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Home My WebLink About2018-12-21_318_574STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DEC 2 1, 2018 1. Type of Request: Abandon L1 Plug Perforations ❑ Fracture Stimulate 0 Repair Well LJ sP>'�6#d Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 185-155 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21390-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? IV A KRU 3C -D8 Will planned perforations require a spacing exception? Yes ElNo 0 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL25629 / ADL25634 I Kuparuk River Field 1 Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft) Effective Depth MD: Effective Depth TVD MPSP (psi): Plugs (MD): Junk (MD): 10,234' 6,839' 10,137' 6,775' NONE 10068710084' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 116' 116' Surface 5,171' 9.625" 5,206' 3732' Intermediate Production 10,224' 7" 10,258' 6830' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9904-9921, 9938-9954, 6623-6634, 6645-6656, 3.500" L-80 9,962' 9976-10004 6670-6689 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - PACKER, BAKER, PREMIER MD= 9652 TVD= 6459 SSSV-NONE NONE 12. Attachments: Proposal Summar Wellbore schematic❑ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development E Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/4/2019 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. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: ,CompIetI9x@ Engineer Contact Email:.Sandeep.pedam@conocophillips.com g Contact Phone: ,907) 263-4724 Authorized Signature Date: 1 2jZ0Tib COMMIS ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 4 Plug Integrity ❑ BOP Test El Mechanical Integrity Test❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'i Yes ❑ No ❑ Spacing Exception Required' Yes ❑ No ❑ Subsequent Form Required: APPROVED BY 1pproved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 Revised 4/2017 Approved applicon lir 1 n $ Lm the date of approval. Attachments in Duplicate Conoco hilli s p Alaska Paul K. Wharton Staff Landman P.O. BOX 100360 — Suite ATO 1482 Anchorage, Alaska 99510-0380 Phone (907) 2634076 Paul. K.Wharton@oonocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3C -08A Well Kuparuk River Unit, Alaska ADL 25634, KRU Tract 21; ADL 25629, KRU Tract 14; and ADL 25628, KRU Tract 15 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") 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 3C -08A Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about September 24, 2018. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). 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 to you. If you require any additional information, please contact the undersigned. Very truly yours, K W tv ffhA1 Paul Wharton Staff Landman cc: Rebecca Swensen 3C -08A Hydraulic Fracturing Notice Letter September 24, 2018 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non -Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Weston Nash Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Suite 406 Attention: Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601 (Zip for PO Box 99519) Anchorage, AK 99503 (Street zip) Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7t" Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director 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 Paul K. Wharton Request of ConocoPhillips Alaska, Inc. for } Hydraulic fracturing for the KRU 3C-08 Well ) under the Provisions } of 20 AAC 25.280 STATE OF ALASKA ) j §§ THIRD JUDICIAL DISTRICT Paul K. Wharton, being first duly sworn, upon oath, deposes and states as follows: My name is Paul K. Wharton. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 1 am Staff Landman for the well operator, ConocoPhil lips Alaska, Inc. ('C PAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about September 24, 2018, 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 241h day of September, 2018. Paul K. Wharton STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 24th day of September, 2018, by Paul K. Wharton. Notary Public, State of Alaska ` ALAS NOT&RY PUBLIC REWCA SWENSEN mon res A 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) SECTION 3 - FRESHWATER AQUIFERS 20 AAC 25.283(A)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a % mile area beyond and lying directly below the Kuparuk River oil and gas producing field" 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. 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 9-5/8" casing cement pump report on 7/17/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 543 bbls of Arctic Set III and 70 bbls of Class G Cement. The 7" casing cement pump report on 7/24/1985 shows the the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 450 Sx (92 bbls) of Class G Cement. Summa 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 design limits. Section 7 -- Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operation must submit and Application for Sundry Approvals (Form 10-403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (7) pressure test information if available and plans to pressure test the casings and tubing installed in the well; On 05/26/2018 the 4-5/8" casing passed a MIT -OA; was pressure tested to 1,800 psi. On 08/22/2018 the 7" casing passed pressure test to 2000 psi. On 11/23/2018 the tubing was pressure tested to 7000 psi after RWO On 11/24/2018 IA was pressure tested to 2750 psi with 1500 psi on tubing The tubing will be pressure tested to 6150 psi and IA to 2750 psi before frac. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,850 Annulus pressure during frac 2,500 Annulus PRV setpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 6,150 Nitrogen PRV 8,550 Highest pump trip 8,050 Table 1: Required Pressures 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 9 & 5/8" 36 J-55 3,520 psi 2,020 psi 7" 26 J-55 4,890 psi 4,320 psi 3&Y2" 9.3 L-80 11,560 psi 12,120 psi 2 & 3/8" 4.6 L-80 11,200 psi 11,780 psi Fable 2: Pressure Ratings Stimulation Surface Rig -Up T-,Ldwnd PurV Tfuck POP,V'rMk T,Ae PAW, T-,Ldwnd PurV Tfuck POP,V'rMk Tree Saver With Wellhead OIL STAT S Enqy Serkes (Canada) Inc. QUOTrz#: Maximum Allowable Pumping Rates Z250 1.438 3 1118 & 4 VIS with tapemd me PROPOSAIJ. nATE: 3.750 101rlinin .2.750-6trPirnin 2,360 4viii—n www.ozescanada.com Tree Saver Rating: 15,000 psi Is MIMIrl 24 mlmin Wellbore schematic X-08 Prop*sed CTD Schematio 1d FNIiY sI' T 3 -VT 020 L-93 EUE TubkW to mrftm 3-1r.x 14lTMMM Camwgas:4trriardrL4so2iZ5, 5271% bf.'eZ 817W. 071 & MOM- Bake- Pmrier padw:a ON V3 QM4' M3 !t 5t mw G 'top -*Tw&m WK%p 01 Am f 1 1.1' MD X -N ple 0 OM A13'"13, min XII TQpGfTMdemMbdg*#2Ass OMC M 13-1W X -h a 9953' LID ;2.878' ffdn IDI, Tubing t3A p 9965 MD ;'OQU�. wM ass : -ta-B.ry Cc 2 �.Mll Im5l' I 2-M, El.ark'-Inr� �n b1l; L4-�FMC M�ftt �,Jg �7 tifi. L4CP FJO K'" L Im fz -M �40 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 Kuparuk Interval is approximately 313' TVD thick, with the top and base picked at 9,543' MD/6,307' TVDSS and 10,024' MD/6,620' TVDSS, respectively. The Kuparuk Interval is composed of fine-grained sandstones, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 0.65ppg. The overlying confining zone consists of greater than 349' TVD of Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 15ppg and 16ppg respectively. The top of the overlying confining zone is picked at 8,987' MD/5,958' NDSS. The underlying confinement zone consist of approximately 520' TVD of mudstones comprising the Miluveach Shale. The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. 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 the 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 one-half mile radius of the proposed wellbore tractor. Casing & Cement assessments for all wells that transect the confining zone 1R-31: The 7" casing cement report on 1/24/1995 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 60 bbls of 15.8 ppg cement. The plug bumped, and the floats were checked and held. 111-33: The 7" casing cement report on 12/29/1994 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 73 bbls of 15.8 ppg cement. The plug bumped, and the floats were checked and held. 3C-091-1-0113131: The 7" casing cement report for 3C-09 on 7/12/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 90 bbls class "G", 15.8 ppg, cement. The plug bumped, and the floats were checked and held. 3C-10AL1 and 3C-10AL1PB1: The 7" casing cement report for 3C-10 on 7/3/1985 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 77 bbls of 15.8 ppg cement. The plug bumped, and the floats were checked and held. 3K-18: The 7" casing cement report on 9/10/1986 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 100 Sxs of 12.0 ppg cement followed by 300 Sx s of 15.8 ppg cement. The plug bumped, and the floats were checked and held. UGNU SWPT 1: The well has been plugged and abandoned as of March 1993. The abandonment operation began with 205 Sx G cement around the bottom of the casing, 450 Sxs G cement thru DV at 3583', squeezed 250 Sxs G cement at 3491-3521', squeezed 50 Sxs G cement at 3109-3111', and squeezed 125 Sxs G cement at 3004-3093'. a m 3 O a N a N N IV 040 C-4 O O N = a a Ln co m 0 t] p a Iv GG O Iq r1 O 0 00 0 a a N C N a 'a N C N M1 -i 0 =~ N Q d a O G N 1-1 N F J r1 r U- r N O U b \ \ 14H F F N \ a � l\D L o c a a O a O a p rn a IN ¢\ o Geo Q\ o '° O Q m _ F Q COL Q- M 0-1 M O M O Z N N N l6 N O N d V) co E C r 00 0 0N a ,-r t: to a -a E a m E rn a -p E 1f1 rn-1-0 � 1O a a 00 m a v C 0) a V a .m -i ,y — a a -a +'' .np +' x a+ W Q E p. a C-\ O Cr �" a a, R � m O E C7 C7 a E C7 Go a 0) W m " n m E v m c o D a s s a s E V-0 a m to c cn Go n co m co in .� " a n N a l7 to a0 d N L) E 01 t j m ,i b m H GO -p 01 \ - -p r lC V -G t In a 'O D_ m O_ -O a 'O x d4 a+ a a a l7 p m a 61 C U HN N a m N i Q- N G\ Ln t O N O OLn N N IV .0 a N N N m aL5 O N pG CL a E E a f0 M 'i N ~ .O "G V Sa 'O M U Q J d u Q n O O CL a-1 O N N l0 m he c p ca m x a -t _ +' C f6 t6 lE IG O a rNi o v `m wa L E m m y m u m o u v IE a a m d O O_ C O C O N m a Y C O L y -p C ` 'O O Of 3 C N a s Y �..1 a M Y a a Y m R C IG E a E l la N0 m� m� m a Q � ¢ ILg � a s .Ns to Ln a c O a a C 2 a O O C O p C a C C (j C O �• G Q a Q O a O ._ O CLI a .1 a O a a w = C O � CL E E G0 0 F a J J F F F N J J U U V U V U U to u W ON 4-- l00 N.-1 r C C GOO � C Qa O M h E C p F a U C C C C OA c y _ H W \ 00 (� m M m _ M o r r r N N N 7 C 7 �O. V1 C VS Q p oG 'D w O W O p X X 4 Z d w OAC a w Z X u1 a � r1 � m 4 2 0 J Q J N M 00 O O C)m "I O H Z oC K H r1 m M m M m O O GOO M 001 N m V$ Vn %a V1 lM10 V1Ln eoO� r-4 N H rm-I .m -I eM-I p Ory, m IN m 01 1 ONL Ol T ONl a 0 0 0 V1 0 0 0 0 In Ln Int Ln 4 Vi i V) .. V} SECTION 11— LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFIING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well and other subsurface information currently available that there are six mapped faults that transect the Kuparuk Interval and enter the confining zone (Kalubik and HRZ) within one half mile radius of the wellbore trajectory of the planned 30.08 CTD wellbore. The three northwest -southeast trending faults and the two north -south trending faults around 3C-08 terminate within shales of the confining zone, and fault throw ranges between 15-140' (see table below). One mapped fault intersects the wellbore within the Kuparuk B2 shale and has a throw of 5'. This fault is not visible within the seismic data and is mapped based on stratigraphic thickness and well log correlation with surrounding wells. Fracture gradients within the confining zone will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining zone is discussed in Section 9. 3C-08 Area Faults Orientation Throw in Feet Fault #1 Northwest -Southeast 130-140' Fault #2 Northwest -Southeast 20-30' Fault #3 Northwest -Southeast 15-20' Fault #4 North-South 35-55' Fault #5 North-South 15 -Oct Fault #6 Unknown 5' Section 12 — Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 3C-08 was completed in 1985 as producer in the Kuparuk A sand formation. The well was completed with 7" production casing and 3.5" tubing. The well will be drilled as a CTD single lateral with three frac sleeves and a perf pup at the toe. A multi -single stage frac will be pumped through the A -sand (3 stages through sleeves and 1 stage through the perf pup) with 225,000MIbs 20/40 Carbolite proppant and 25,000 Mlbs 20/40 Carbo Scale Guard proppant. Proposed Procedure: Halliburton Pumping Services,: (C Sand 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 12 clean insulated Frac tanks, with a berm surrounding the tanks that can hold - single tank volume plus 10%. Load tanks with 100° F seawater (approx. 4810 bbls are required for the treatment with breakdown, maximum pad, and 420 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,500 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 238 bbl breakdown stage (25# Hybor) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 15 BPM as quick as possible, pressure permitting. Increase annulus pressure to 2,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with x maximum expected treating pressure of 7,850 psi. Section 13 — Post -Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. 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