturin- g operation (Provided CDW (a)(12)(A) Estimated volume 1366K lb prop, 18,721 bias clean vol, 20,126 bbl' slurry - CDW _ detailed (x)(12)(8) Additives: names, purposes, concentrations detailed i CDW _ (a)(12)(C) Chemical name and CAS number � Confidential chemical CAS provided or previously provided of each _ and on file with AOGCC. CDW (a)(12)(D) Inert substances, weight or volume of each detailed CDW (a)(12)(E) Maximum treating pressure with ! supporting info to determine Max 7400 psi, 25 bpm. As per email 11/13/17 CDW I appropriateness for program_ _ (a)(12)(F) Fractures - height, length, MD and TVD to top, description of fracturing Table provided. 17 intervals with 6 to 14 stages CDW model _ (a)(13) Proposed program for post- fracturing well cleanup and fluid recovery Class I disposal well plan CDI-01. CDW (b)Testing of casing w Plan to retest to 3850 psi casing prior to frac. Max IA or intermediate Tested >110% of max anticipated pressure during frac stated as 3500 psi. PRV set as 3600 psi. As per CDW casing email 11/13/17 (c) Fracturing string (c)(1) Packer X100' below TOC of Outlined in provided table VTL production or intermediate casing (c)(2) Tested >110% of max anticipated Plan to test surface to 9000 psi. Plan to test tubing to 4500 pressure differential psi. Maximum differential pressure is 3900 psi (7400 psi CDW string with 3500 IA backpressure). As per email 11/13/17 AOGCC Page 3 November 14, 2017 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. CRU CDS-22 ( PTD No. 217-089; Sundry No. 317-490) Paragraph —� -- - - - Sub -Paragraph Sectian j Complete .....------ AOGCC Page 4 November 14, 2017 Surface line tested to 9000 psi. 8000 psi pump trip, (d) Pressure relief Line pressure <= test pressure, remotely nitrogen PRV set as 8500 psi. IA PRV set at 3600 psi. Max valve controlled shut-in device I treating pressure estimated 7400 psi. As per email CDW 111/13/17 (e) Confinement Frac fluids confined to approved CDW formations (f) Surface casing Monitored with gauge and pressure relief pressures device CDW (g) Annulus pressure monitoring & 500 psi criteria notification -� _ (g)(1) Notify AOGCC within 14 hours (02) Corrective action or surveillance - (g)(3) Sundry to AOGCC (h) Sundry Report - (i) Reporting -�- (i)(1) Fra_cFocus Reporting (i)(2) AOGCC Reporting: printed & _ electronic 6) Post frac water sampling plan (k) Confidential Clearly marked and specific facts information supporting nondisclosure (1) Variances Modifications of deadlines, requests for requested variances or waivers AOGCC Page 4 November 14, 2017