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DIO 037
Image Project Order 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. _ ©3 Order File identifier Organizing (done) ^ Two-sided III II II ~ I II I ) I I I II I ^ Rescan Needed I II I III II ~~ I I III II I R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: fs~ Project Proofing I II I II III III II I I III BY: Maria Date: /~ /s~ Scanning Preparation x 30 = + =TOTAL PAGES BY: Maria /~ Date: // (Count does not include cover sheet) '~ / o !s/ Production Scanning Stage 1 Page Count from Scanned File: e~~,~ (Count does include cove sheet) Scanning is complete at this point unless rescanning is required. Page Count Matches Number in Scanning P eparation: YES _ BY: Maria Date: $ 5 Stage 1 tf NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: NO /s/ f M NO Illilllllllll!IIII ReScanned Maria Date: /s/ Comments about this file: o ~v~~~ee iuuiuimomu 10/6/2005 Orders File Cover Page.doc • Disposal Injection Order #37 East Barrow #15 1. February 24, 2010 North Slope Borough Application for DIO 2. March 26, 2010 Notice of Public Hearing, Affidavit of Publication, E -mail list, Bulk mail list 3. May 13, 2010 Fed -Ex proof of delivery 4. May 18, 2010 Public Hearing Transcript 5. May 20, 2010 North Slope Borough Application for DIO 6. June 8, 2010 E -mail re: DIO 10 -01 and 10 -02 7. July 6, 2010 Response to AOGCC from Bill Van Dyke re: South and East Barrow Gas Fields 8. November 14, 2011 PRA request for approval to dispose non- hazardous fluids 9. March 5, 2012 PRA request for approval to dispose non- hazardous fluids Disposal Injection Order #37 East Barrow #15 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF the North Slope ) Disposal Injection Order No. 37 Borough for disposal of Class II oil field ) Docket No. DIO -10 -02 wastes by underground injection in a ) portion of the Barrow Sandstone that is ) Barrow Sandstone, Kingak Formation not capable of viable production in well ) South Barrow No. 15 Well South Barrow No. 15, Section 23, T22N, ) East Barrow Gas Field R17W, Umiat Meridian ) North Slope Borough, Alaska ) ) July 26, 2010 NOTICE CLOSING DOCKET BY THE COMMISSION: The Commission has the closed the Docket in the above captioned matter. ENTERED AND EFFECTIVE at Anchorage, Alaska and this 26th day of July, 2010. BY DIRECTION OF THE COMMISSION 4 bri AA) j f J J. Colombie S cial Assistant to the Commission • s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF the North Slope Borough for disposal of Class II oil field wastes by underground injection in a portion of the Barrow Sandstone that is not capable of viable production in well South Barrow No. 15, Section 23, T22N, R17W, Umiat Meridian Disposal Injection Order No. 37 Docket No. DIO-10-02 Barrow Sandstone, Kingak Formation South Barrow No. 15 Well East Barrow Gas Field North Slope Borough, Alaska July 26, 2010 IT APPEARING THAT: 1. On March 1, 2010, the North Slope Borough (NSB) requested that the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) authorize underground disposal of Class II oil field waste fluids into a depleted portion of the Barrow Sandstone through the South Barrow No. 15 (SB 15) wellbore, which is located in the East Barrow Gas Field. 2. In accordance with 20 AAC 25.540, notice of opportunity for a public hearing was published in the ANCHORAGE DAILY NEws on March 29, 2010, on the State of Alaska Online Notices on March 26, 2010, in the Arctic Sounder on April 1, 2010 and on the Commission's Web site on March 29, 2010. The scheduled hearing date was May 18, 2010. 3. The Commission received no comments, protests or requests for a public hearing. 4. The public hearing was held on May 18, 2010. 5. On June 17, 2010, the Commission requested additional information from the NSB. The NSB responded to this request on July 6, 2010. 6. Information submitted by the NSB and public well history records are the basis for this order. FINDINGS: 1. Location of Well and Adjacent Wells (20 AAC 25.252(c)(1)) SB 15 is a vertical well that was drilled and completed to a total measured depth of 2278' during August and September 1980.' The surface and bottom hole locations of the well are 990' from the north section line and 2640' from the east section line of Section 23, Township 22N, Range 17W, Umiat Meridian. The plat included with the NSB's application indicates that there are no wells within a %-mile radius of SB 15. The nearest well is South Barrow No. 19, which lies about 3200' to the southeast. ' All depths presented herein are measured depths within the SB 15 wellbore unless otherwise specified. • • Disposal Injection Order 37 East Barrow Gas Field South Barrow No. 15 Well July 26, 2010 Page 2 of 7 2. Notification of Operators/Surface Owners (20 AAC 25.252(c)(2) and 20 AAC 25.252(c)(3)) The NSB is the only operator within a %-mile radius of the proposed disposal well. Ukpeagvik Inupiat Corporation (UIC) is the only surface owner within a'/-mile radius of SB 15. NSB and UIC were both provided a copy of the application for disposal on or about February 24, 2010, according to the "Affidavit of Notice to Surface Owners and Operators" provided by the NSB. 3. Geological Information on Disposal and Confining Intervals (20 AAC 25.252(c)(4)) The proposed disposal interval is the Barrow Sandstone, which is an informal member of the Kingak Formation. The Barrow Sandstone, which was deposited in a marine environment, consists of silty, very fine-to fine grained, moderately sorted sandstone that contains pyrite, siderite, glauconite, and calcite and is commonly interbedded with siltstone and shale. In SB 15, the existing perforations in the potential injection interval are from about 2054' to 2064' and from 2110' to 2151' (see Figure 1, below). In the East Barrow Gas Field, porosity for the Barrow Sandstone ranges from 2 to 28 percent, averages 18 percent, and has a median value of 18 percent. Permeability for the Barrow Sandstone ranges from 0.01 to 3295 millidarcies, averages 133 millidarcies, and has a median value of 13 millidarcies. Approximately 135' of shale and siltstone of the Kingak Formation immediately overlying the Barrow Sandstone will provide upper confinement for injected fluids. Interpreted cross sections indicate this upper confining layer is laterally continuous across the South Barrow Gas Field. A structure map provided by the NSB indicates there are no faults in the vicinity at the depths that correlate to the injection and confining intervals. Lower confinement will be provided by several three- to five-foot thick shale and siltstone beds that lie beneath the Barrow Sandstone and underlying Argillite basement rock. 4. Evaluation of Confining Intervals (20 AAC 25.252(c)(9)) A separate fracture stimulation model has not been prepared. The confining interval is judged to be adequate to prevent propagation of fractures through the overlying Kingak shale and siltstone confining layers based on the limited nature of the anticipated total disposal volume (between 30 to 50 thousand barrels of waste) and evidence indicating no problems were encountered during production well fracture stimulations or while conducting disposal operations in well South Barrow No. 5, as authorized by DIO 5, 5. Standard Laboratory Water Analysis of the Formation (20 AAC 25.252(c~10)); Aquifer Exemption (20 AAC 25.252(c (11~ Laboratory-measured total dissolved solids (TDS) concentrations were provided for water samples from five wells in the East Barrow Gas Field. All samples exceeded 10,000 milligrams per liter. An aquifer exemption is not necessary. • • Disposal Injection Order 37 East Barrow Gas Field South Barrow No. 15 Well July 26, 2010 Page 3 of 7 Correlation Depth Resis Porosity GR <M D ResD RHOt3 10 API 24 .2 OHMM 20 .65 GM/CC 2.6 -. ,_ T'•5~'DS~> Rests and -Sift -Shale __ __ __ _ ~ _ ~~- ow Poro .2 OHMM 20 SP T'':~Ci ResS NPOR 100 MV 10 .2 OHMM 20 0 <M p DTCP(DT) 70 US~FT 7 Pebble Shale ~ - ~~~€;, ~~~~°~4 ~ _a0 Confitti~t- - { ~~'°~ ~ Walak a Sandst one ~ ~ - L ~~~~ cr C~a ' ° , t nconform it : . ~ y ~"~' '' ~~~V k~ 6 * k ~ ~v: Kingak Shale ~ ~~~ _ -190 -1960 I~~tei`vFt ~1i -- -- _ `~ 2000 ~~~ii,0 -1990 - - --- _ ~ ' ., 4 ,1+ ry ~(~ ,'i_i -200U ~ _ __ __ -2OLCI - ^~ :. ii60 Perforatio -20x0 ' ;tip -~ - -. - -- -2060 _ - 2100 Y -=- _ ; Perforatiofi ; `_ r.-- - Barrow Injcc4ifi ^ -- - Sandstone Interti~~ _- t.._ -- _ - y ,_. -2160 _ ~_ ~: _ ,: _ ,_. 2200 ,quo ~_ - -2180 _ _ ~ ~___ - _ . . -:.c00 ~ ~ ~ - _ 22ac~ -- . . . -x,-20 ~~i3a Figure 1. South Barrow 15 Well Log Displaying Injection and Confining Intervals (Horizontal gridlines represent five-foot increments of measured depth) • • Disposal Injection Order 37 East Barrow Gas Field Page 4 of 7 South Barrow No. 15 Well July 26, 2010 6. Well Logs (20 AAC 25.252(c Log data from SB 15 are on file with the Commission. 7. Demonstration of Mechanical Inte rite and Disposal Interval Isolation (20 AAC 25.252(c)(6)) SB 15 was completed as a gas production well in September 1980. The well has 13-3/8" conductor casing is set at 80' (80' true vertical depth, or TVD), 9-5/8" surface casing set at 1514' (1514' TVD), and 7-inch production casing set at 2198' (2198' TVD). The well is equipped with 2-7/8" tubing hung at 2155' (2155' TVD). The well is not equipped with a packer in accordance with Conservation Order 233. Surface casing was cemented to surface. The production casing was cemented into the surface casing using a combination of the primary cement job and freeze protection/cementing operations via cementing collars set above the surface casing shoe. No cement bond log is available. Allowing for 30% hole enlargement, sufficient cement was pumped to place 600' of cement above the top perforation. Cumulative production from SB 15 was nearly 733 million cubic feet and the well was on line continuously between January 1982 and October 1992. From about June 1987 until the well was permanently shut in during June 1993 the well typically produced in the 120 to 180 MCFPD range. In its July 6, 2010 response to Commission questions, the NSB indicated that SB 15 is a high-maintenance, poor performer that is subject to hydrate formation. Its limited production capacity no longer justifies the operational and maintenance efforts required to keep the well online. In addition, SB 15 is not connected to the limited road infrastructure, so ground access is only available during the winter season. The NSB requests a waiver to the mechanical integrity test requirements of 20 AAC 25.252 (d) and 20 AAC 25.412 (e) as allowed by 20 AAC 25.450 (a). The standard mechanical integrity test is not possible due to the absence of a packer. The NSB instead proposes daily monitoring of tubing and annulus pressures during the limited-duration injection operations, which are expected to occur during a single winter season. 8. Disposal Fluid Type, Composition, Source, Volume, and Compatibilitywith Disposal Zone (20 AAC 25.252(c)(7~) SB 15 will be one of two disposal wells planned to support the NSB's 2011 - 2012 well work program. The NSB intends to use SB 15 to dispose of drilling, production, completion, and workover wastes originating from exploration and development well activities in the East Barrow, South Barrow and Walakpa gas fields on the North Slope. The NSB projects the waste disposal volume to be between 30 and 50 thousand barrels. The NSB estimates the daily injection volume will average 1000 barrels per day, with injection rates between 2 and 7 barrels per minute. Information provided by the NSB demonstrates the fluids to be disposed are compatible with the disposal zone. 9. Estimated Injection Pressures (20 AAC 25.252(c~~ • • Disposal Injection Order 37 East Barrow Gas Field South Barrow No. 15 Well July 26, 2010 Page 5 of 7 The NSB estimates that the surface injection pressure will vary between 400 and 800 psig. The maximum pressure encountered while stimulating SB 15 was 1300 psi. The injection pump has a 3000 psig working pressure, and it is equipped with a 2400 psig pressure safety relief valve. 10. Mechanical Condition of Wells Penetrating the Disposal Zone Within %-Mile of SB 15 (20 AAC 25.252(c,~(12~) There are no wells within a %-mile radius of SB 15. 11. Underground Injection Control Variances (20 AAC 25.450) Regulation 20 AAC 25.450(a) allows the Commission to authorize less stringent requirements for casing and cementing, tubing and packer mechanical integrity, operation and monitoring, provided that the reduction in requirements will not result in an increased risk of movement of fluids into freshwater. CONCLUSIONS: 1. The requirements and conditions for approval of an underground disposal application in 20 AAC 25.252 are met. 2. Disposal injection of Class II wastes into the Barrow Sandstone in the SB 15 well will not cause waste. 3. The proposed Barrow Sandstone disposal interval is sufficiently porous, permeable, and thick to receive the proposed volume of injected wastes. Overlying and underlying strata will be effective, waste-confining barriers. 4. Fluid compatibility is not an issue for the proposed, limited disposal operations within SB 15. 5. All water within the Barrow Sandstone exceeds 10,000 milligrams per liter TDS. Therefore there is no possibility of contamination of freshwater. 6. Despite the absence of fresh water, it is appropriate to demonstrate that the SB 15 wellbore has mechanical integrity and that injected fluids will be confined to the intended receiving zone. Supplemental mechanical integrity demonstrations and the surveillance of injection operations-including temperature surveys, monitoring of injection performance (i. e., pressures and rates), and analyses of the data for indications of anomalous events- establish sufficient mechanical integrity to demonstrate that fluids will not move behind casing beyond the approved disposal zone. NOW, THEREFORE, IT IS ORDERED THAT disposal injection is authorized into the Barrow Sandstone within SB 15 subject to each of the following requirements: RULE 1: Infection Strata for Disposal The underground disposal of Class II well oil field waste fluids is permitted into the Barrow Sandstone within SB 15 between the measured depths of 2050 feet and the total depth of the • Disposal Injection Order 37 East Barrow Gas Field South Barrow No. 15 Well July 26, 2010 ~~ Page 6 of 7 well. The Commission may immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined by the upper or lower confining zones. RULE 2: Fluids This authorization is limited to Class II oil field waste fluids generated during drilling, production or workover operations including plugging. This authorization DOES NOT include domestic waste water. RULE 3: Demonstration of Mechanical Integrity The operator shall run a baseline temperature log and perform a baseline step-rate test at the planned waste disposal pumping rates prior to initial waste injection. A subsequent temperature log must be run after the step-rate test to confirm confinement of the injected fluids. The operator shall submit this information and their assessment of the information to the Commission prior to commencement of disposal injection operations. RULE 4: Infection Rate and Pressure No waste disposal is permitted until the Commission determines the maximum pumping rate and pressure. Maximum pumping rate and pressure will be subsequently authorized according to the information determined in Rule 3. Once allowable rate and pressure are determined, surface pressures and rates must be monitored continuously during injection for any indications of anomalous conditions. Results of daily wellhead pressure observations in SB 15 must be documented and available to the Commission upon request. The conduct of subsequent temperature surveys or other surveillance logging (e.g., water flow, acoustic) will be based on the results of the initial and follow-up temperature surveys and injection performance monitoring data. RULE 5: Well Integrity Failure and Confinement If pressure communication, leakage or lack of injection zone isolation is indicated in any way - by injection rate, operating pressure observation, test, survey, log, or any other evidence -the operator shall immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe, inconsistent with sound geoscience or engineering principles, result in waste or threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for SB 15 indicating any well integrity failure or lack of injection zone isolation. RULE 6: Surveillance A report evaluating the performance of the disposal operation must be submitted to the Commission by July 1 of each year. The report shall include data sufficient to characterize the disposal operation, including, among other information, the following: injection and annuli pressures (daily average, maximum and minimum); fluid volumes injected (disposal and clean fluid sweeps); injection rates; an assessment of fracture geometry; a description of any anomalous injection results; and a calculated zone of influence for the injection fluids. Wellhead pressures shall be monitored daily. Pressure records shall be made available for inspection upon Commission request. • • Disposal Injection Order 37 East Barrow Gas Field Page 7 of 7 South Barrow No. 15 Well July 26, 2010 RULE 7: Notification of Improper Class II Infection The operator must immediately notify the Commission if it learns of any improper Class II injection. Complying with the notification requirements of any other local, state or federal agency remains the operator's responsibility. RULE 8: Administrative Action Unless notice and public hearing are otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. RULE 9: Compliance Operations must be conducted in accordance with the requirements of this order, AS 31.05, and (unless specifically superseded by Commission order) 20 AAC 25. Noncompliance may result in the suspension, revocation, or modification of this authorization. ENTERED at Anchorage, Alaska, and dated July 26, 2010. Chair, Commissioner Cathy P. F~(ierster,'Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission gants for good cause shown; a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. if the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which. case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration. will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography CEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503 Baker Oil Tools Ivan Gillian Jill Schneider 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 /~u,/ed i ~~/r~ • • Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, July 28, 2010 8:12 AM To: Aubert, Winton G (DOA); Ballantine, Tab A (LAW); Brooks, Phoebe; Davies, Stephen F (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Johnson, Elaine M (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA); (foms2 @mtaonline.net); (michael.j.nelson@conocophillips.com); (Von.L.Hutchins@conocophillips.com); Alan Dennis; alaska@petrocalc.com; Anna Raff; Barbara F Fullmer; bbritch; Becky Bohrer; Bill Walker; Bowen Roberts; Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; caunderwood; Charles O'Donnell; Chris Gay; Cliff Posey; Crandall, Krissell; dapa; Daryl J. Kleppin; David Boelens; David House; David Steingreaber; 'ddonkel@cfl.rr.com'; Deborah J. Jones; Delbridge, Rena E (LAA); 'Dennis Steffy'; doug_schultze; Elowe, Kristin; Evan Harness; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Gregg Nady; gspfoff; Harry Engel; Jdarlington (jarlington@gmail.com); Jeff Jones; Jeffery B. Jones Qeff.jones@alaska.gov); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Nicks; John Garing; John Katz Qohn.katz@alaska.gov); John S. Haworth; John Spain; John Tower; Jon Goltz; Joseph Darrigo; Judy Stanek; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; 'Kim Cunningham'; Larry Ostrovsky; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark Kovac; Mark P. Worcester; Marguerite kremer; 'Michael Dammeyer'; Michael Jacobs; Mike Bill; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker@alaska.gov); PORHOLA, STAN T; Rader, Matthew W (DNR); Raj Nanvaan; Randall Kanady; Randy L. Skillern; rob.g.dragnich@exxonmobil.com; Robert A. Province (raprovince@marathonoil.com); 'Robert Brelsford'; Robert Campbell; Roberts, Susan M.; Rudy Brueggeman; Scott Cranswick; Scott, David (LAA); Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tamera Sheffield; Taylor, Cammy O (DNR); Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjr1; Vicki Irwin; Walter Featherly; Williamson, Mary J (DNR); Winslow, Paul M; Yereth Rosen; 'Aaron Gluzman'; Bettis, Patricia K (DNR); 'Dale Hoffman'; Fredric Grenier; 'Gary Orr'; 'Jason Bergerson'; Jerome Eggemeyer; 'Joe Longo'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; Ostrovsky, Larry Z (DNR); Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; Talib Syed; 'Tiffany Stebbins'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR) Subject: co432d-008 (KRU), aio4e-015 revised (PBU), sio6-001 (SRU), dio36 and dio 37 (Barrow) Attachments: aio4e-015 revised.pdf; sio6-001.pdf; dio36.pdf; co432D-008.pdf; dio37.pdf Jody J. Colombie Special Assistant Alaska Oil and Gas Conservation Comfnission 333 West 7th Avenue, Suite 100 ~9nchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) • �� SEAN PARNELL, GOVERNOR O ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMJSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL DISPOSAL INJECTION ORDER 37.001 Mr. Bill Van Dyke Petroleum Engineer PRA 3601 C Street, Suit 822 Anchorage, AK 99503 Re: Request for Disposal of Cement Rinsate and Approved Non - Hazardous Fluids in South Barrow Well No. 15 Dear Mr. Van Dyke: By letter dated November 14, 2011, PRA, acting on behalf of the North Slope Borough (NSB), requested authorization to dispose of non - hazardous wastes, other than those wastes returned from downhole, into the South Barrow Well No. 15 (SB 15) Class II disposal well. This well is located in the Barrow Gas Field on the North Slope. The wastes identified by PRA would be generated during well work and drilling programs, and include excess cement slurry, cement rinsate, and small quantities of excess fluids associated with the proposed activities such as completions, well workover, testing, drilling and well abandonment. The AOGCC GRANTS your request. Our records indicate that SB 15 passed the mechanical integrity demonstrations required by Disposal Injection Order No. (DIO) 37 during September 2011 and Sundry Approval 311 -301 was issued September 28, 2011 authorizing injection into the well. The fluids noted in your request are generated in primary field operations intrinsic to development activities intended to improve the ultimate recovery of natural gas from the reservoir, to repair well integrity, or properly abandon those development wells that have no future utility. These fluids are consistent in composition with materials already authorized under DIO 37 and pose no risk of fluid movement into an USDW. The AOGCC also agrees with the assessment that underground injection into this Class II disposal well represents the environmentally preferable option for managing non - hazardous drilling and well service fluids in the Barrow Gas Field. The Commission has determined that the fluids, as represented in PRA's request for administrative approval, namely excess cement slurry, cement rinsate, precipitation from impounded areas, small volumes of unused brine, excess water based mud, small volumes of unused completion fluids and drum rinsates from materials used to prepare the listed fluids are Dio 37.001 • • November 29, 2011 Page 2 of 2 suitable for disposal in the SB -15 as proposed. No authorization is given to dispose of excess materials in unopened containers. This approval applies only to this specific request and is not blanket authorization to inject these or similar non - hazardous fluids down other Class II disposal wells. DONE at Anchorage, Alaska and dated November 23, 20 S ys ' ° � y � s • (4 i mow; O Daniel " eamount, Jr. /1707 orrnan fig, 05 ` eti Chair, Commissioner Commissioner ' VAT1O C o RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • Fisher, Samantha J (DOA) From: Fisher, Samantha J (DOA) Sent: Tuesday, November 29, 2011 8:58 AM To: '( michael .j.nelson @conocophillips.com)'; '(Von.L .Hutchins @conocophillips.com)'; 'AKDCWellIntegrityCoordinator; 'Alan Dennis'; 'alaska @petrocalc.com'; 'Anna Raft"; 'Barbara F Fullmer; 'bbritch'; 'Becky Bohrer; 'Bill Penrose'; 'Bill Walker'; 'Bowen Roberts'; 'Brandon Gagnon'; ' Brandow, Cande (ASRC Energy Services)'; 'Brian Havelock'; 'Bruce Webb'; 'caunderwood'; 'Chris Gay; 'Claire Caldes'; 'Cliff Posey; 'Crandall, Krissell'; 'D Lawrence'; 'daps'; 'Daryl J. Kleppin'; 'Dave Harbour; 'Dave Matthews'; 'David Boelens'; 'David House'; 'David Scott'; 'David Steingreaber ; 'ddonkel @cfl.rr.com'; 'Dennis Steffy'; Easton, John R (DNR); 'Elizabeth Bluemink'; 'Elowe, Kristin'; 'Erika Denman'; 'eyancy; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Schultz (gary.schultz @alaska.gov)'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'Gregory Geddes'; 'gspfoff; 'Jdarlington (jarlington @gmail.com); 'Jeanne McPherren'; 'Jeff Jones'; 'Jeffery B. Jones (jeff.jones @alaska.gov)'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John Katz (john.katz @alaska.gov)'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'Jon Goltz'; Jones, Jeffrey L (GOV); 'Judy Stanek'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Kim Cunningham'; 'Larry Ostrovsky'; 'Laura Silliphant (Iaura.gregersen @alaska.gov)'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley @anadarko.com)'; 'Mark P. Worcester; 'Marguerite kremer (meg.kremer @alaska.gov)'; 'Michael Dammeyer; 'Michael Jacobs'; 'Mike Bill'; 'Mike Mason'; 'Mike Morgan'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'nelson'; 'Nick W. Glover; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Decker (paul.decker @alaska.gov); 'Paul Figel'; 'Randall Kanady'; 'Randy L. Skillern'; 'Rena Delbridge'; 'Renan Yanish; ' rob.g.dragnich @exxonmobil.com'; 'Robert Brelsford'; 'Robert Campbell'; 'Rudy Brueggeman'; 'Ryan Tunseth'; 'Scott Cranswick'; 'Scott Griffith'; 'Shannon Donnelly; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Steve Lambert'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'tablerk'; 'Tamera Sheffield'; Taylor, Cammy 0 (DNR); 'Temple Davidson'; Teresa Imm'; 'Terrie Hubble'; 'Thor Cutler; 'Tim Mayers'; Tina Grovier'; 'Todd Durkee'; 'Tony Hopfinger'; 'trmjrl'; 'Vicki Irwin'; 'Walter Featherly'; 'Will Chinn'; Williamson, Mary J (DNR); 'Yereth Rosen'; 'Aaron Gluzman'; 'Ben Greene'; Bruno, Jeff J (DNR); 'Casey Sullivan'; 'Dale Hoffman'; 'David Lenig'; 'Donna Vukich'; 'Eric Lidji; 'Gary Orr'; 'Graham Smith'; Heusser, Heather A (DNR); 'Jason Bergerson'; 'Jill McLeod'; 'Joe Longo'; King, Kathleen J (DNR); 'Lara Coates'; 'Lois Epstein'; 'Marc Kuck'; 'Marie Steele'; 'Mary Aschoff; 'Matt Gill'; 'Maurizio Grandi'; Ostrovsky, Larry Z (DNR); 'Patricia Bettis'; 'Peter Contreras'; 'Richard Garrard'; 'Ryan Daniel'; 'Sandra Lemke'; 'Talib Syed'; 'Ted Rockwell'; 'Wayne Wooster'; 'Wendy Wollf; 'William Van Dyke; Ballantine, Tab A (LAW); Bender, Makana K (DOA); 'Brooks, Phoebe L (DOA) (phoebe.brooks @alaska.gov)'; 'Colombie, Jody J (DOA) (jody.colombie @alaska.gov)'; 'Crisp, John H (DOA) (john.crisp @alaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies @alaska.gov); 'Foerster, Catherine P (DOA) (cathy.foerster @alaska.gov)'; 'Grimaldi, Louis R (DOA) (lou.grimaldi @alaska.gov); Herrera, Matt F (DOA); 'Johnson, Elaine M (DOA) (elaine.johnson @alaska.gov)'; 'Laasch, Linda K (DOA) (Iinda.Iaasch @alaska.gov)'; 'Maunder, Thomas E (DOA) (tom.maunder @alaska.gov)'; 'McIver, Bren (DOA) (bren.mciver @alaska.gov)'; 'McMains, Stephen E (DOA) (steve.mcmains @alaska.gov)'; Mumm, Joseph (DOA sponsored); 'Noble, Robert C (DOA) (bob.noble @alaska.gov)'; 'Norman, John K (DOA) (john.norman @alaska.gov)'; 'Okland, Howard D (DOA) (howard.okland @alaska.gov)'; 'Paladijczuk, Tracie L (DOA) ( tracie .paladijczuk @alaska.gov)'; 'Pasqua!, Maria (DOA) (maria.pasqual @alaska.gov)'; 'Regg, James B (DOA) (jim.regg @alaska.gov)'; 'Roby, David S (DOA) (dave.roby @alaska.gov)'; 'Saltmarsh, Arthur C (DOA) (art.saltmarsh @alaska.gov)'; 'Scheve, Charles M (DOA) (chuck.scheve @alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount @alaska.gov)' Subject: dio37 -001 South Barrow Attachments: dio37- 001.pdf Samantha Fisher, Executive Secretary II Alaska Oil and Gas Conservation Commission (907)793 -1223 1 • • Mary Jones David McCaleb XTO Energy, Inc. IHS Energy Group George Vaught, Jr. Cartography GEPS P.O. Box 13557 810 Houston Street, Ste 200 5333 Westheimer, Suite 100 Denver, CO 80201 -3557 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton President 408 18 Street 6900 Arctic Blvd. Golden, CO 80401 -2433 P.O. Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI Baker Oil Tools K &K Recycling Inc. Land Department 795 E. 94 Ct• P.O. Box 58055 P.O. Box 93330 Anchorage, AK 99515 -4295 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Richard Wagner Gordon Severson Planning Department P.O. Box 60868 3201 Westmar Circle P.O. Box 69 Fairbanks, AK 99706 Anchorage, AK 99508 -4336 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith James Gibbs P.O. Box 190083 P.O. Box 39309 P.O. Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Penny Vadla Cliff Burglin 399 West Riverview Avenue 319 Charles Street Soldotna, AK 99669 -7714 Fairbanks, AK 99701 \ Q o • • siTATE �� L SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPR VAL DISPOSAL INJECTION ORDER 37.002 Mr. William Van Dyke Petrotechnical Resources Alaska 3601 C Street, Suite 822 Anchorage, AK 99503 RE: Request for Administrative Approval South Barrow #15 (PTD 1000450) East Barrow Gas Field Dear Mr. Van Dyke: Petrotechnical Resources Alaska (PRA), acting on behalf of the North Slope Borough, requests approval to dispose of small volumes of diesel in conjunction with freeze protecting exposed valves at the base of eight upright tanks used for the temporary storage of liquid drilling wastes. The drilling wastes are generated from drilling activities within the Barrow Gas Fields which commenced in September 2011. In accordance with Rule 8 of Disposal Injection Order (DIO) 37, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby grants PRA's request for administrative approval to dispose of the diesel freeze protect fluids in South Barrow #15. Liquid drilling wastes generated from current drilling activities in the Barrow Gas Fields are stored in a central tank farm prior to batch disposal injection into South Barrow #15. Although the tanks are heated, the exposed valve located at the base of each tank is susceptible to freezing, and to date at least one valve has failed. Displacing liquid drilling wastes from the valve with diesel will prevent a freeze - related failure of the internal components of the valve. PRA estimates each valve will require approximately ten gallons to freeze protect, repeated each time the tank is emptied and refilled during the disposal cycle and that the total volume of diesel used will be approximately one percent of the expected total liquid drilling waste injected into South Barrow #15. The request to dispose of diesel freeze - protect fluids with the drilling waste is justified by the following: - Testing demonstrated that South Barrow #15 has the necessary mechanical integrity to operate as an Underground Injection Control Program Class II disposal injector; - The confinement of disposed fluids has been demonstrated by baseline and subsequent surveys and ongoing injection performance monitoring; DIO 37.002 • March 13, 2012 Page 2 of 2 - Addition of the small volume of diesel — commingled with the drilling waste when the each tank is emptied and then injected into South Barrow #15 — will have no impact on confinement or the integrity of the injection zone; - Separating the diesel from the waste stream for disposal at another North Slope facility would be technically and economically challenging with no derived environmental benefit; rather, the numerous additional handling and staging requirements would increase the potential for a surface spill; - The purpose for using diesel is freeze protecting a critical valve in the storage system, not disposal of the commercial product; and - Diesel is the best suited product available for freeze protecting the valves, and is routinely used in the freeze protection of North Slope hydrocarbon systems, notably exploration, development, production and injection wells that are shut down for an extended period of time. This approval is limited to the disposal of small volumes of diesel necessary for freeze protecting the isolation valves at the base of the eight upright tanks used for temporary storage of liquid drilling wastes, as outlined in PRA's letter dated March 5, 2012. DONE at Anchorage, Alaska and dated March 13, 2012. ti; \'; ;` : If VC A • / 41_ '` Cat . Fo rster Daniel T. Seamount, Jr. ,`I t�'11'L�* Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. M provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 0 • Mary Jones David McCaleb XTO Energy, Inc. IHS Energy Group George Vaught, Jr. Cartography GEPS P.O. Box 13557 810 Houston Street, Ste 200 5333 Westheimer, Suite 100 Denver, CO 80201 -3557 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton President 408 18 Street 6900 Arctic Blvd. Golden, CO 80401 -2433 P.O. Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI K &K Recycling Inc. Land Department Baker Oil Tools P.O. Box 58055 P.O. Box 93330 795 E. 94 a. Anchorage, AK 99515 -4295 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Richard Wagner Gordon Severson Planning Department P.O. Box 60868 3201 Westmar Circle P.O. Box 69 Fairbanks, AK 99706 Anchorage, AK 99508 -4336 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith James Gibbs P.O. Box 190083 P.O. Box 39309 P.O. Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Penny Vadla Cliff Burglin 399 West Riverview Avenue 319 Charles Street Soldotna, AK 99669 -7714 Fairbanks, AK 99701 I , • Fisher, Samantha J (DOA) From: Fisher, Samantha J (DOA) Sent: Wednesday, March 14, 2012 11:21 AM To: '(michael.j. nelson @conocophillips.com)'; '(Von.L .Hutchins @conocophillips.com)'; 'AKDCWelllntegrityCoordinator; 'Alan Dennis'; 'alaska @petrocalc.com'; 'Anna Raff; 'Barbara F Fullmer; 'bbritch'; 'Becky Bohrer; 'Bill Penrose'; 'Bill Walker; 'Bowen Roberts'; 'Brandon Gagnon'; 'Brandow, Cande (ASRC Energy Services)'; 'Brian Havelock'; 'Bruce Webb'; 'caunderwood'; 'Chris Gay'; 'Claire Caldes'; 'Cliff Posey'; 'Crandall, Krissell'; 'D Lawrence'; '; ' ;, ' ;, ' ;, House'; 'dapa'; 'Daryl J. Kleppin'; 'Dave Harbour; 'Dave Matthews'; 'David Boelens'; 'David , 'David Scott; 'David Steingreaber; 'ddonkel @cfl.rr.com'; 'Dennis Steffy'; 'Elowe, Kristin'; 'Erika Denman'; 'Francis S. Sommer; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Schultz (gary.schultz @alaska.gov)'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'Gregory Geddes'; 'gspfoff; 'Jdarlington (jarlington @gmail.com)'; 'Jeanne McPherren'; 'Jeff Jones'; 'Jeffery B. Jones (jeff.jones @alaska.gov)'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner; 'Joe Nicks'; 'John Easton'; 'John Garing'; 'John Katz (john.katz @alaska.gov)'; 'John S. Haworth'; 'John Spain'; 'Jon Goltz'; Jones, Jeffrey L (GOV); 'Judy Stanek'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Kim Cunningham'; 'Larry Ostrovsky'; 'Laura Silliphant (laura.gregersen @ alaska.gov)'; 'Marc Kovak'; 'Mark Dalton'; 'Mark Hanley (mark.hanley @anadarko.com)'; 'Mark P. Worcester; 'Marguerite kremer (meg.kremer @alaska.gov)'; 'Michael Dammeyer; 'Michael Jacobs'; 'Mike Bill'; 'Mike Mason'; 'Mike Morgan'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'nelson'; 'Nick W. Glover; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Decker (paul.decker @alaska.gov)'; 'Paul Figel'; 'Randall Kanady'; 'Randy L. Skillern'; 'Rena Delbridge'; 'Renan Yanish'; ' rob.g.dragnich @exxonmobil.com'; 'Robert Brelsford'; 'Robert Campbell'; 'Ryan Tunseth'; 'Scott Cranswick'; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Steve Lambert'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'tablerk'; 'Tamera Sheffield'; Taylor, Cammy 0 (DNR); 'Temple Davidson'; 'Teresa Imm'; 'Terrie Hubble'; 'Thor Cutler; 'Tim Mayers'; 'Tina Grovier; 'Todd Durkee'; 'Tony Hopfinger; 'trmjrl'; 'Vicki Irwin'; 'Walter Featherly'; 'Will Chinn'; Williamson, Mary J (DNR); 'Yereth Rosen'; 'Aaron Gluzman'; 'Ben Greene'; 'Bruce Williams'; Bruno, Jeff J (DNR); 'Casey Sullivan'; 'Dale Hoffman'; 'David Lenig'; 'Donna Vukich'; 'Eric Lidji'; Franger, James M (DNR); 'Gary Orr; 'Graham Smith'; 'Greg Mattson'; Heusser, Heather A (DNR); 'Jason Bergerson'; 'Jennifer Starck'; 'Jill McLeod'; 'Joe Longo'; 'Kim Cunningham'; King, Kathleen J (DNR); 'Lara Coates'; 'Lois Epstein'; 'Marc Kuck'; 'Marie Steele'; 'Mary Aschoff; 'Matt Gill'; 'Maurizio Grandi'; Ostrovsky, Larry Z (DNR); 'Patricia Bettis'; Perrin, Don J (DNR); 'Peter Contreras'; Pexton, Scott R (DEC); 'Richard Garrard'; 'Ryan Daniel'; 'Sandra Lemke; 'Talib Syed'; 'Ted Rockwell'; 'Wayne Wooster; 'Wendy Wollf; 'William Hutto'; 'William Van Dyke' Subject: DIO 37.002 East Barrow Gas Field Attachments: dio 37- 002.pdf 1 • • Fisher, Samantha J (DOA) From: Fisher, Samantha J (DOA) Sent: Wednesday, March 14, 2012 11:22 AM To: Ballantine, Tab A (LAW); Bender, Makana K (DOA); 'Brooks, Phoebe L (DOA) (phoebe.brooks @alaska.gov)'; 'Colombie, Jody J ( DOA) (jody.colombie @alaska.gov)'; 'Crisp, John H (DOA) (john.crisp @aiaska.gov)'; 'Davies, Stephen F (DOA) (steve.davies @alaska.gov)'; 'Foerster, Catherine P (DOA) (cathy.foerster @alaska.gov)'; 'Grimaldi, Louis R (DOA) (lou.grimaldi @alaska.gov)'; Herrera, Matt F (DOA); 'Johnson, Elaine M (DOA) (elaine.johnson @alaska.gov)'; 'Jones, Jeffery B (DOA) (jeff.jones @alaska.gov)'; 'Laasch, Linda K (DOA) (linda.laasch @alaska.gov)'; 'McIver, Bren (DOA) (bren.mciver @alaska.gov)'; 'McMains, Stephen E (DOA) (steve.mcmains @alaska.gov)'; Mumm, Joseph (DOA sponsored); 'Noble, Robert C (DOA) (bob.noble @alaska.gov)'; 'Norman, John K (DOA) (john.norman @alaska.gov)'; 'Okland, Howard D (DOA) (howard.okland @alaska.gov)'; 'Paladijczuk, Tracie L (DOA) ( tracie .paladijczuk @alaska.gov)'; 'Pasqual, Maria (DOA) (maria.pasqual @alaska.gov)'; 'Regg, James B (DOA) (jim.regg @alaska.gov)'; 'Roby, David S (DOA) (dave.roby @alaska.gov)'; 'Saltmarsh, Arthur C (DOA) (art.saltmarsh @alaska.gov)'; 'Scheve, Charles M (DOA) (chuck.scheve @alaska.gov)'; 'Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov)'; 'Seamount, Dan T (DOA) (dan.seamount @alaska.gov)' Subject: DIO 37.002 East Barrow Gas Field Attachments: dio 37- 002.pdf 1 - #.9 • • pr 3601 C Street Suite 822 Anchorage, AK 99503 907 - 272 -1232 (voice) 907 - 272 -1344 (fax) March 5, 2012 Mr. Daniel T. Seamount, Chairman Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 MAR 6 6 2012 RE: North Slope Borough, moos ks 1}ii & Gas Cons. Commission East Barrow Gas Field, A±trltnm# Disposal Injection Order No. 37, Request #2 for Administrative Approval to Dispose of Non - Hazardous Fluids In Well South Barrow No. 15 Dear Chairman Seamount: The North Slope Borough (NSB) is the operator of the Barrow Gas Fields that are operated under the authority of the Barrow Gas Transfer Act, 1984. Petrotechnical Resources Alaska (PRA) has been retained by the NSB to provide technical and management services for this project. The Barrow Gas Fields are remote fields that are isolated from usual North Slope waste handling facilities by distance, weather, and financial constraints. The current drilling program includes drilling, completion, and abandonment activities. The NSB plans to drill up to six new production wells in addition to plugging and abandoning several wells that have no future utility as production wells. The current drilling program began with barge operations in July 2011. Drilling began in early September from a road - accessible site (Wells Savik 1 &2). Four additional wells, Walakpa 11, 12, 13 and 14, will be drilled from two ice pads beginning in mid January 2012. Walapka #12 is now completed and Walakpa #11 is currently underway. It is anticipated that activities will be completed in the second quarter of 2012 and equipment returned to Deadhorse by barge during the 2012 open water season. The NSB converted an inactive production well, South Barrow 15 (also known as EB -15), to a Class II disposal well. SB -15 was authorized under AOGCC Permit 100 -045. On July 26, 2010 the Commission issued Disposal Injection Order (DIO) 37 that conditionally approved use of the well as a Class II disposal well. An initial temperature survey, step -rate injection test and a follow -up temperature survey were completed in September 2011 and the results were submitted to the Commission for review. The Commission issued Sundry Number 311 -301 on September 28, 2011 authorizing injection into the well. 1 • • The SB 15 disposal well will be used for a time period of approximately nine months. The total volume of injected fluids will be small in relative terms compared to most other disposal wells on the North Slope. We anticipate that approximately 30,000 barrels of Class II waste will be injected into the well. Previously the NSB was granted administrative approval by the AOGCC to dispose of small volumes of nonhazardous fluids that are generated from primary field operations during the course of the current active project. By this letter the NSB requests administrative approval to dispose of additional small volumes of nonhazardous fluids, in particular diesel. The composition of the diesel is identical to the composition of the diesel used to freeze protect SB -15 between disposal cycles. Rule 8 of DIO 37 allows the Commission to administratively waive or amend any rule stated in DIO 37 as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscientific principles, and will not result in fluid movement outside of the authorized injection zone. Liquid drilling waste from the project is stored in 8 upright heated tanks at a central tank farm. We are experiencing freezing problems at the exposed valve located at the bottom of each tank. It is difficult to keep these exposed valves warm and as a result we have had them freeze and in one case fail. To prevent further freezing and more importantly to prevent any further failure of the valves, we would like to place a small amount of diesel across the valve each time we move fluid in or out of a given tank. This will keep the valve body internal area free of ice. The amount of diesel used across each valve will be relatively small, approximately 10 gallons per valve per event. Three additional freeze protection events are expected. The diesel will only be replenished when a tank is filled with more drilling waste or completely emptied during a disposal cycle. The benefit of injecting the diesel into the SB -15 well along with the rest of the drilling waste in the tank is that it will not have to be staged and then transported back to Deadhorse in a complex transit schema of tankage, barging and truck transit which involves multiple handling and staging steps. Each handling operation increases the risk of an accident or spill. In addition, it would be very difficult (if not impossible) to isolate and capture the small amount of diesel during each disposal cycle. Of the fluids available to us, diesel appears to us to be the best choice as a freeze protect agent and is the fluid used to freeze protect the injection well between injection cycles, so the Class I fluids we are requesting approval to inject will be identical to the Class II fluids already injected. The disposal of the diesel into the SB 15 well is the only economically and operationally feasible handling option. Once used for freeze protection, it will be impossible to keep the fluids separate from the drilling fluids in the tank. Alternative options, assuming we could isolate the diesel, include staging fluids in tanks that are managed to prevent freezing (significant amounts of water based liquids would likely be captured along with the diesel), multiple transfers to trucks and tanks for transit and barge expenses of more than $350,000 per round trip. In addition, the NSB would incur additional disposal fees in Deadhorse. 2 • • Approval of this request does not promote or increase waste generation. The NSB is only requesting approval to dispose of waste that is incidental to standard oilfield operations; in general, generation of these materials cannot be avoided. Diesel is currently used to freeze - protect tubing strings and annuli in the active gas wells and in the SB 15 disposal well. There are no water wells located within the greater Barrow area and therefore injection of these materials poses no risk of fluids moving into underground sources of drinking water. All wells 1/4-mile radius of SB -15 are gas production wells. There are no additional located within a 1 g p surface owners or mineral estate owners adjacent to SB-15. Disposal of oil field wastes generated from the Barrow gas fields is a challenge, both logistically and financially. The fluid types requested below are compatible with the existing permitted fluids to be injected into the well, are compatible with the injection zone formation, and will not move outside the permitted injection zone. The fluid requested below is classified as non - hazardous and the fluid composition is consistent in composition to fluids already authorized for injection under DIO 37. 1. Small volumes of diesel from surface freeze protection operations The NSB believes that the disposal of this fluid into SB -15 meets the Commission's guidelines and past practices. The fluids are non - hazardous, pose no risk to underground drinking water sources, and disposal in this fashion is the most efficient and environmentally preferable disposal option. Operations are underway and we would like to start to inject the diesel as soon as possible. If you have any questions concerning this request for administrative approval please contact me at 907 - 982 -2019 or ,,;,;: a z,r, r ,;;, ° .i t e,. _ 3 Sincerely, / -7//a,./ William Van Dyke Petroleum Engineer cc: Tom Walsh, PRA Mike Cook, PRA Barbara Vanderwendee /Chris Garlasco, PRA Steve Chronic, NSB Jack Laa.sch, NSB 3 co RECEIVED NOV 1 4 2011 Nuke Oil t Cons. Commission 3601 C Street Suite 822 1 Anchorage, AK 99503 1 907 - 272 -1232 (voice) 907 - 272 -1344 (fax) Waged Roma+ 41044 info@petroak.com November 14, 2011 Mr. Daniel T. Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 RE: North Slope Borough East Barrow Gas Field, Disposal Injection Order No. 37, Request for Approval to Dispose of Non - Hazardous Fluids in Well South Barrow No. 15 Dear Chairman Seamount: The North Slope Borough (NSB) is the operator of the Barrow Gas Fields that are operated under the authority of the Barrow Gas Transfer Act, 1984. Petrotechnical. Resources Alaska (PRA) has been retained by the NSB to provide technical and management services for this project. The Barrow Gas Fields are remote fields that are isolated from usual North Slope waste handling facilities by distance, weather, and financial constraints. The current drilling program includes drilling, completion, and abandonment activities. The NSB is presently drilling six new production wells in addition to plugging and abandoning several wells that have no future utility as production wells. The current drilling program began with barge operations in July 2011. Drilling began in early September from a road - accessible site (Wells Savik 1 &2). Four additional wells, Walakpa 11, 12, 13 and 14, will be drilled from two ice pads beginning in January 2012. It is anticipated that activities will be completed in the second quarter of 2012 and equipment returned to Deadhorse by barge during the 2012 open water season. The NSB has recently converted an inactive production well, South Barrow 15 (also known as EB -15), to a Class II disposal well. SB -15 was authorized under AOGCC Permit 100 -045. On July 26, 2010 the Commission issued Disposal Injection Order (DIO) 37 that conditionally approved use of the well as a Class II disposal well. An initial temperature survey, step -rate injection test and a follow -up temperature survey were completed in September 2011 and the results were submitted to the Commission. The Commission issued Sundry Number 311 -301 on September 28, 2011 authorizing injection into the well. The SB 15 disposal well will be used for a time period of approximately nine months. The total volume of injected fluids will be small in relative terms compared to most other disposal wells on the North Slope. We anticipate that approximately 30,000 barrels of Class II waste will be injected into the well. Disposal options in the Barrow area are limited. The SB 15 Class II disposal well is the only injection well available in the area. Access to the nearest Class I well is limited to barge operations during open water season, rolligon transit and fixed wing aircraft. During the current drilling program, most liquid wastes other than sanitary wastewater will be brought -to- surface fluids that can be managed at the SB 15 well. However, some associated fluids that have not been brought to surface will be generated. These are predominantly rinse waters for cleaning tubing, containers and other equipment. There may also be small volumes of well completion and work -over fluids and unused drilling muds produced. The NSB requests approval to dispose of small volumes of non - hazardous fluids that are generated from primary field operations during the course of the current active project (present date through July 2012). Composition of these fluids is similar or identical to the composition of the Class II fluids injected into SB -15. Rule 8 of DIO 37 allows the Commission to administratively waive or amend any rule stated in DIO 37 as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscientific principles, and will not result in fluid movement outside of the authorized injection zone. The benefit of injecting the fluids into the SB -15 well are that they will not have to be staged and then transported back to Deadhorse in a complex transit schema of tankage, barging and truck transit which involves multiple handling and staging steps. Each handling operation increases the risk of an accident or spill. The disposal of the fluids into the SB 15 well is the only economically feasible handling option. Alternative options include staging fluids in tanks that are managed to prevent freezing, multiple transfers to trucks and tanks for transit and barge expenses of more than $250,000 per round trip. In addition, the NSB would incur additional disposal fees in Deadhorse. 2 Approval of this request does not promote or increase waste generation. The NSB is only pp q p g Y requesting approval to dispose of wastes that are incidental to these non - routine oilfield activities. Drilling last occurred in the Gas Field in the 1990's. In general, generation of these materials cannot be avoided. Rinse fluids are generated from washing surface equipment, containers and trucks that have come in contact with unused drilling and completion fluids such as cement, brine, and excess drilling mud. The composition of such rinseate is identical to the used fluids that are Class II. Small volumes of excess fluids are generated in operations such as completion operations when it is necessary to estimate and prepare the volume of fluid required for the well work in advance. These completion operations cannot tolerate an underestimated fluid volume. Completion and drilling fluids must be used within a short period of time and often cannot be stored for later use. Finally, precipitation from impounded areas that may have drips and drops of unused oilfield chemicals cannot be avoided. If in solid form, the project has the ability to incinerate these residues; this disposal option is not viable for rainfall and other liquid wastes. There are no water wells located within the greater Barrow area and therefore injection of these materials poses no risk of fluids moving into underground sources of drinking water. All wells located within a 1/4 -mile radius of SB -15 are gas production wells. There are no additional surface owners or mineral estate owners adjacent to SB -15. Disposal of oil field wastes is a challenge, both logistically and financially. The fluid types requested below are compatible with the existing permitted fluids to be injected into the well, are compatible with the injection zone formation, and will not move outside the permitted injection zone. Disposal of these fluids will be on an as- needed basis; records will kept with injection documented and reported to AOGCC. All the fluid types requested below are classified as non - hazardous and the fluid composition is consistent in composition to fluids already authorized for injection under DIO 37. 1. Cement rinseate and excess cement slurry from clean up of the cementing unit and associated hoses, lines, tanks and silos; 2. Precipitation from impoundments around unused oilfield chemicals and fuel containers; 3. Small volumes of unused brine and excess water -based drilling mud; and 4. Small quantities of excess or unused fluids associated with well drilling, completion, testing and abandonment activities such as unused completion fluid, drum rinseates and excess drummed nonhazardous chemicals. These fluid types would be generated from drilling and completing the Savik 1 and 2 wells, the Walakpa 11 -14 wells and during several P &A operations we plan to conduct. No analytical data 3 is available; however, Material Safety Data Sheets for the cement products, well work -over and completion fluids are attached. The NSB believes that the disposal of these fluids into SB -15 meets the Commission's guidelines and past practices. The fluids are non - hazardous, pose no risk to underground drinking water sources, and disposal in this fashion is the most efficient and environmentally preferable disposal option. Operations are underway and we would like to start to inject the above referenced fluids as soon as possible. If you have any questions concerning this request for administrative approval please contact me at 907 - 982 -2019 or email to: bvandyke @petroak.com. Sincerely, Y 7 William Van Dyke Petroleum Engineer cc: Tom Walsh, PRA Mike Cook, PRA Barbara Vanderwendee /Chris Garlasco, PRA Matt Dunn, NSB Jack Laasch, NSB 4 7 • ~ RESPONSE to AOGCC July 6, 2010 RE: South and East Barrow Gas Fields: NSB Application for Disposal Injection Orders To: Dave Roby /~ From: Bill Van Dyke;~~ Shown below are your questions and our responses. I hdVe bee:: r2~i_cti:..^_'1 t:-12 atia~~3D y. _?"' ..._;:lai._Or f.~0:'t i.~[°_ ~4~~~, ~ieS ^:e CSC a`"11Cdt~QnS a:7d the t2s s.?v.^.1' CreSL,^~`_e~ at tr!e :'edrl;zy it appears there are Se`Tera~ ~nZOr.'T.iatiOr: _:.'..,C:1SiSte:lC3eS 07'i the tW^ .d2_1S prOpGSBd t^De L.Onvcrted t0 diS OS3i ;delis t.^.at ^idiS2S e?:'d2liatl0?: of the tiSB~S DrCL'v^Shc d ~ti;=~i't. .'iere _S d __SL C- I~t^r" 02tCrn'~:,at1C:':S a"':d SOme follow-up questions. 1; ~o specifl.. znfor:*ation i s pre-: ided to supeort the s' at~^: that vne SB-13 and ~B-1~ :yells are detileted. Both ..el?s had vrod~~ced at a relatively ^onsister:t rate to a~number of 1uars pric_ tc being shut- in. Se"ier31 SvUrCeS SL'geSt -~7?25C- `.^e11S had 2SSeP.t7.al~'_y Wat2r2~ 01it, yet ~1G water prCd!lc_iOr was reported _.., t.^,c tiL`~a~~ for eitPer rrel~. .Or Sev2rai years prier tc shin-i^.. In general, both wells are not capable of com-nercial production. The periods they ~•re.re used ir, the past were for emergencies only and typically they are more trouble and expense to keep maintained and producing than the benefit of the small production. For low rate wells to be produced, there is a maintenance and operation. costs that do not justify the time and expense far the gas. Wells produced in the Barraw gas fields are susceptiBle to hydrate plugging and require continuous methanol. injection to prevent freeze up and a slugging of methanol when performance falls due to hydrate formation. In the winter, when the need is greatest for gas in the Barrow yields, staff being able to service wells is at a premium, so low rate wells are not given much priority. Typically, wells that produce less than ZQQ arcf/d are considered more operational trcuBle than they are worth. Low rate wells that: are spread out, isolated and not easily accessible by road cannot be produced in the summer and are tco much ~rauble to produce in the arinter. SB X13 and SB ;~i5 were considered far wel: stimulation ir. 2C08, but the estimated cast and chance of success of the portfalio of candidates did r,ot ;~rarrant the cost of a orork over .;ar~:paign for any of the wells. Curre:~tly 8~=+ of the gas produced by t'r:e NS8 for t::e city of Sarrcw is provided from ~r;alakpa, Sout'r. and East Fools of tl-:e South Barrow gas ~ie3_d are used as Backup, as they accessible By road. Saute: Pool`s • RESPONSE to AOGCC July 6, 2010 pressure is depleted by suer 50~ and therefore does not have large deliverability, Primary producers in South Field during periods of extre:~e cold are SB#~10 and NSH-1, c~;hic'.^. are both accessible by gravel road. East Faa~ is believed to be recharged aver ti.^.:e by hydrates dissociation and is praducti~re ir. the Lower Barrow gas sand by EB-14. The NSB's plan is to drill and car,.plete 2 new trells in the East Barrow Pool and 4 new wells in the Walakpa Field to Beet future growth needs. These six ne~.r wells eaill be completed with horizontal completions and be capable of high enough rates to mininize issues with freezing up due to hydrates. 6d'nile the drilling operating equipment and personnel spread is in Barrow, there will be 8-9 wens that have been deemed r.an commerr_ial swill be abandoned. SB 13 and SBr15 are on the list of abandonment candidates. ~~ ~'......_ilatl`Jc ~T...Z.t:.,~-vn _.,_ J,~.-~?~ f C,". .l'a'y iy;~ ~...raug`:~. ~,.iy 20':,~ N:Ye, ~t last prGauced, :raS apprOXiTM!dte,.y L ~G :TL.,.".i. Prad''Ct1G^ ranged from: 172 to 12~ mcfpd for t<^:e last full year of ~egular prad'~...: t2Grc ;Tra:^1 3pri_ 2;~-~~ _C .ld rte. fi 2nJ ~; L`r...Gr tG 5^st-i_. d'1rin~ ., 1_j% 2000. The well is not accessib'_e by road so cannot be produced in the summer, when demand is low and at the low production capacity is not considered commercial to produce in the winter. The o-rell was considered for stir<ulation, but the poor performance of the well and cost to mobilize the sti~rul.ation spread to Barrow could rYot be justified fo_~- a portfolio of 6 potential wail candidates. The remaining reserves for th_s well are considered ur_economic at this time and the well wi11 be abandoned after use as a disposal well for the 201.1-12 drilling campaign. (If well SB13 is in communication with the main Fault Block, the reserves will be drained by SB-20 and NSB-1.} Belo~•r is a su:~-„wry of South Barrow ~13':> well h_story, Well Name: South Barrow #13 Tirnin~ of Well Drilling. Completions and Stimulation AUGCC Well Number: 100-037 API Well Number: 50023200080000 Date Spudded: 12/17/76 Total Depth: 2534' Date TD Reached: 1/2/77 Date of First Production: 09188 Markers KB Elevation: 40' GR/Pebbte Shale 1740' Kingak Shale 2240' Upper Barrow Sandstone 2296' • • RESPONSE to AOGCC July 6, 2414 Lower Barrow Sandstone 2363' Well History • Well South Barrow #13 was spudded 12!17176, • A 20" conductor was cemented at 74'. • A 14-314" hole was drilled to 1148', and wvas logged with DIL, BHCSoniclGR. Rathole was drilled to 1157'. 10-3/4" casing was cemented at 1157'. • An 8-112" hole was drilled to a depth of 2425', which was cored 2159-2219', 2288-2348',2410-2425'. The well was logged with DIL, BHCSonic/GR, CNL/FDC/GR. • The hole was deepened to 2534', with core from 2522-2534. The well was logged with DIL, BHCSonic/GR, CNL/FDC/GR, Dipmeter and 17 SWC. • A 7" casing string was run. to 2514' and was cemented. • The well was then drilled to a depth of 22.45', with a core being taken 2209- 2245'. • The casing was cleaned out to 2474' Ran CBL/VDL/GR logs. • Well was perforated on i/6/77 with 4SPF HyperjetII at following depths 2358-2368', 2314-2345', 2224-2234. • 2-7/8" production tubing was run to 2384' • Swabbed well and rocked with gas. Well would not flow. • Pulled tubing, Ran Gyro. • Perforated on 1114/77 with 4SPF Hyper~etlI at following depths: 2224.5-2234.5', 2383-2387', 2356,5-2376.5', 2315.5-2345.5' • Ran tubing and with tubing tail hung at 2394' • Rocked well with gas and blew well clean. Flowed well -very slight blow. • Set BPV. Released rig on i116i77. • 7/20/78 performed a drawdown and back pressure test. AOF reported as 360 MCF/D with reservoir pressure of 859 psis. Calculated K= 0.92md, S=2.5 • 3/20/87 Stimulated well with hydraulic foam fracture treatment placing 104 sacks of 20140 sand • 8127/87 performed pressure buildup test. Calculated K= 0.41md, 5=4.3 Discussion of Well Performance Well South Barrow #13 was placed on production in September 1988 and produced at a peak winter rate of 350 MSCFJD in 1988 and had declined to a peak winter rate of 190 MCFlD by April 1992, The well has produced at about 100 MCF/D from 1992-1996. This well did not produce prior to the hydraulic fracture treatment and has been a very low producer since that time. ~ • RESPONSE to AOGCC July 6, 2010 Both pressure buildup analyses show the average permeability to be less than 1 md. It does not appear that this well was damaged by the hydraulic fracture stimulation, as it did not flow prior to stimulation. The well may be considered for an acid stimulation treatment, but there does not appear to be a large upside due to the lack of reservoir permeability. RESPONSE to AOGCC July 6, 2010 South Barrow # 13 Production Curve From AOGCC Production Database S BARROW Well No. 13 ao 20 0 Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 10 0.1 Jan-80 Jan-82 Jan434 Jan-86 Jan-88 Jan-40 Jan-92 Jan-94 Jan-36 Jan-48 Jan-00 Jan-02 Jan-04 Jan-06 100.000 10.000 1.000 0.100 0.010 Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-~ Jan-92 Jan-94 Jan-46 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 J l`. .... !-... 0....i IAA\AI.I..i -~- Gas Rate (CD) (MMcf/d) - - -Water Rate (CD) (bbl/d) RESPONSE to AOGCC July 6, 2010 b Cumulati'+2 production for EB-15, from Dece:ni~er 1931 through ITay 1993 when it last produced, was approximately ?30 ~mcf. Broduction r.~as typically in the 12v to~3~ mcfpd range beginni,.g in about June ,i~~! unt~! i ~I?2 well llnti_ Shut-in during J'.~;:2 19`y3. The Weil is nat accessible by a serviceable grave_ road so cannot be produced in the sum-ner, s-iron demand is :pow and at the low productier. capacity is not. considered co~;unercial to produce in the winter. The well ;aas cons-~dered =c- stimulation, but: the poor perforzc:a.~ce of the yell and cost to mobilize the stimulation, spread to Barrow could not be justified fo_° a portfolio of 6 potentia'~ well candidates. The remaining reserves for t'r,is Nell are considered ui~econcmic at this time and the well YFill be abandoned after use as a disposal well for the 2011-12 drilling campaign. Belo.. is a sum7a_ry of South Barro;. ,~i5's well history. Well Name: East Barrow #IS Timing of Well Drilling Goxnpletions and Stirnulatian AOGCC Well Number: 100-045 API Weil Number: 500232001b0000 Date Spudded: 8123180 Date TD Reached: 911180 6 • RESPONSE to AOGCC July 6, 2010 Total. Depth: 22'78' Markers Kingak Formation; 1900' Upper Barrow Sand: 2094' Datf; of First Production: December 1981 KB .Elevation: 30' Nell Historv • Well East Barrow #1 S was spudded 8/23/$0. • A 17-1/2" hole was drilled to 84', where 13-318" casing was cemented at 80'. * A 12-114" hole was drilled to 1510', which was cored 800-825', 1329-1389'. Logged with DIUGR/SP, BHCSanic/GR"TTI and HDT-Dipmeter. • An additional 5' of 12-114" hole was drilled. • 9-518" casing was cemented at 1514'. • An 8-112" hole was drilled to a depth of2278', which ryas cored 1838-1881', 2096-2136' and 2165-21$7'. • DST #1 {Upper Barrow Sand) 2080-2136': Packer Failed. • DST #2 {Upper Barrow Sand) 2095-2136': Packer Failed. • DST #3 (Upper Barrow Sand} 2105-2136': 500 MCF/D at FP of 294-265 psia FSIP = 964 psia + The 8-112" hole tivas logged with DLL/GK, BHCSonic/GR, CNL/FDC/GR, HDT Dipmeter and MLL/ML. • DST #4 (Lower Barrow Sand) 2188-2278. Recovered 79 bbl formation water; FSIP =1026 psia. + 7" casing was run to 2198' and was cemented. • CBL/VDLICCUGR lag was run. • Perforations 2054-2464' and 2110-2151' 4SPF • 2-718" tubing was hung at 2155' • Production test 9/17/$0: Final rate of 1.0 MMSCF/D on 5116" choke FTP: 460 psia, FBHP: 649.5 psia, FBHT: 50.8 deg F., FSIBHP: 962 psia. • From AOGCC production records, the well began production December 1981. Discussion of Nell Performance tivell East Barraty # I5 was placed on praduction. in December 1981 and produced at a peak average monthly winter rate of 901 MSCF/D in August 1983 and had declined to a peak winter rate of 155 MCF/D by January 1992, 7 ~ ~ RESPONSE to AOGCC July 6, 2410 Although the well performance suggests it maybe tight, there could also be formation damage and should be considered for an acid stimulation treatment. RESPONSE to AOGCC July 6, 2010 East Barrow #15 Production Curve From AOGCC Production Database E BARROW Well No. 15 -rroaucing uays 40 20 - Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-90 Jan-92 Jan-9a Jan-56 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 10 1 0.1 Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-90 JanA2 Jan-94 Jan-96 Jan-48 Jan-00 Jan-02 Jan-04 Jan-06 100 10 1 0.1 0.01 Jan-80 Jan-82 Jan$4 Jan-86 Jan-88 Jan-90 Jan-y2 Jan-94 Jan-46 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 () r.,.., r ~ o.,,,~ innennn.-r -a--Gas Rate (CD) (MMcf/d) ~- - -Water Rate (CD) (bbVd) • RESPONSE t0 AOGCC July 6, 2010 • e} SB-13 repGrted T=o .rater production fram. October 1993 until Technically the hell is rot watered out, but _.. is simp'1y ncn- comr.:ercial due. tc the severe winter operating enviran~ent dur_nq ti~~e Barracv winters and rct being accessib~e by road tc attenpt to produce in the summer mant;^s. CI} "~-~~ reparted eSSEn'__ally :nG :rater prCdi,~.`_iG frGiit rpr~l _988 untl Si .._-2n, Tec~nically the yell is not :vatered out, but. it is simply noa- com^!ercial due to the severe winter oper.atirg environment during t:,:e Barrow rrlnterS d:'3d not being aCCeSS~bie by road t£7 attempt to produce in t~-:e sux:mer r:onths , 2} It is claimed teat ~~-13 is it aT isolated fault blLck with t~:2 ~;Sb-~~ F7eli y2t t!~Ere iS ar engineering "?elf.Cra*':d3 related t0 C?dCkpreSStire a.^.d dra44dO:d:? 3?'13i jrSeS fCr th~^ S::~,^,~2Ct :4e~i ^Jrid3Ct2d ~ll~ j 2Q-~?, 1978, "vrt?iC~l StdteS: ~~itj:?e ~Cr2Tia`~~'J:? dppearS t0 .^e part=?~~ f drained byt~''.e ~'XiS~i_^<y^ ;^lei? 5 aS 1S eV.2deriCed by t."12 Sk';.llt-1?l re52r VCir pressure of 8~9 psia ;vi~:icn is about 240 psi lcti:er than the initial reSerVGir prc"~SSllre. ~~ Additiandlly, during teSt1P."toriy at t!'?2 ledrii:Cj iFr. StGkeS Stated t'iat preSS'~re ' n file iaUlt biQt~k WaS ;.a' Culated t0 be 758 psi from a pressure b~.~ildup test it the N5B-v2 well in 290'0. il'OleVer, a L1reS5'..kre b:llidup teSY_ in ~ne SB-13 `Nell ..:lot was cOnd:cted C^i f_t1^yt1St 27, ? ~~ +, e5~ gated reSErGCir CreSSUr2 at 6~1 pS1. There are CCnfl_Ct1I2g geap'?yS_Cai interpr'atationS iQr tYe lccatian Of the fault. In addit:.an there cou_d be -:t~alti~le vaults and it is not kno~.v^. if the fault ar faults seal 10©"~, The erell is not commercial as described in 1j a. above. It will be ab_:adoned during the 2411-12 drilling ca:npaig :. .~i Per.e ray 1Jee:: a;^.Gt:t ~.~ t3'~` pr.,uLCed frv.,, the fa?1Jit blOCk that ccntains pile SB-13 wel_, whici~ ..yt the approxr^:ately ~40 psi preSSi.ure drop repo rted by }ne ~JB wCt: d 1^:d Car? that apGrC {1Z?:a te.y 1 BCF Cf gas ~ "l,~ ..v prOd'i~ed fOr e":2ry -iU~ psi preSSlire drop, ulTer: th~s, ar<a ,_ ;e lace ._ reported .~:at~_ prcd~~..._... gnat ~rrcua _..d~cate a~u~..v_ 1S't.l.x, t ~re 3pzaa.._ tG be Se:"era_ L7'.^F' ..,_ re;-',a~ Ing re52~ :?eS, nGt the eSS than l ~~~ aS =2St~fled t0 cy i°. _'. ...}CkeS a'- he ,.ear~::g, _.. toss fasir beck ya- .he TSB prGpases to v.,4.aert .,r:e .~_ t'r.e t:=?a .el_s tO a arsp~sal „~_~ and _.. aoar_.... bor. .._-_s aS part ci t}":e ~pCGrc,~.:~ p2rutiC;.S. Nr. utckes has reviewed the 200? neservx~s Study perfcrr:;ed by PRA ar.d ~,aouyd like to correct that or.'.~y '~.6 BCE' reran t:>is fa~,:lt block, but t7ie wvl1S are ^at Camrnercial aS deSCrlbed In ~l abaVe. Bath VJB#2 and aB~13 are being cons~~dered for abandcnm.F=^:t regard=ess of t%:e fault iocatiori, 10 • • RESPONSE to AOGCC July 6, 2410 v'_ 1 c l."_~La1".-reSSi.ire _.. `".e ~~-i ;•lell *riaS apprOXi,T.aLel'y' ~E psi, n!';~„i:_S ^OnS~Steii_ .,_ ._ the _.. ,. ~a_ DOf.'~ pr2SS?_re. Ci:rrently reCOrded po01 preSSlre S apprOXiff€ately ~~~ pS1 and cu_lding Over ti.T;e arccrdina to `;r. Stokes Testimony. T:.is is being attributed ~o disassaci ation of gas from a 'r: •ydrate la`_ter in t're upper part ~f the reServGlr, aS S::G^ it iS `?ery diff~~.it t0 2Stlmate ~i>t,. a rY OertaTntij ;r7~lat are the. gds reserves ~n v..i5 portion Of the reSer'J~3:ir. SB nl5 is produced from the mapper Barro`r Sandsto.^.=. ~:~e mair, productioe interval in the Bast Barrow Pool is from the Lower Barrow Sandstone, ~~aich is the i*lterval that SB~`14, the best and only commercial well in the field produces from and where 2 Y:or'._zontal wells will De completed. fihese wells will be used as an emergency backup to the waiakpa gas field in the evert of a pipeline problem from Vialakpa. SB#1:, is not considered ccm~ercial as described ir. l~ above. It is being prcposed for abandonTM:ent during the 2bi1-12 drilli-~:g caspaign. :, ~ccGrdirg tG a December 1993 report prepared by araV_slPe~erSOn ^'TrCnmental ~O,eSllting, In-.^.. toed ~~PrGpOScd JJ1tYl Barrow vas TJelt,. i`~G. i7 deep =??~eOtlOn Edell Pre-FeaSibillty Study's it i5 believed that file Arel~ i3 ~~Separated from :.Ile rest Gf the t•72115 by 3 Series Gf ~aliltS and folds." AS SiYCh ti12 ~B-1~ might be the Only we~i Capable Of reC=O"ier.~ng the gas ...?'2 tl::_S pOrt~On of tCle f~e~d. 6t Tne On Dage ~ Gf thE' re:Ort Tientl0^ied in iteICt .~. d'liOVe it states rr ~t~he wel= pr OduCeS ~.OL^I C7a3nntltleS Gf ?'ldt Ural gas P7.1 ~. I'i SOmB writer and oil." ~s previously stated, the production reports submitted by the "aSB to the AOGCC show no water production irGm this :cell for several years prior to ~~ being shut-in, it a_so never reported any liquid rydrocarbon prGd'..~tion. ,; ~1r. S~GKES ine?'itlGned a L.~.~b reSerV25 study ~Or t e [5arr047 Gas Fields Ciit ,.ne ~G^'u._SS1'Jn has _i.,_ b2en orOV~ded W_tY'. thS. ~rlould you please: 1j ? J.de a ..ODy Oi t%e L'J`yC _..SerVeS S`;riy t~:a_ 'r7aS L'n<`.2r~aken ~~" ~~ for t':i2 ~J~ b?. .,..~. .~ ~_. G^ii~ 3r~~~ tPe ~ OSStrc'":at... tI?at WY'~S comlleted _T? 20v^c tZ3_ .~_ . $tG`.{ems r:e~ ~Cr2~ CS',.~_~.g ^~1S teSt~:Ti:~.:j~ rf»^ca~~ DL'4:'i~e. L~ r~d~`"eSS ~t2Z":S '_ t ;~ E, abG`ie, a5 j%Ou prOti e 7e ~..1?d eXp "_a,.at iOl'iS, 3~.Or.g :^.__is S- y.~Or _t~:7 =~..... ..,<... _... ~.a ~it~n, for t e 5..,_~v.. ~:i'g QUeS..iC1S: 1n4 ~ I.uei~t. -.a ~:~i~$ Q~~, w~i...:e7'it a) .. ;Jeri ~~-~~ 3 ......-~ti S^.. ~?"?. 1 ~ee ~ c.^Oi'e. ,:~; ~C y,^u ue.._c'ie ~i;..._ ~:':P _y~ i `"eS3....re S. _~ic`y in ~_.... J~-_~ `r7el.._ • • RESPONSE to AOGCC July 6, 2010 G'JeS nOt GrO~iide a^.d a^.Cllr3~e re5cr'TC_r preS51r2 +'~r ~dS t:2 r2Serz.TOr Seen SOISie _eC1'idrgc`' Si _~e }':tat .._"ie '^,osS,~_bly irOTCi ,aa`_er or:Cr 3C'.^T'teP`_ O.'- hy^rate disasscr_iation as _s be_ieved ~., be vcc~.:_ring _:~ ~ne East ~arrefr reservoir? Nsr. Stokes believes that the 1957 pressl.re is earrect and tha: SB-i3 is rot in the 7SS-2 rB, based a^ pressures. tlternativel-y t~:ere .:fay be ,.,ultiple fa'u'lts or the `au1vS may tG SG''B etCterit ..Bak. Why are t~ese swells considered tc nave watered-out? ras any produced water nct reported to ~~GCC? The :wells are riot technically s-catered ot.t. ~'ney are ..ot co ~-:ercial d; ;^i^y are SB-13 ar:d EB-15 consi~'.ered good caraidates nor conversion tc disposal ooeratians? $E:e .~ abC3Je. TnBy' are Flom C:OPLTCerClai a.*:d t12y are e;~1St1:^_g Wel1'LJGrB5. They are also proposed nor abae.don^e^., d.<ring this drilling campa.gn. c} re tri25e wails good candidates nor i_'3C.tUre or acid stiriulation7 Ni`nat about the other production wells? ~o. See comr,:ents in ' ; above. ^rac ar::~/or acid hazTe not shown tc be co^+:a-:Brczally viable. Lj if.~y-ly ;,do~:~ ~ ~reSe ...^v?~VerS10_`iS rraSt.e reSerJeS? These are not reserves associated witCl thesB wails as tt'YB'y are not economic to producB. Tr'iells will be P5~?~Yd regardless. gi ~rlas there a^y _ikuid ~:ydrocarbon production. fro:rt the EB-15 we~~l. Only in JST ~i ;n the mower farrow 5and:7toae, b'•u~^Ot S1riCe CJut CP. production i:a tiiB Upper Barrotr Sandstone Sorry i did not bring this to your attention: prior to the hearing, but a far~:ily 2sSUe pre'Tent ed Ilia _~Gr :OR.tC'let ing n:y rev~Btr dt tClcdt ti?L!e. 17 • • Colombie, Jody J (DOA) From: Roby, David S (DOA) Sent: Friday, June 18, 2010 10:04 AM To: Colombie, Jody J (DOA) Subject: FW: Questions concerning NSB's Barrow DIO requests For the Barrow DIO application files. Dave Roby (907)793-1232 From: William Van Dyke [mailto:bvandyke@petroak.com] Sent: Thursday, June 17, 2010 1:16 PM To: Roby, David S (DOA) Cc: Davies, Stephen F (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Pete Stokes; Tom Walsh Subject: RE: Questions concerning NSB's Barrow DIO requests Dave I will work on the specific answers over the next few days and I can drop off the report that Pete did a few years ago.. The basic premise is that the wells are uneconomic to produce and will be plugged and abandoned when the equipment spread is in Barrow in 2011-2012. This is true regardless of whether the wells are used for disposal or not. Two new horizontal high-capacity wells are planned in East Barrow. Both EB I S and SB 13 are very poor producers at best. Bill Van Dyke Petrotechnical Resources Alaska (PRA) 907.982.2019 (cell) -----Original Message----- From: Roby, David S (DOA) [mailto:dave.roby~cr~alaska.~ov] Sent: Thu 6/17/2010 12:44 PM To: William Van Dyke Cc: Davies, Stephen F (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: Questions concerning NSB's Barrow DIO requests Hi Bill, I have been reviewing the available information from the AOGCC files, the DIO applications and the testimony presented at the hearing. It appears there are several information inconsistencies on the two wells proposed to be converted to disposal wells that makes evaluation of the NSB's proposal difficult. Here is a list of my determinations and some follow-up questions. 1) No specific information is provided to support the claim that the SB-13 and EB-15 wells are depleted. Both wells had produced at a relatively consistent rate for a number of years prior to being shut-in. Several sources suggest these wells had essentially watered out, yet no water production was reported to the AOGCC f~either well for several • years prior to shut-in. a) Cumulative production for SB-13, from July 1978 through July 2006 when it last produced, was approximately 856 mmcf. Production ranged from 172 to 129 mcfpd for the last full year of regular production (from Apri12005 to March 2006) prior to shut-in during July 2006. b) Cumulative production for EB-15, from December 1981 through May 1993 when it last produced, was approximately 730 mmcf. Production was typically in the 120 to 180 mcfpd range beginning in about June 1987 until the well until shut-in during June 1993. c) SB-13 reported no water production from October 1993 until shut-in. d) EB-15 reported essentially no water production from April 1988 until shut-in. 2) It is claimed that SB-13 is in an isolated fault block with the NSB-02 well yet there is an engineering memoranda related to backpressure and drawdown analyses for the subject well conducted July 20-23, 1978, which states: "[t]he formation appears to be partially drained by the existing wells as is evidenced by the shut-in reservoir pressure of 859 psia which is about 240 psi lower than the initial reservoir pressure." Additionally, during testimony at the hearing Mr. Stokes stated that pressure in the fault block was calculated to be 758 psi from a pressure buildup test in the NSB-02 well in 2006. However, a pressure buildup test in the SB-13 well that was conducted. on August 27, 1987, estimated reservoir pressure at 631 psi. 3) There has been about 1.5 BCF produced from the fault block that contains the SB-13 well, which with the approximately 140 psi pressure drop reported by the NSB would indicate that approximately 1 BCF of gas could be produced for every 100 psi pressure drop. Given this, and the lack of reported water production that would indicate aquifer influx, there appear to be several BCF of remaining reserves, not the less than 1 BCF as testified to by Mr. Stokes at the hearing, in this fault block yet the NSB proposes to convert one of the two wells to a disposal well and to abandon both wells as part of the upcoming operations. 4) The initial pressure in the EB-15 well was approximately 960 psi, which is consistent with the initial pool pressure. Currently recorded pool pressure is approximately 935 psi and building over time according to Mr. Stokes testimony. This is being attributed to disassociation of gas from a hydrate layer in the upper part of the reservoir, as such it is very difficult to estimate with any certainty what are the gas reserves in this portion of the reservoir. 5) According to a December 1998 report prepared by Travis/Peterson Environmental Consulting, Inc. titled "Proposed South Barrow Gas Well No. 15 Deep Injection Well Pre-Feasibility Study" it is believed that the well is "separated from the rest of the wells by a series of faults and folds." As such the EB-15 might be the only well capable of recovering the gas in this portion of the field. 6) The On page 4 of the report mentioned in item 5 above it states "[t]he well produces low quantities of natural gas with some water and oil." As previously stated, the production reports submitted by the NSB to the AOGCC show no water production from this well for several years prior to it laeing shut-in, it also never reported a~iquid hydrocarbon production. 7) Mr. Stokes mentioned a 2006 reserves study for the Barrow Gas Fields but the Commission has not been provided with this. Would you please: 1) Provide a copy of the 2006 reserves study that was undertaken by PRA for the NSB beginning in 2005 and the pressure data that was collected in 2006 that Mr. Stokes mentioned during his testimony. 2) Address Items 1 through 6, above, as you provide detailed explanations, along with supporting documentation, for the following questions: a) Why were SB-13 and EB-15 shut-in? b) Do you believe that the 1987 pressure survey in the SB-13 well does not provide and accurate reservoir pressure or has the reservoir seen some recharge since that time possibly from water encroachment or hydrate disassociation as is believed to be occurring in the East Barrow reservoir? c) Why are these wells considered to have watered-out? Was any produced water not reported to AOGCC? d) Why are SB-13 and EB-15 considered good candidates for conversion to disposal operations? e) Are these wells good candidates for fracture or acid stimulation? What about the other production wells? f) Why won't these conversions waste reserves? g) Was there any liquid hydrocarbon production from the EB-15 well. Sorry I did not bring this to your attention prior to the hearing, but a family issue prevented me from completing my review at that time. Regards, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 w7r� • • Colombie, Jody J (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, June 08, 2010 3:57 PM To: William Van Dyke; Colombie, Jody J (DOA) Subject: RE: DIO 10-01 and 10-02 Bill, Your search confirms my understanding that only 1 bond log was run. At this time, I am not aware of anything else needed by the Commission. We are working on finalizing the orders. Tom Maunder, PE AOGCC From: William Van Dyke [mailto:bvandyke@petroak.com] Sent: Tuesday, June 08, 2010 9:43 AM To: Colombie, Jody J (DOA) Cc: Maunder, Thomas E (DOA) Subject: DIO 10-01 and 10-02 Jody We have searched high and low for the cement bond log for well EB 15. It is no where to be found. The BLM both in AK and CO have no record of ever getting a copy. Is there any other info that the Commission needs to go forward with a decision on the appln? Bill Van Dyke PRA 907-272-1232 office 907-982-2019 cell 907-272-1344 fax ~~ May 20, 2010 Mr. Daniel T. Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 RE: North Slope Borough Barrow Gas Fields 3601 C Street Suite 822 Anchorage, AK 99503 907-272-1232 (voice) 907-272-1344 (fax) info@petroak. com Application for Disposal Injection Order, and Application for Approval of Two UIC Class II Disposal Wells Dockets DIO 10-O1 and 10-02 Dear Chairman Seamount: HAND DELIVERED REC~lV~p SAY 2 ~~ 2010 .i ~~ mss. i~ion Enclosed are the supplemental materials that the Commission requested at the May 18, 2010 public hearing concerning the North Slope Borough's (NSB) applications for a disposal injection order and two UIC Class II disposal wells located in the Barrow Gas Fields. I understand that the applications are referred to as Dockets DIO 10-01 and 10-02. Also enclosed are revised copies of two of the Attachments included in our original application. Attachment 12 is a Google Earth satellite image showing the two water lagoons that are used for sources of public drinking water and the locations of the South Field and East Field. Attachment 13 is an aerial photo taken from the BUECI web site showing the southern of the two water lagoons which is labeled Isatkoak Reservoir on the photo. Attachment 14 is another satellite image showing the Isatkoak Reservoir and the South Field location. The two lagoons are the public drinking water sources for the community of Barrow. Water from the lagoons is filtered and processed before it is distributed to the community. The revised copy of Attachments 1 F corrects the label on that attachment and the revised copy of Attachment 3 adds the SB 10 well location to the plat. At the hearing Commissioner Norman asked what specific waivers the NSB was requesting. In addition to the waiver to not require packers in the wells and to not require pressure testing of the tubing by casing annuli, we are also requesting a waiver to operate both disposal wells without • L' packers. I believe this is understood, but I wanted to reiterate the request again here to make sure the Commission considers the request. If you have any questions please contact me at 907-982-2019. Sincerely, William Van Dyke CC: Tom Walsh 2 Structure Map -South Barrow Field -Top Barrow SS _. __ __ .- ~. ~y ^.. ..~ ~ ~ _ __ _ ,. ~~ _ _ -',~ '~_ ~~ (;~' j _ - _ ~-229 ~~~ '~ ,~ '~ - _ ~ ~~ f --- - - _ r _ r ._ 1 / __ ,, iI it J. ~~ ~ ...~-~ - - ~.T ( __ ' .... ! NSB_~ ~ ~ `' ~ '~I -- _ ~ .~ 11'•x' ~}-' ! f.~,.r '.. ~ i 4' v ~ ,, ., i . _ i ~. ~, ( ~ '° __ -~= South Barrow #13 - -~ ~ {~ ~~ ~, ~ ~ ~a ~~, ~. _ _ r (i ~' ~ ~ --~-~_ r "~---~~~-_~_ ~ ~~~' ; - ~ - ~~ ,t _ t~~- ~'~, ~ ? ~ ~ ~~ ~ North ~. '"~l/ . - ~ ( ~' i !; ;~` ' ~ •~~ ,~~'~~,~' ~ f ''_~ _ ~ REVISED ATTACHMENT 1F l t ~~ ~ r' ' ~ ~ '; ~ ~ '', { ~ ~ ,~ ;~ ~' ~~ ~ GEOLOGIC REPORT ' ' 'o ~.`, ~~ ~ ,~' , ~ i ~~ ,~ '' I ~' ~ ~ `" ~ ~- ~ ; + ~ ^ NSB Barrow Gas Fields Upgrades Project + ~~ ` ~ ,fi ~~ „',~,~ t `* ~~~~^~ ,~.- ~ •r ' I Proposed Plug & Abandonment Wells ~ +>~$'` ' ~' ~ ' ~'"' . r ~ ~, +~; ,~ i4r~ "~ a; ~~ ~~' ° i' ;~ . ~ '' • SB 8, 11, 13, NSB-02 ` ~ ~ ~k ,~ "~~',~,~~ xs ,. ,?~. =: ,~"_~~~,' ,;, .,, , ~ 1+$S~ K ~nllfll Rat7i?LNFI~IC1 p i •.'~f~e~~r«~ ,~'~~}~~,a+y'~" ~ +~~' ~ ~~`~~~ ,.5; ~iN "+i1"+yr'*~ ,~~.:, «, `~~ ~ ~ ~~~~ 1~ ~~~, y;/I~. (~~~~ ?. A`.'~~ # ~+• fit, `r t, iy ~ ... i°i E. '~+`.~ ~4 ~ ~ •-i» >;.r~~.~ ti ~ •~k/~'<o~ ~r nM"~r. ,t' _ .. ,~......~. _ ~^~- ~ ~ -~ r ° ~- _ ~ + ~ ''" .~. '.~ a+,,r ~ Note: SB 08 -Satellite image y ~a i +~+* ~ mat ~~~ i , •,...~ f` ~t+ } ~F:. ~+~ pEr a~•~ t ~ .~ r ,~ ~., ~`+~ ~ ~ l~l~res well in different section .b r.~ 4 ~ _ „7p 1 i ~ Ykyf'V "~~ I "T ~- ,z ~ ~ ' ~ ~ ~RC' - - ,. ~. ~ . s ,~ s 4+. i r ~ ~ ~ $. / i" ~ 3:.1•~ ~ R, `.. M e' ~ , 2 • . ; r,,: ~~Ywlb - ."l^5• • •L tT' .M M ,/~ e~, ~. '~ r~ ~=~ ~~ ' * ` 9 ^~~eld '. ~t , s= ~~ '•: ~'`~ +r~-: ~ { 'ice ; - 3~' s ~ ;~ , fix: :.~~~ ~ ~%' `•!,~ ~ ~ n r 1.'yrK 4` ! .~'~ .~ mot' s ,. _• , ~,~, t~,y~ t ~}-~ ~'~ B NSB 07D1 " r - +/+d++'rS- ~ Fl ' i ~ 'ww. ~ 5 `~'r x1Fr ;- a.• '~ ~C° I r. ,; ~ ~~ ~ ~~'r . `x~$''h4~ `~~} .. SE3 (~~~r~~~~ ~~~ ~~ °:"il y ~ T ~` ~ .r y * _ I t '.1 4~5~'SL't !~' ~ .: R~/ "M yy A `,.. ~.4w - ~ ,ay ~ ~, ^ e ° ~~i 1 ( _ # ~ . w v ".`p r' 1N ,~" - / ti- hNy+.,°.r .a ~' ~ ~„= r ,~: r ~, s -a y ^. ~ ~- r~~- +~ ~ ..j•• ~ w`S'P Ik "5~* arc .~'• d _ ~ ~ti ~ k.*3, 1~ ~ e Ar ~'~" a +q .v*:5 .. [.,$„4,~ -~' ~~ ~,7e' 'k .. i.r y 1 fit ; i '~. ~ c d' ~ I ~ i i ~:Y. a + ~ '+~-'~' "-1' . (.'+ : ~,r ~ z 1 ~ . a t" ..: y`, ' h '~ - 16~, x ~, t r4 !~',{~ ~. ~~~ ~ ' ,~ ~f, i ;7 [~ ~~ ~ .~' -` REVISED ATTACHEMNT 3 ~~ d Y ~ y~~' `~ ~t °~~ ~~ ~~ I,~ti>~~ '"~ `~ ~ PLAT OF NEARBY WELLS ti ~', :. `r ~ `± Proposed Disposal Well ,~ .i,~r4 -rte,, n`''`. `'~'~-.~ ~~~,* '~~ ~ r '~,}` ..~ - ~ .' ors p~`, .~ "~-__--`-~-------`---e `• ~ t~ ~~ r+ + ~ .>~ ,i~~;' ~ i ~,. ~~ '~; .-+~ ~ Y 9 ~ P8A Wells Requiring Ice Aa ess w ~ ~ 6 Yj f,4' ~; ~ ~ +~ a ~ ,,. _, t i + ~ +• f Y e • ~ 11 i 6'` $'`~ 22~ ~ ~R ~ ^~ .. ',~,~r~i~1"~.-• 6~; ~~' ~~ ~ 1t`r ~ ~ P&A WellsAccessible by Road ~ ~. + 4 +t,H~z t `t '_. w.~ 'i t °, r. _" o ~-•~.~}~ \~- a ~ ~ '~ ., 1 ' '"S ,.~-~{ ~,~.'=r + ~ ~ Ice Road Route •«'~~ y~~'' ~'a~~r ~~~. ~ ~~ ~~~• .~.,n >' ~, c~ .-may i = r. 'rS !~'~- .4;. ~`. a~~. t ~ 'r ~ + -' tg ar,~ •„ ~~, ~ y ~ ~ Fz ° ~ + C J~/{,~ ~~t,, x 4 ~ `~f °, y+ Ice RoadAccessto Lakes ,~ ~ • ° ,Fc ,. ~ ,. ~" ~ `` + a~; ~°k" 4 ii 'r .~, S - Existing Gas Lines . ~ a #. ` ~; ~ `} 4 ~" :.~~ f; _ r ~ti i.}.^:3 ~y~. ~~ ~ _°= Roads-NSt3 GPS 0 Z00 400 600 8001,000 2000 A5P6, NAD27 3,000 4,000 5,000 Image: Aero-Metric, Inc. ' ~ - ~ Feet ~ 5/20/2010 AAiles 0~ O t 02 O.a 1:12.500 0.6 O A ~ r ~ v -u~ ATTACHMENT 12 ": ,. LOCATION MAP SHOWING ~'~ .~ BARROW WATER LAGOONS ~'~~ ,~ ..~ ~ ~. ~_, ~' ' „z ~' . ~! ` 1 r ~~ ~ ~ ' 4;?.~ `~` t1 .. ~ ~~~~~ '~~ r~ ATTACHMENT 13 • Aerial Photo LOCATION MAP SHOWING BUECI WATER LAGOON Image: Aero-Metric, Inc. 0 1,000 2,000 3,000 4,000 5,000 ASP6, NAD27 10,000 5/20/2010 FeA ~ Miles 0 • 0.5 1 1'40,000 2 3 ~4 i f 1 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 Before Commissioners: Daniel T. Seamount, Chair Cathy Foerster 3 John K. Norman 4 In the Matter of the North Slope ) 5 Borough's request for Disposal ) Injection Orders for South Barrow ) Docket DIO 10-O1 6 No. 13 and East Barrow No. 15 ) DIO 10-02 7 ALASKA OIL and GAS CONSERVATION COMMISSION 8 Anchorage, Alaska 9 May 18, 2010 9:00 o'clock a.m. 10 VOLUME I 11 PUBLIC HEARING 12 BEFORE: Daniel T. Seamount, Chair Cathy Foerster, Commissioner 13 John K. Norman, Commissioner 14 15 16 17 18 19 20 21 22 23 24 25 R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 • TABLE OF CONTENTS Opening remarks by Chair Seamount Testimony by Mr. Van Dyke Testimony by Ms. McMullen Testimony by Mr. Lowe Comments by Mr. Walsh Testimony by Mr. Stokes R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 03 06/15 07/24 08 13 42 r- i 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 P R O C E E D I N G S (On record - 9:02 a.m.) CHAIR SEAMOUNT: On the record. I'd like to call this hearing to order. Today is May 18, 2010, it is 9:02 a.m. We're located at 333 West Seventh Avenue, Suite 100, Anchorage, Alaska. Those are the offices of the Alaska Oil & Gas Conservation Commission. To my left is Commissioner Cathy Foerster, to my right is Commissioner John Norman and I'm Dan Seamount, the Chair. R & R Court Reporting will be recording the proceedings. You can get a copy of the transcript from R & R Court Reporting. We'd like to remind anybody that's testifying to speak into the microphones so persons at the back of the room can hear and so the Court Reporter can get a clear recording. This is Docket DIO 10-01 and DIO 10-02, by Application on February 24th, 2010 North Slope Borough requested approval of two UIC Class II disposal wells. They are the South Barrow No. 13 and the East Barrow No. 15, located in the Barrow Gas Fields. Wells Barrow 13 and East Barrow No. 15 are existing, depleted gas wells. Per application the North Slope Borough Plans to convert these to disposal wells while their 2010 and 2011 drilling program is underway. Upon completion of the drilling program the two disposal wells will be plugged and abandoned. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 3 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Notice of the hearing was published on March 29th, 2010 in the Anchorage Daily News and on April 1st, 2010 in the Arctic Sounder, as well as the State of Alaska on-line notices and the AOGCC web site. The AOGCC has received no comments from the public. This hearing is being held in accordance with 20 AAC 25.540 of the Alaska Administrative Code. The hearing will be recorded. If there's anybody not with the applicant -- not representing the applicant that would like to ask questions, the way to do that is to write your question and the person you'd like to ask the question of and hand it to our Special Assistant, Ms. Jodie Colombie. And she's in the back, she can raise her hand. Okay. I'm not sure there are any non- applicants willing to testify. And it looks like we have two people testifying from PRA representing the North Slope Borough. Before we start, Commissioner Foerster, do you have any comments? COMMISSIONER FOERSTER: Not at this time. CHAIR SEAMOUNT: Do you, Commissioner Norman? COMMISSIONER NORMAN: I have nothing. CHAIR SEAMOUNT: Okay. We will start with the applicant and then give the public opportunity to ask questions. Who would be first to testify? Okay. Both of you are going to R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 4 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 testify, is that correct? MS. McMULLEN: Correct. CHAIR SEAMOUNT: Okay. Are you giving sworn testimony? MR. VAN DYKE: Mr. Chairman, Bill Van Dyke with PRA. First, good morning. Commissioner Norman, Commissioner Foerster, good morning. If it's required, we can. CHAIR SEAMOUNT: It -- there's more credence to your testimony if it is sworn. So I would recommend it. MR. VAN DYKE: Mr. Chairman, I prefer to give sworn testimony. CHAIR SEAMOUNT: Okay. Are you? MS. McMULLEN: And I am too, I'm Barb McMullen. CHAIR SEAMOUNT: Okay. Both you please raise your right hand. (Oath administered) MS. McMULLEN: Yes. MR. VAN DYKE: I do. CHAIR SEAMOUNT: Okay. Do you both wish to be considered as expert witnesses? MR. VAN DYKE: Mr. Chairman, I would like to be considered as an expert witness. CHAIR SEAMOUNT: Ms. McMullen, would you? MS. McMULLEN: I would too. CHAIR SEAMOUNT: Okay. Let's start with Mr. Van Dyke. State your name, who you represent, what the subject or the R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 5 • • 1 2 3 4 5 6 7 8 9 10 11 12 13' 14 15 16 17 18 19 20 21 22 23 24 25 discipline is that you will be considered as an expert witness and your qualifications. TESTIMONY OF WILLIAM VAN DYKE MR. VAN DYKE: My name is William Van Dyke, I'm employed by Petrotechnical Resources of Alaska as a Petroleum Engineer. PRA, Petrotechnical Resources of Alaska, is working for -- is under contract with the North Slope Borough to prepare these applications for the disposal wells. I feel I'm qualified to make the applications and to make the findings in the applications that prevention of waste, protection of correlative rights, protection of fresh water will be achieved. CHAIR SEAMOUNT: Okay. We all know your qualifications and experience. MR. VAN DYKE: Sorry. I have a degree in Petroleum Engineering from Penn State. I've worked in the past for Chevron in Louisiana, for Gulf Oil Company in Pennsylvania and in Texas. Moved to Alaska in 1978 and was employed with the Department of Natural Resources from 1978 through 2007, held various engineering and management unitization positions within DNR. In 2007 I went to work for Petrotechnical Resources of Alaska as a Petroleum Engineer. I have worked on several of these disposal well applications since joining PRA, some with the EPA, some with the AOGCC, Kenai Field and the rest on the North Slope. CHAIR SEAMOUNT: Commissioner Norman, questions. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 6 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15' 16 17 18 19 20 21 22 23 24 25 COMMISSIONER NORMAN: I have no questions of Mr. Van Dyke. CHAIR SEAMOUNT: Commissioner Foerster. COMMISSIONER FOERSTER: I have no questions. CHAIR SEAMOUNT: Are there any objections to making Mr. Van Dyke an expert witness? COMMISSIONER NORMAN: No objection. COMMISSIONER FOERSTER: No objection. CHAIR SEAMOUNT: Okay. Unanimously, Mr. Van Dyke, you are to be considered as an expert witness. Ms. McMullen. TESTIMONY OF BARB McMULLEN MS. McMULLEN: I'm Barb McMullen, I'm with PRA and I'm a Geoscientist. I originally had my undergraduate degree at Ohio State University. I had my master's degree at University of Alaska, Fairbanks. I worked for British Petroleum for 10 years and now with PRA for 10 years. Most of my work at BP was with Milne Point and Endicott in both the business unit and in development geology. And now with PRA I've consulted out to Brooks Range Petroleum, done several for the North Slope Borough and various other geoscience projects. CHAIR SEAMOUNT: Thank you, Ms. McMullen. Commissioner Foerster, questions? COMMISSIONER FOERSTER: I have none. CHAIR SEAMOUNT: Commissioner Norman. COMMISSIONER NORMAN: No questions. CHAIR SEAMOUNT: Do I hear any objections to considering R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 7 1 Ms. McMullen as an expert witness? 2 (No objections) 3 CHAIR SEAMOUNT: Hearing none, Ms. McMullen is to be 4 considered an expert witness unanimously. 5 Okay. Who's going to start? 6 MR. VAN DYKE: Mr. Chairman, before Ms. McMullen and I go 7 through the formal application, there are two more people 8 seated at the front table. I'd like to introduce Mr. Dan Lowe 9 to my immediate right with the North Slope Borough and Mr. Tom 10 Walsh with PRA. And they both have brief opening statements 11 they'd like to meet if that's okay with you. 12 CHAIR SEAMOUNT: Okay. Welcome. And are you going to be 13 testifying other than the opening statements? 14 MR. LOWE: It depends if he wants me to. 15 MR. VAN DYKE: It's not planned at this time, Mr. Chair. 16 CHAIR SEAMOUNT: Okay. Well, if you do then we'll give 17 you the -- we'll..... 18 Do we need to swear him in? 19 COMMISSIONER NORMAN: Only if they're going to be 20 testifying as to factual matters. 21 CHAIR SEAMOUNT: Okay. If you are going to be testifying 22 -- called on to testify, that's when we'll swear you in and 23 consider you as an expert witness. Please proceed. 24 TESTIMONY OF DAN LOWE 25 MR. LOWE: My name is Dan Lowe, I'm a drilling consultant R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 8 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 ~ 22 23 24 25 with the North Slope Borough. And just a brief background, the purpose of what we're trying to do here is drill six new development gas wells and two in the East Barrow Gas Field and four in the Walakpa Field. This is basically driven by a supply demand issue for, you know, the Borough. I think that right now they believe their peak deliverable is 800 million cubic feet a day and I think the peak load they have seen on one or two occasions during not this winter, but past winter, was above 7, perhaps even 7.5. So the feeling is it's time for some additional production. And some of the other wells, of course, have depleted out and need repair. There is -- what happens in these fields, there's actually three separate fields, the South Barrow Field originally discovered by the Navy and then the East Barrow Field which was an extension of that discovered by the Navy and then the Walakpa Field to the south, discovered by Husky Oil in 1980 and '81, I forget. But, you know, so what has happened to the development is they will have a drilling period and then hopefully they'll go for 15; 20 years and have adequate supply before they bring another rig to the fields and do any more drilling. And that's -- so that's what's driving this right now. Our strategy a little different from the past, we want to drill horizontal wells, roughly 1,500 foot laterals, try to get more production and more stable production. And then the -- of course, the need for cuttings and liquid and mud disposal, R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 9 • 1 2 3 4 5 6 7 8 9 10 11 12 ~' 13 14 15 16 17 18 19 20 21 22 23 24 25 that's our, you know, one key expense and thing that has to be done and the Borough, they do want to live with the standards, of course, that they impose on industry or help to impose on industry. And, you know, the goal is to run, you know, a safe professional operation just like, you know, the -- any of the major operators would on the North Slope. And the key thing, I think our strategy is both the horizontal wells that we want to drill and also to keep our cuttings as clean as possible which, you know, my goal is just drill it with a water base mud with some brines. Everybody wants to put in lubricants if it gets tough drilling, but that will be the ultimate last result or last thing that, you know, I personally want to see. So that's -- you know, that's the project, the one thing, the timing, it's been pushed back by a year, it'll be the 2011 that we move the right to Barrow and then we will be done -- you know, we'll drill over the winter of 2011, 2012, demobe from the field in the following summer of 2012. CHAIR SEAMOUNT: Thank you, Mr. Lowe. Commissioner Foerster, do you have any questions? COMMISSIONER FOERSTER: While you're out there are you going to be doing any other work on any of your other wells? MR. LOWE: Yes, there's quite a few candidates, you know, the old wells have been picked for P&A, PP&A, and they'll be some -- you know, there's some pipeline work they want to do, R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 10 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21' 22 23 24 25 we'll be putting in -- of course, we'll be hooking up the new facilities, you know, more than just drilling. COMMISSIONER FOERSTER: Are these the wells that you inherited or you received from the BLM? MR. LOWE: Yes. COMMISSIONER FOERSTER: Okay. And a lot of those are just in need of elimination? MR. LOWE: Yes. Well, you know, the thing is, the -- because there's no workover rig around and it costs as much to mobilize a drilling rig as it does a workover rig up there, the wellbores themselves are, in my opinion, quite precious and if they're all of any use we need to look hard at that. In looking through some of these, I know -- I worked for Husky 30 years ago when I got out of school and they were doing the primarily the exploration drilling that was going on in NPRA at the time. So if you look at the casing designs on these little baby 2,200 foot gas wells, they've got some, you know, very stout, good -- you know, good, high quality thick pipe that you wouldn't typically see in a, you know, little gas field. COMMISSIONER FOERSTER: We're involved in an effort statewide to eliminate idle wellbores with no future utility or no -- get rid of wells before they become orphans and we're plodding through, but you're in -- on our list and we will be getting in touch with you. MR. LOWE: We should be. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 11 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16' 17 18 19 20 21 22 23 24 25 COMMISSIONER FOERSTER: Yeah. Okay. CHAIR SEAMOUNT: Anything else? COMMISSIONER FOERSTER: Not at this time. CHAIR SEAMOUNT: Commissioner Norman. COMMISSIONER NORMAN: Just, you know, listening to Mr. Lowe, it does occur to me there were some factual statements made and I think it might be advisable for the record to have Mr. Lowe put under oath and then ask him if he would acknowledge that everything he has said is true and correct to the best of his knowledge and so forth. Sorry for that, Mr. Lowe..... MR. LOWE: Yeah, no problem. COMMISSIONER NORMAN: .....but we didn't know quite what you were going to say..... MR. LOWE: Right. No, I understand. COMMISSIONER NORMAN: .....but you got into some specific representations of facts so we would like that on the record. CHAIR SEAMOUNT: Is there anything else? Okay. Mr. Lowe, please raise your right hand. (Oath administered) MR. LOWE: Yes. ,CHAIR SEAMOUNT: Thank you, Mr. Lowe. The only questions I have, I -- how many wells did you say you were going to drill? MR. LOWE: Well, it's budget driven, but our goal is for R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 12 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 ~ 22 23 24 25 six wells..... CHAIR SEAMOUNT: Six. MR. LOWE: .....two in the East Field and four in the Walakpa Field. CHAIR SEAMOUNT: And I assume they're all less than 3,000 feet? MR. LOWS: They'll have a measured depth of right around 4,000 foot and the..... CHAIR SEAMOUNT: Okay. MR. LOWE: .....Barrow sands are right around 2,250. CHAIR SEAMOUNT: Okay. And then I thought I heard you say the potential production is 800 million cubic feet a day? MR. LOWE: From the current wells, yes. MR. VAN DYKE: Eight million. MR. LOWE: Oh, did I saw 800 million. COMMISSIONER FOERSTER: You said 800 million. MR. LOWE: Excuse me. CHAIR SEAMOUNT: Okay. Unless there's any more comments, Mr. Walsh. COMMENTS BY MR. WALSH MR. WALSH: Thank you, Chairman Seamount. Commissioner Foerster and Commissioner Norman, good morning. My -- I'm Tom Walsh, I'm a Geophysicist and Managing Partner of Petrotechnical Resources of Alaska, an integrated oil and gas consulting company here in Anchorage, Alaska operating since R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 13 • 1 2 3 4 5 6 7 8 9 10 11 12 13 ~~ 14 15 16 17 18 19 20 21 22 23 24 25 1997. I'll keep my comments brief, I just want to give you a little bit of an update for our relationship with the North Slope Borough. We are consulting, as Mr. Van Dyke pointed out, for the North Slope Borough on this drilling and abandonment effort for the 2011/'12 season. We have been involved with the North Slope Borough in helping them to manage their Barrow Gas Fields since about 2006. In some of the studies we've undertaken our remaining reserves estimation, well remediation plan for some of these derelict wells, hydrate studies for potential hydrates associated with the Barrow Gas Fields, drilling design and operations for new development wells and working with the Borough on lease agreements associated with the exploration program that ConocoPhillips carried out several years ago. We'd like to just point out one other individual that is with PRA that is here today, Peter Stokes is with us and he may be called upon to provide expert witness testimony as well if needed. And I believe that's it. Thank you for the opportunity to be here today. CHAIR SEAMOUNT: Thank you, Mr. Walsh and welcome, Mr. Stokes. Commissioner Norman, any questions? COMMISSIONER NORMAN: No questions. CHAIR SEAMOUNT: Commissioner Foerster? R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 14 1 2 3 4 5 6 7 81 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 COMMISSIONER FOERSTER: Not at this time. CHAIR SEAMOUNT: Okay. Thank you, Mr. Walsh. Who's next? TESTIMONY OF WILLIAM VAN DYKE (CONTINUED) MR. VAN DYKE: Mr. Chairman, I'll start out. Bill Van Dyke with PRA. Today we'll present a discussion of our application. We would ask that our application as submitted be made part of the public record. The application as submitted had no confidential information included in it. As noted we've had a year push back in the project so the dates in the application, you know, as far as our -- when we'll be mobilizing and demobilizing, when we'll actually be operating the disposal wells. Those dates get pushed back one year. CHAIR SEAMOUNT: Okay. And your application's automatically in the record. MR. VAN DYKE: All right. Thank you, Mr. Chairman. There are pool rules for the Barrow Gas Fields, it's Conservation Order 233 for the Barrow Gas Fields, East Field and South Field and Conservation Order 274 for Walakpa Field. There's also an existing disposal injection order and that's DIO No. 5, that was for a disposal well that was utilized during one of the previous campaigns, same idea then as we have in mind now, to dispose of liquid wastes. We'll go through the application just section by section, give an overview, reference some of the exhibits, if that's okay with you. We don't have a Powerpoint slide, we don't have R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 15 1 2 3 4 5 6 7 8 9 10 11 12 13 !, 14 15 16 17 18 19 20 21 22 23 24 25 separate written testimony to submit, we'll use the application as the guideline. And there's a -- we submitted our cover -- the application had a cover letter from the North Slope Borough and then immediately following the cover letter there was a discussion of the approval criteria and that's the guide we'll use today for today's hearing. Our application is for approval of two Class II disposal wells, we plan -- as stated we plan to convert two existing inactive gas wells to disposal wells, those are South Barrow 13 and East Barrow 15 wells. You'll notice in some of the literature that East Barrow 15 well is referred to as the South Barrow 15 well. The naming convention up there got a bit confused over the years, but there are two fields, South Barrow and East Barrow, and we try to call the wells in the South Field South Barrow wells and the wells in the East Barrow Field East Barrow wells. We don't plan to utilize our disposal wells for a long period of time, this is, you know, different that Kuparuk or Prudhoe Bay or some of the Cook Inlet operations, we'll just be using the disposal well while a rig is in the field, basically, you know, less than a 12 month period. Probably it'll be active for no more than eight months. We don't plan to have a grind and inject facility on site. If we do -- well, we just don't plan to have one right now, we don't -- we're looking at other options and feel we have other R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 16 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 good options for disposal of cuttings. So we're looking to dispose of about 30,000 barrels of liquid. If we have to have a grind and inject plant on site that number would probably go up to about 50,000 barrels of liquid and slurry cuttings. So we would be asking for if there is a limitation placed on these wells that it be at least 50,000 barrels. Likewise if there's a limitation placed on the wells for a time period of operation, we would ask for a 12 month season to operate the disposal wells. And that would be of actual disposal operations rather than any pretesting for injection tests or anything like that, but actually a 12 month period of actual operation of the disposal wells. Section 2 of the discussion is the burden of proof. We feel like we have met the burden of proof to protect the public interest, we don't feel like oil field waste would travel into other formations other than the Barrow sands, we feel it would be isolated to the Barrow sands and the oil field waste would not move into sources of fresh water. In addition there are no commercial hydrocarbon bearing zones either above or below the Barrow sand. We submitted Section 3 of the approval criteria, is a location map, plat maps or attachments 2, 3 and 3A are plat maps that show the wells and the fields. Attachment 2 shows both the East Field and the South Field and the wells in those fields. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 17 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Attachment 3 is a plat that shows a close up of the South Barrow Field. I will note that there's a well missing on that map, that layer must not have been turned on, I just noticed there's a well, South Barrow 10, that just didn't print out on that map. It's about a half mile away from the proposed disposal well. We can get you a revised attachment 3 to our application with that well on there. It's about half a mile north of the disposal well, of well South Barrow 13. And that's attachment 3 to the application, we'll get you a revised copy. And then attachment 3A is East Field close up of the proposed disposal well which is up at the top of the page and then attachment 3A also shows the wells that Mr. Lowe spoke to, the two new horizontal wells and they are the -- shows the proposed well paths for those two new proposed wells. And they are nowhere near the proposed disposal well. Section 4 of the approval criteria was the operator and surface owners, identification of those surface owner is UIC and the mineral state owner and the operator is the North Slope Borough. Section 5 of the approval criteria was providing an affidavit of notice to the surface owners and the operators, that affidavit was included in the application and I can submit today copies of the FedEx notification that the applications were served to both UIC and the North Slope Borough by FedEx R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 18 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 delivery. And that leaves one of the more technical sections, that's the geologic report and the wells logs and Ms. McMullen is going to cover that area. CHAIR SEAMOUNT: Commissioner Norman, do you have any questions? COMMISSIONER NORMAN: Does ASRC have any, Arctic Slope Regional Corporation have any position in this area? MR. VAN DYKE: Commissioner Norman, not in this immediate area, not in the three gas fields..... COMMISSIONER NORMAN: Yeah. MR. VAN DYKE: .....but they do have a position to the south..... COMMISSIONER NORMAN: Yeah. MR. VAN DYKE: .....and I think the map makers map that you have here would..... COMMISSIONER NORMAN: Yeah. MR. VAN DYKE: .....would show that. COMMISSIONER NORMAN: Okay. CHAIR SEAMOUNT: Commissioner Foerster? COMMISSIONER FOERSTER: I have a couple questions. What is your plan if you don't use a grind inject, what is your plan for your solids? MR. VAN DYKE: First and foremost, we hope to keep our cuttings very clean and we -- we're 99.9 percent sure that we R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 19 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 a can dispose of clean cuttings in the North Slope Borough landfill..... COMMISSIONER FOERSTER: Okay. MR. VAN DYKE: .....the Barrow landfill. COMMISSIONER FOERSTER: Okay. My second question is when you talk about not damaging any fresh groundwaters, have you done any simulation runs on injecting in any wells in this -- in either of these reservoirs? MR. VAN DYKE: Commissioner Foerster, we discuss that in the application, but the short answer is we have not -- PRA does not have a fracture simulator and we have not contracted with a third party to run fracture simulations, but I do have some examples of operations in the Barrow Fields that are.-- where wells were acid stimulated or fractured or the SB 5 well which was used as a disposal well. COMMISSIONER FOERSTER: Okay. Well, in other wells that were fractured, were simulations done to design those fractures? MR. VAN DYKE: There was a was a service company write-up, description, but I'm not -- I'm call that a fracture simulation that I've seen in recent time, that are run. -- Commissioner Foerster, there you know, a prefrac job not sure that was -- I would in the -- in the same terms she fracture stimulation designs COMMISSIONER FOERSTER: So there was no simulation design R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 20 ~ ~ 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 that we typically see that models the pressures and the..... MR. VAN DYKE: Commissioner Foerster, no. COMMISSIONER FOERSTER: Okay. MR. VAN DYKE: There was a post-fracture analysis, you know, that calculated out the fracture length was about 50 feet..... COMMISSIONER FOERSTER: And did it..... MR. VAN DYKE: .....you know, in a well that was fractured. COMMISSIONER FOERSTER: .....did it calculate a frac height? MR. VAN DYKE: No, it did not. COMMISSIONER FOERSTER: Okay. So -- okay. But did the frac appear to stay in zone, did -- was there any analysis that could support that a fracture didn't grow into freshwaters or anything? MR. VAN DYKE: Commissioner Foerster, there was no evidence that the fracture grew out of zone or that there was any problems with the wellbore or the wellbore construction. COMMISSIONER FOERSTER: Okay. MR. VAN DYKE: It..... COMMISSIONER FOERSTER: You understand what I'm fishing for? MR. VAN DYKE: Yeah. The fracture was operational, it was a -- it was one of those operations that was a technical R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 21 1' 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 success, but it probably was not an economic success, you know, the well had not produced at all before and it -- after frac it produced at a very marginal rate at best. COMMISSIONER FOERSTER: Okay. Thank you. CHAIR SEAMOUNT: Commissioner Norman. COMMISSIONER NORMAN: Mr. Van Dyke, if you -- where is the nearest offtake point for fresh water utilized by the public in that area, Barrow, Wainwright or other, if you know? MR. VAN DYKE: Commissioner .Norman, it would be surface water in Barrow and I don't know exactly which -- where that is. We could chase that down for you if you would like. COMMISSIONER NORMAN: Well, as you know that's an important responsibility of ours to protect freshwater so that would be appreciated if you could after the hearing, we could leave the record open if you could let us know where the closest offtake point is for freshwater. MR. VAN DYKE: Will do. COMMISSIONER NORMAN: That's all. CHAIR SEAMOUNT: Thank you. Mr. Van Dyke, according to our production records the number 15 well was producing 160 mcf a day when it was shut-in which -- I mean, that's within the same order of magnitude as the other producers in the field. Is -- are any of the wells planned to be drilled going to somewhat offset this well? MR. VAN DYKE: Mr. Chairman, for the EB 15 well we plan to R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 22 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19, 20 21 22 23 24 25 drill two horizontal wells in that same gas pool. CHAIR SEAMOUNT: Okay. And then you're going to be disposing of at least water into the same zone that you're going to be producing from in the other wells. Are you aware of any kind of compatibility of the water with the reservoir? MR. VAN DYKE: Mr. Chairman, we couldn't find any incompatibility issues, you know, in prior injection operations. CHAIR SEAMOUNT: Okay. MR. VAN DYKE: And the volume -- you know, if all the volume -- if we injected the full 50,000 barrels even in EB 15, you know, and I guess in a vacuum 50,000 barrels sounds like a lot of fluid, but when you do the calculations, I mean, you're only going to have a zone of influence of maybe 150 feet away from that well. It's -- you know, this is not gas cap water injection at Prudhoe Bay or grind and inject disposal operations at Prudhoe Bay, I mean, it's -- in the grand scheme of things as far as disposal operations, it's relatively small, but at the same time it's very important for the Borough. CHAIR SEAMOUNT: Okay. Thank you. Any other questions or comments? COMMISSIONER FOERSTER: I have more, but I'm going to wait..... CHAIR SEAMOUNT: Okay. COMMISSIONER FOERSTER: .....maybe they'll be addressed. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 23 1 2 3 4 5 6 7 8 9 10 11 12 i 13' 14 15 16 17 18 19 20 21 22 23 24 25 CHAIR SEAMOUNT: Okay. Is it Ms. McMullen's turn? TESTIMONY OF BARB McMULLEN (CONTINUED) MS. McMULLEN: Okay. Commissioners, I'm just going to go over the geology section here of 6 and the well .section on 7. As pointed out earlier we have the two candidates for disposal, SB 13 and East Barrow 15, again located in separate gas fields. The South Barrow 13 is in the South Barrow Gas Field and as labeled typically SB 15 is in the East Barrow Gas Field. Our proposed disposal interval is the Barrow sandstone and in these wells, it's located at a depth where the sands are either water wet or gas depleted. And neither well is any longer producing gas. South Barrow 13 is located in an isolated fault block with one other well, NSB 02, and both wells right now are planned for P&A after this drilling campaign is over. And SB 13 is a structurally lower well. South Barrow or East Barrow 15 is structurally the deepest well in the East Barrow Field and it is on the northern flank of the field. Both of our new wells that we plan to drill will be going due south and due east, so the opposite direction from where this injection -- disposal injection well is going to be used. The geology of both gas fields is well understood due to good well control, core and log data and 2-D seismic in the area. Reservoir properties and the lateral continuity of reservoir sands are well documented. The geologic report describing the proposed injection interval and confining layers R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 24 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19' 20 21 22 23 24 25 is provided in this attachment 1 here along with a lot of the graphics and maps. And I would like to point out in"attachment 1S, it is mislabeled, it should be the -- it's a structure map, it should be the top of the upper Barrow sandstone and not the Walakpa sandstone. Do you need an additional map with the title change or is that something that -- on the record now that's..... CHAIR SEAMOUNT: I would think we should. COMMISSIONER FOERSTER: Okay. CHAIR SEAMOUNT: Or we shouldn't? COMMISSIONER FOERSTER: Well, I was thinking we could just scratch it out and write the right name. CHAIR SEAMOUNT: Is that legal, Mr. Assistant Attorney General? MR. BALLENTINE: I didn't hear the proposal. CHAIR SEAMOUNT: Commissioner Foerster's proposal was to hand correct the error on one of the maps that the applicant supplied, I -- we do that with..... MR. BALLENTINE: It might be better if the applicant..... CHAIR SEAMOUNT: It would be better if the applicant did it? MR. BALLENTINE: Yeah. CHAIR SEAMOUNT: Why don't you hand scratch it? MS. McMULLEN: Okay. All right. The Barrow sandstone averages about 100 gross feet in this area and is comprised on R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 25 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 consolidated sands and shales. The sands contain relatively low porosity values, anywhere from 4 to about 24 percent and permeability. values are under about 400 millidarcies. And also note for the purposes of this report the Walakpa sandstone is included in the pool here in the Barrow -- with the Barrow sandstone in the South Field, even though the Walakpa sand is about 100 vertical feet above it. So part of the pool, that Walakpa sand's in there. And that particular sand at South Barrow does have perforations, but in the East Barrow Field the Walakpa sands are not perforated. Structurally the Barrow sandstone is encountered around 2,000 feet subsea and faulting is minor in both fields and reservoir structure therefore is relatively uncomplicated. The Barrow sandstone lies between two substantial confining layers and it is capped by about 1,000 feet of permafrost. The base permafrost is estimated at a minimum depth of about 1,000 feet subsea and that is based on temperature surveys in these wells. Beneath the permafrost a thick sequence of about 1,000 feet of lateral extensive cretaceous shales and sand stringers act as a confining cap for the disposal interval. No commercial hydrocarbons are found above the Walakpa sandstone. And again note that the Walakpa sandstone in South Barrow is perforated. And below the Barrow sandstone a relatively thin sequence, about 50 to 200 feet of triassic sands occur just above the argillaceous basement and no commercial hydrocarbon bearing R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 26 1' 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 zones underlie the Barrow sandstone in either field. So with the cap above and cap below we feel that the Barrow sandstones are confined. And section 7 shows the well logs for South Barrow 13 and East Barrow 15. South Barrow 13 was drilled to argillaceous basement and 2,476 measured depth, but East Barrow 15 was not drilled to basement, only about a 100 measured depth feet below the lower Barrow sandstone. And perforation intervals are also annotated on the logs. CHAIR SEAMOUNT: Commissioner Norman, do you have any questions? COMMISSIONER NORMAN: No questions. CHAIR SEAMOUNT: Commissioner Foerster? COMMISSIONER FOERSTER: I have a few. Do you have the original reservoir pressure for the Barrow sand? MS. McMULLEN: Commissioner, I do not have that initial information. Dan, do you? MR. LOWE: Well, I mean, how exact. It's right around 960. COMMISSIONER FOERSTER: And how about the current, is there an estimate of the current pressure? MR. LOWS: Go ahead. MR. VAN DYKE: Commissioner Foerster, Mr. Stokes is prepared to speak to reservoir pressures and POZ analysis and reserve reports that PRA has prepared for the North Slope R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/fax 274-8982 ANCHORAGE, ALASKA 99501 27 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Borough. And if it's okay with you he would do that after we run through the formal sections in the application. COMMISSIONER FOERSTER: Okay. I can wait for that answer then. You said that the 15 was now wet and the 13 is now depleted, is that correct? MR. LOWE: 15 was drilled into the water leg, the lower Barrow sand was in water, the upper Barrow was in gas. So it was a very poor well from the beginning. So it wasn't -- it wasn't one of the better wells. And South Barrow 13 has been depleted, it no longer -- neither one is producing anymore. COMMISSIONER FOERSTER: And neither one has the capability of producing? MR. VAN DYKE: Commissioner, I wouldn't -- I would say that if you went in and worked over these wells and, you know, plugged off water and spent a lot of money, you could probably still get a little bit of gas. I wouldn't deny that that's possible, but that would not be the wise choice in this case. COMMISSIONER FOERSTER: Thank you. That's all right now. CHAIR SEAMOUNT: Okay. You mentioned the fault box, Ms. McMullen, do these faults seal? MS. McMULLEN: Chairman, I believe they do seal along with microfaults in there that were formed prior to hydrocarbon migration. We do see pressure differences, especially in the South Field between the NSB 2 and South Barrow 13 wells and the fault block to the north, so yes, we're going on the consensus R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 28 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 that it's sealing. CHAIR SEAMOUNT: What's the displacement on the faults? MS. McMULLEN: It varies anywhere from 10 to 15 feet to maybe, you know, 50 feet. CHAIR SEAMOUNT: Okay. They're little baby ones then? MS. McMULLEN: Correct. CHAIR SEAMOUNT: You mentioned argillaceous basement..... MS. McMULLEN: Basement. CHAIR SEAMOUNT: .....what age is this argillaceous basement? MS. McMULLEN: It's the metamorphic rocks..... CHAIR SEAMOUNT: Is that right? MS. McMULLEN: .....that are below the -- yeah. CHAIR SEAMOUNT: Okay. All right. On the structure maps it shows number 13 almost as high as a lot of the producers and, I guess, if it's depleted and the other ones are not then, I guess, that where your fault block, fault trapping comes in, is that interpretation correct? MS. McMULLEN: Yeah, Mr. Chairman. That's the fault block, that east/west fault there is the one that's sealing this NSB 2, South Barrow 13 area from the northern area here. And I believe neither well right now is producing, but..... MR. VAN DYKE: Well, if I may, Mr. Chairman. Actually NSB produces at low rates, but it's only because in the past that's where the Borough had its mercaptan injection point, you know, R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 29 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19' 20 21 22 23 24 25 where it puts the odorant into the natural gas. And that mercaptan station is being moved and the Borough would prefer not to produce NSB 2. CHAIR SEAMOUNT: Okay. MR. VAN DYKE: Once the mercaptan station is moved. CHAIR SEAMOUNT: Well, I believe that number 2 is quite a bit higher structurally than the number 13? MS. McMULLEN: Correct. CHAIR SEAMOUNT: Okay. COMMISSIONER FOERSTER: But they're both going to be plugged? MS. McMULLEN: They're both slated for P&A. CHAIR SEAMOUNT: What kind of drive is this, you mentioned -- I think someone -- you've mentioned water production, watered out, is it a strong water drive? MR. VAN DYKE: Mr. Chairman, Mr. Stokes and Pete will speak to that..... CHAIR SEAMOUNT: Okay. MR. VAN DYKE: .....you know, once we get through the rest of the application. But it's a -- it's very -- you know, the fields are very interesting because of the hydrate -- presence of the hydrates. CHAIR SEAMOUNT: Okay. Any other questions or comments? COMMISSIONER FOERSTER: Not at this time. COMMISSIONER NORMAN: No questions. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 30 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 MR. VAN DYKE: Mr. Chairman, I'll go back on the record. Bill Van Dyke with PRA. Number 8 in the approval criteria speaks to the well casing information and mechanical integrity. We've provided attachments, 6 and 6A show the well construction for both wells, attachment 7 and 7A show the well schematics and attachments 8 and 8A show the tubing and casing specifications. I think it was noted, but I'll repeat it again. Both wells are completed without packers and both wells at this moment have open perforations. I don't know how much detail you want me to go through on the well construction, I mean, the completion diagrams, the completion reports, you know, have the casing information, cementing information. I would -- I guess for the record at least I'll note that, you know, well EB 15 had a two stage cement job, there's about 750 feet of cement in the bottom of the well across the Barrow sands, then there's another oh, plus or minus 400 feet of cement up at 1,300 feet. If you -- if you do the math those two cement jobs should have overlapped, but there's no way to guarantee that they did. But there's certainly adequate cement in that well in a 7 inch casing, while SB 13 was -- the casing is cemented all the way to surface. COMMISSIONER FOERSTER: And do you have any cement bond logs for either of those wells? MR. VAN DYKE: Yes. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 31 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 COMMISSIONER FOERSTER: And what do those look like? MR. VAN DYKE: Commissioner, I don't feel qualified to look at the bond logs and they were found to be acceptable when the wells were drilled at the time. And the casing was tested before. COMMISSIONER FOERSTER: Mr. Lowe, are you qualified to make an assessment on those -- the quality of those bond logs? MR. LOWE: Yes. COMMISSIONER FOERSTER: Would you do so? MR. LOWE: As soon as I find them, yes. COMMISSIONER FOERSTER: Okay. CHAIR SEAMOUNT: We may have them. MR. LOWE: Oh, really. Okay. COMMISSIONER FOERSTER: We have them. MR. VAN DYKE: We have one, Commissioner. MR. LOWE: They did do a 2,000 pound pressure test of the casing and the casing does have two FO, you know, sliding sleeves, you know, that they cemented through, but after the casing test they ran the wireline logs and, you know, there's nothing else that went into the hole after that that would have accidently opened those sleeves, plus they did the casing test. They produced it for five or six years and never saw any kind of leakage so that should still be fully adequate. COMMISSIONER FOERSTER: Thank you. MR. VAN DYKE: Again I don't know if it's your preference R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 32 1 2 3 4~, I 5' 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 to actually just, you know, read through the completion report, you know, and state all the casing strings and depths, I -- it's..... COMMISSIONER FOERSTER: I don't think we need that, do you? CHAIR SEAMOUNT: I think it's in the record, yeah. MR. VAN DYKE: It's on the record. Okay. Thank you. As far as the types of fluids that we wish to inject, we listed those in our discussion in section 9, it's a rather lengthy paragraph because we wanted to be as explicit as we could on the types of injection fluids we hope to inject. They would all be approved Class II fluids and we're asking for -- to be allowed to inject at least 50,000 barrels maximum. And I don't think I maybe stated this earlier. We're -- at this point in time we're not sure if we're going to use both wells or only one well and if we only use one well we don't know which of the two wells that would be so we'd like to have both wells approved. COMMISSIONER FOERSTER: So in your application you listed camp waste as a disposable fluid, that's not Class II? MR. VAN DYKE: Okay. COMMISSIONER FOERSTER: So that would not be something that we allow you, are you aware of that? MR. VAN DYKE: Yes. COMMISSIONER FOERSTER: Okay. Okay. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 33 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 MR. VAN DYKE: And in addition as far as the injection fluids, we would -- we would request approval regardless of which well we use and which field it's in, that we be allowed to inject waste from all three gas fields into that well. COMMISSIONER FOERSTER: Okay. MR. VAN DYKE: So if the well's in East Barrow, we would like to be able to bring fluids over from South Barrow and from Walakpa. COMMISSIONER FOERSTER: But no domestic waste? MR. VAN DYKE: No, no domestic waste. COMMISSIONER FOERSTER: Okay. MR. VAN DYKE: We have an agreement with the North Slope Borough that camp waste will go to the Barrow wastewater treatment plant. As far as maximum injection pressures and surface pressures and average injection rates, again the -- there have been, and this information is in your records, Glasby (ph) 5 was used as a disposal well, again in the exact manner that we're proposing to use these two wells, while SB 13 was fracture stimulated while SB 20 was acid stimulated. And those wells have no problem with well construction issues and were able to take fluids, injection fluids, successfully. Now we looking at those past operations, you know, average injection pressures were between 400 and 800 pounds at the surface. In order to kick off the wells pressures were in the range of R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 34 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 1,200 to 1,500 pounds, just to get fluids to start to move at least on one of the operations, but then average pressure after that was 400 to 800 pounds, couple barrels a minute injection rate. And we would certainly have -- our injection pumps would be equipped with safety relief valves, you know, safety shutoff equipment and certainly proper measurement equipment for volumes. You know as far as the fracture information that Commissioner Foerster asked about earlier, we did not contract out to have a separate simulation analysis run by a third party. We plan to limit our injection pressures and we also plan to inject in relatively small batches because, you know, we'll be drilling one well at a time and so there'll be some liquid waste from one well at a time then there'll be down time in between. And at least from the fracture simulation models that I've seen run for other operations, when you inject -- when you do this off and on sort of batch disposal, the model results I've seen is that you tend to grow lots of short, small fractures, you don't grow one long fracture because you're injecting -- you inject for a day and then you shut down for a week, you know, or you inject for two days and then you shut down for a week. And so at least the modeling I've seen in the past is that you -- if you do fracture you grow a series of very small fractures along the wellbore rather than one very long fracture. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 35 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 COMMISSIONER FOERSTER: How would that work since do -- do the stresses -- are the stresses different at this shallow a depth because, you know, in my experience with fracturing you follow the plane of least principal stress, and everything you pump is going to go on that plane. So I wouldn't imagine a fan of different fracs, I would imagine the same -- the same cracks coming open again and again and again. And..... MR. VAN DYKE: I am not a fracture simulation expert or rock mechanics expert, but just having reviewed some of these studies in the .past which are in your records, you know, available for the Commission to review, that is the rock mechanics behavior that are exhibited. Section 12 of the approval criteria are the formation water quality information. Again we have a pretty good inventory of water samples from South Barrow and East Barrow. They're included in attachment 9 in the application. Total dissolved solids are -- well, the lowest one I saw was 16,000 parts per million TDS, most of them are in the range of 20 to 25,000 parts per million total dissolved solids. There was no subsurface freshwater or drinking water sources penetrated by these wells and we will follow-up as far as the Barrow freshwater sources. And as Ms. McMullen said, the permafrost thickness is in the range of about 1,000 feet in the area of both wells. One of the orders, and I think it's a disposal injection order at R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 36 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 that time used a permafrost depth of about 500 foot thickness and there's been a lot of study done since then on permafrost in this area and certainly we believe that the permafrost depth is closer to 1,000 feet rather than the 500 feet that's included in one of the orders for these fields. With respect to aquifer exemptions, based on the water salinities we don't believe an aquifer exemption is required. We hope that that is also the ruling from the Commission. COMMISSIONER NORMAN: And that's based upon water quality analysis information you've provided? MR. VAN DYKE: Yes, that's based on the..... COMMISSIONER NORMAN: Yeah. MR. VAN DYKE: .....water qualities that are shown in attachment 9 to the application. With respect to mechanical integrity of other wells within a quarter mile radius, there are no existing wells within a quarter mile radius of either SB 13 or EB 15 and the new wells we've proposed to drill will not be within a quarter mile radius of either well. Section 15, mechanical integrity demonstration, as I stated these wells are existing wells, they have casing, tubing handing in the casing, no packer and open perforations so we would request a waiver for an exemption on some of the mechanical integrity testing requirements because we cannot test -- we have no packer to test against between the casing R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 37 i ~ 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 I 18 19 20 21 22 23 24 25 and tubing in that annulus. And we don't plan to have -- to bring a rig on location for either well. Both wells are located some distance away from where we will be drilling so the plan would not be to come in first and workover these wells. We believe a waiver is warranted because the wells have exhibited good cement and construction properties. The casing was tested in the wells when they were drilled. Our injection volumes will be relatively small when you think about disposal wells in the grand scheme of things. Our injection operations will have a limited period of time when we're actually using the wells and we'll be using them in intermediate stages even when we do use them. We will so closely monitor the surface injection pressures and casing pressures. There was a formation integrity test run in EB 15, that's in your records. It's shown in attachment 10 in the application. That was the only actual formation integrity test that I could find in the records, you know, when these wells were being drilled. And I think they tested to a gradient of .61 PSI per foot when they -- in that test. No mechanical integrity problems have been noted during the previous well stimulation or disposal injection operations. The production history for these wells are shown, it's attachment 11 and 11A, the last two attachments. Both wells have been shut-in for a number of years. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 38 ~ M 1 2 3 4 5 6 7 8 9 10 11 12 13 14 I 15 I 16' 17 18 19 20 21 22 23 24 25 With respect to the mechanical integrity of other wells within a quarter mile radius, again there are no other wells within a quarter mile radius. And then section 17, well design construction and testing, again, you know, the wells are cemented across the disposal interval and well above the disposal interval. We would request a waiver that the wells be required to be completed with a packer. And again attachments 6, 6A, 7, 7A and 8, 8A, show the well construction details which we believe are sufficient. Then with respect to notices to be filed with the Commission, we will file these notices as required. We have not prepared -- for example, we've not prepared sundry notices for any P&A operations yet or any conversion operations for these wells or permits to drill for the new wells. We'll get that in -- get those in with plenty of time to spare, but -- and we realize we have to do that, but we'll get them in as required. That's a go through the application at least on a high level. If you have any questions now we could entertain those and as I said Mr. Stokes is here to -- if you're interested more in the reservoir dynamics, the gas pool dynamics themselves rather than the disposal well specifically, Mr. Stokes could speak to that. CHAIR SEAMOUNT: Commissioner Foerster, any questions? R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 39 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 ~I 16 17 18 19 20 21 22 23 24 25 COMMISSIONER FOERSTER: None. CHAIR SEAMOUNT: Commissioner Norman. COMMISSIONER NORMAN: Just maybe to avoid recall, the proposal here then is for injection of between 30 and 50,000 barrels of liquid and some solids, is that right, within a maximum of a one year period? MR. VAN DYKE: Commissioner Norman, that's correct. We would request 30,000 barrels of liquids and then as a contingency another 20,000 barrels of slurried cuttings. COMMISSIONER NORMAN: Okay. And then could you summarize again the waivers that you feel -- you're asking for? MR. VAN DYKE: We would ask that the wells not be required to be completed with a packer, so waiver on the packers. COMMISSIONER NORMAN: Right. MR. VAN DYKE: And a waiver on the requirement for a mechanical integrity test on the annulus because we have open perforations and no packer so we can't -- we have a hard time getting there otherwise. COMMISSIONER NORMAN: Okay. Thank you. CHAIR SEAMOUNT: Thank you. Methane hydrates were mentioned, what depth are they located at? MR. VAN DYKE: I hate to put you off, but Mr. Stokes and Mr. Walsh are the hydrates experts..... CHAIR SEAMOUNT: Okay. MR. VAN DYKE: .....and they've spent a lot of time R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 40 1 2 3 4 5 6 7 8 9 10 11 12 13' 14 15 16 17 18 19 20 21 22 23 24 25 studying that in our fields. CHAIR SEAMOUNT: Well, it's an interesting aside. MR. VAN DYKE: Yeah. CHAIR SEAMOUNT: Okay. Are you two finished testifying for now? MR. VAN DYKE: Just one closing comment, I mean, you mentioned hydrates, you know, this project started, there was going to be a -- the federal government was going to be involved and it was going to be a hydrates gas science project. And that helped get the project going, they were going to help fund mobe and demobe of the rig, you know, some of the equipment, some of the standby. And they -- that went along for a few years and last year -- late last year, the federal government pulled out of the project. And that got rid of the gas hydrates science tests. It also got rid of a big piece of the budget that we were hoping to use and so we've been scrambling ever since to revise the project. But that's just sort of a little bit of the history on the gas hydrate. You may have read something about proposal to drill some hydrate test wells up there, that was going to be a federal campaign that is no longer on the books. CHAIR SEAMOUNT: Okay. Thank you, Ms. McMullen and Mr. Van Dyke. And if you please hang around unless we want to ask you further questions. Okay. Mr. Stokes, I guess we'll swear you in. Please R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 41 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19~ 20 21 22 23 24 25 raise your right hand. (Oath administered) MR. STOKES: Yes. CHAIR SEAMOUNT: Okay. Would you please state your name, who you represent, whether you want to be an expert witness and I assume you do, and what would be the discipline that you're going to be considered as an expert witness for and what your qualifications. TESTIMONY OF PETE STOKES MR. STOKES: Okay. My name is Pete Stokes and I work for PRA and have done quite a few projects for the North Slope Borough as a petroleum engineer. I have a degree in Mining and Mechanical Engineering from the University of Alaska. I am a licensed Petroleum Engineer in the state of California and the state of Alaska. I've worked previously for Union Oil and Unocal in Alaska and California, Oklahoma, Indonesia and then back in Alaska. I've worked for PRA since about 2004 and as I stated I've done several studies on these reservoirs in the North Slope Borough's gas fields. What I'm going to talk about is sort of the reserve study that I did back in 2006 for the East Barrow Field and the South Barrow Fields. CHAIR SEAMOUNT: Okay. Thank you, Mr. Stokes. Commissioner Norman, any questions? COMMISSIONER NORMAN: I have no questions. CHAIR SEAMOUNT: Commissioner Foerster? R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 42 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19! 20 21 22 23 24 25 COMMISSIONER FOERSTER: None. CHAIR SEAMOUNT: The only question I have is what's more difficult, to be licensed in California or Alaska? MR. STOKES: Well, I took the test once and then I got commodity in Alaska, but I do..... CHAIR SEAMOUNT: Okay. So Alaska recognizes..... MR. STOKES: .....have to do continuing education credits in Alaska whereas I don't in California. So I don't know if that's any..... CHAIR SEAMOUNT: So Alaska's more of a pain? MR. STOKES: Well, I mean, I took the -- initially took the test when I was working in California. So..... COMMISSIONER FOERSTER: And you had to get Arctic engineering to get commodity here? MR. STOKES: Correct, yes. COMMISSIONER FOERSTER: Yeah, okay. CHAIR SEAMOUNT: Okay. Do I hear any objections to naming Mr. Stokes as an expert witness? COMMISSIONER NORMAN: No objection. COMMISSIONER FOERSTER: No objection. CHAIR SEAMOUNT: Hearing none, Mr. Stokes will be considered as -- or is defined as an expert witness unanimously. MR. STOKES: Thank you. CHAIR SEAMOUNT: What is the word? R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 43 ~ ~ 1 2 3 4 5 6 7i 8 9I 10' 11 12' 13' 14 !~ 15 16 17 18 19 20 21 22 23 24 25 COMMISSIONER NORMAN: Accepted. CHAIR SEAMOUNT: Accepted. Sorry. English wasn't my best subject. MR. STOKES: There have been several questions around reservoir pressure and reservoir drive mechanisms and I'll just sort of give you sort of a brief overview of my knowledge of the fields. PRA was engaged back in 2005 to do a reservoir reserve study in the Walakpa Field and we did go out and get downhole pressure data in Walakpa and wrote up a reserves report for them. Subsequently they asked us to do the same for their South and East Barrow Fields. As was pointed out earlier, there's some naming conventions, I believe, the AOGCC refers to the East Field as the East Pool of the South Barrow Field and then the South Field as south of the South Pool of the South Barrow Field. CHAIR SEAMOUNT: That was before my time. MR. STOKES: Unfortunately it's very confusing to really understand where the wells were and where the well records were, but we've sort of gotten past that. I have researched a lot of the earlier well records in the South and East Barrow Fields and have found work that had been done previously when they drilled the wells. And just talking about South Barrow 13 which is in the NSB 2 fault block if you will which is isolated from the other wells in the South Barrow R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 44 ~ r 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Field, there's two wells and the original pressures that were reported for South Barrow 13 was 859 PSI and the original pressure reported for NSB 2 was 896 PSI. Now once again in researching records oftentimes you're not able to really pinpoint exactly where that pressure was estimated at, but that's what I found in the record. For our 2006 pressure campaign we did downhole pressure build-ups in NSB number 2 and found that fault block pressure at that time to be 758 PSI. It's a rather small fault block, it hasn't been too much depleted and the reason why is both of those wells were pretty poor wells from a permeability standpoint and they just were not very good producers. I might point out here that we were talking about having a well being able to -- capable of producing 150 MCF a day and that was sort of the last producing rate that is shown on the records. V,]hat has evolved over the years with the -- supplying the city of Barrow with gas is initially the South Field was discovered and produced and it met all of their fuel needs. Subsequent to that the East Barrow Pool was discovered and it helped meet additional needs. And then in 1990 the Walakpa Field was discovered and then subsequently developed and now it meets substantially all of the Borough's needs for gas to supply the city of Barrow. Unfortunately Walakpa is not accessible by roads, it's -- there's a pipeline only and it's R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 45 1 2 3 4 5 6 7 8 9 10 11 12' 13 14 15 16 17 18 19 20 21 22 23 . 24 25 accessible either by helicopter on tundra travel vehicles or obviously ice -- snow roads in the wintertime. So it's not very convenient to operate as it would be if you could drive to the wells. But unfortunately it's the bulk of the remaining reserves for the North Slope Borough providing energy to Barrow. So it's the area where we're going to drill four wells in this -- in this development program. And the two wells that'll be drilled in East Barrow are wells that will provide sort of an alternative supply in case there's something that happens to the Walakpa pipeline, for example, or -- and they are accessible by road and they are pretty high reservoir pressure currently. And I'll get into my hydrate story in a minute, but so that's sort of the -- how the development has played out for the Barrow Gas Fields including Walakpa. Well, once Walakpa was developed and was capable of producing at averages of 500 and 600 MCF a day, the smaller depleted gas wells in -- specifically in the South Field, and the wells are not as capable in the South Field such as SB 13 and NSB 2, they were not operated because it takes a lot of effort to produce a well and keep it from forming hydrates and freezing up in the winter, a lot of ethanol needs to be used. Obviously it's a manpower issue to keep small wells going when you've got the main wells that you're operating 20 miles to the south that you have to be out with tundra travel type vehicles. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 46 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 So as a result these wells are not produced and not considered viable commercially when they've got other production from Walakpa. We did consider a slate of these wells, putting together a stimulation package and seeing if we could economically mobilize a coil tubing unit and a acid spread to come over and attempt to stimulate them, but unfortunately we were not able to get bidders to come over and do that. So as a result these wells are slated for abandonment because they're not capable of being commercial. Now the East Barrow, once again that's a separate area over to the east and it was developed after South Barrow. The original pressure in East Barrow 15 was 962 PSI and the original report in East Barrow was 963 PSI. And what we're seeing currently in the reservoir that East Barrow 14 is producing out of, it's currently at 935 PSI and it has built back up over time due to lack of production. The original hypothesis by earlier engineers was that there was a strong water drive that was encroaching into the East Barrow fault block and that was why the pressures did not decline as you would normally expect a volumetric reservoir to decline over time or over production. We have since produced well in excess of what they thought the reservoir would produce if there were a strong active water drive coming in and watering out the wells. And we speculate R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 47 • 1 2 3 4 5 6 7 8, 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 or we have convinced ourselves that there's probably a hydrate layer in the upper part of the East Barrow reservoir that is disassociated as you reduce the reservoir pressure from producing the gas. And we have done modeling that shows that the hydrate stability zone is on the order of 2,000 feet in the East Barrow Field. So we feel like when we put these two horizontals into the East Barrow Field that we will not only have backup for the community of Barrow, but we'll also be producing and depressuring this hydrate zone that's -- that feel is at the upper end of the -- or on the top of the reservoir. So are there any questions? CHAIR SEAMOUNT: Commissioner Norman, do you have any questions? COMMISSIONER NORMAN: Just one. Could you comment on whether permeability of the receiving zone presents any challenge to use of the wells as injection wells? I think Mr. Van Dyke also made a brief comment about that. MR. STOKES: Yes, I've really not been involved in water disposal and fracing so I can't comment on that. COMMISSIONER NORMAN: Thank you. CHAIR SEAMOUNT: Commissioner Foerster? COMMISSIONER FOERSTER: No questions. CHAIR SEAMOLTNT: Are these fields under compression at all? R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 48 • 1 2 3 4 5 6 7 8, 9 10 11 12 13 14 15 16 17 18 19~, 20 21 22 23 24 25 MR. STOKES: Chair Seamount, the -- there are no compression. The fields are produced at just pipeline pressures and then the pipeline takes it to a central gathering facility in South Barrow and it's..... CHAIR SEAMOUNT: Okay. MR. STOKES: .....dehydrated and shipped to town in a pipeline quality pipeline. CHAIR SEAMOUNT: Do you ever foresee compression? MR. STOKES: I -- from what we understand the reserves in Walakpa to be, if we drill these four short, horizontal laterals we would not have compression needs for many years..... CHAIR SEAMOUNT: Okay. MR. STOKES: .....understanding the demand of the village of Barrow. CHAIR SEAMOTJNT: And did you mention reserve estimates, remaining reserves? MR. STOKES: We did a calculation for Walakpa and the remaining reserves there depending on the amount of usage is on the order of 150 to 200 BCF remaining. Now at East Barrow because of the hydrate recharge which was originally thought to be water influx, we have not made an estimate of what the reserves are. In the South Barrow northern fault block, we anticipate remaining reserves to be about 8 BCF. And NSB 2 fault block which is where South Barrow 13 is, the remaining R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 49 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 reserves there were less than one BCF. CHAIR SEAMOUNT: Okay. Is -- are there hydrates in all the fields? MR. STOKES: We feel like probably at Walakpa there is because that sand is very continuous to the north and would be going up dip into the hydrate stability zone. And that is another issue of why I give a range for Walakpa reserves because there appears to be potentially a big aquifer to the south from the Brontosaurs well which is 20 miles to the south and then there's the potential of a big hydrate cap to the north of dip. In South Barrow we feel that the northern fault block, we feel like it's been more of a volumetric decline and we -- the modeling that we did for hydrate stability did not show that the reservoir was in the hydrate stability zone, it was too warm. That was the other thing in Walakpa, we did extensive modeling there as well and did show that was a hydrate stability zone up dip of the producing wells. CHAIR SEAMOUNT: Okay. I haven't been paying attention to the methane hydrate science projects, but if you produce -- if you're getting a contribution from methane hydrates, wouldn't you -- I mean, wouldn't you produce a lot of water along with it? MR. STOKES: We have in our reservoir simulations it goes show obviously you've got something to -- you've got water when disassociate the hydrate clath rate and you've got methane gas. R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 50 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 But what is shown in our reservoir simulations is the water saturation does not become mobile to where it's like a water drive, you do get water, it remains in your reservoir. We would not anticipate seeing water in the wells and we have not experienced that in East Barrow where we feel like the most likely place we have hydrates. CHAIR SEAMOUNT: Fascinating. Commissioner Norman, any other questions? COMMISSIONER NORMAN: No questions. CHAIR SEAMOUNT: Commissioner Foerster? COMMISSIONER FOERSTER: No questions. CHAIR SEAMOUNT: Okay. Thank you, Mr. Stokes. I think we should probably take a 15 minute recess. COMMISSIONER NORMAN: Could I ask one follow-up of Mr. Van Dyke before we go on break? CHAIR SEAMOUNT: Go ahead. COMMISSIONER NORMAN: Mr. Van Dyke, part of the same question I asked Mr. Stokes and maybe I misunderstood, but I thought I heard you just briefly mention that permeability might present some challenge to the receiving zone being able to accept injection of liquids. Did I hear that right or not? MR. VAN DYKE: Commissioner Norman, I don't believe I made that statement, but the sands are, you know, relatively low permeability compared to again some of the shallow sands at Prudhoe Bay or, you know, the (indiscernible), but from the R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 51 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 injection operations that we have had in the past at Barrow, acid stimulation, fracture stimulation, the disposal operation in well SB 5, this Barrow sand certainly appears capable of taking fluids at, you know, reasonable pressures. COMMISSIONER NORMAN: Thank you. CHAIR SEAMOUNT: Okay. At this time I'd like to take a 15 minute break. And I'd like to be 10 minutes, but we're always -- we always go over so try to be honest and say 15 and we're probably lying about that. But that means 10:42 we'll come back. And we're off the record at 10:22. (Off record - 10:22 a.m.) (On record - 10:36 a.m.) CHAIR SEAMOUNT: We're back on record at 10:37, 10:38, whatever. Now we'll give opportunity for public comment, and Mr. Lash, I never know what you're up to, are you public or are you with these guys? MR. LASH: Both. I'm on my -- I happen to be on my R&R so but I -- when I'm not I'm with these guys. CHAIR SEAMOUNT: Okay. Do you have any comments? MR. LASH: No. CHAIR SEAMOUNT: Okay. Thank you. All right. Well, we'll leave the record open until -- for one week and that'll be May 25th, 2010. And we would like the answer on where the nearest water source is. And there's a structure map that was R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 52 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 mislabeled, which attachment was that? MS. McMULLEN: It was in the geologic report and it's..... MR. STOKES: Attachment 3 didn't have SB number 10. MS. McMULLEN: .....1F. CHAIR SEAMOUNT: Okay. Attachment 1F of which geologic report? MS. McMULLEN: It's -- that is attachment 1 in the back. CHAIR SEAMOUNT: Oh, okay. And that geologic report..... MS. McMULLEN: Contains the map as attachment 1F. CHAIR SEAMOUNT: And which field is that? MS. McMULLEN: That is the South Barrow Field. CHAIR SEAMOUNT: South Barrow Field. And in -- what was that..... MR. STOKES: I believe attachment 3 didn't have SB number 10, a well. CHAIR SEAMOUNT: Oh, it was missing a well..... MR. STOKES: Yeah. CHAIR SEAMOUNT: .....on attachment 3. MR. STOKES: I think that's just a surface map. CHAIR SEAMOUNT: Commissioner Norman? COMMISSIONER NORMAN: I have just one follow-up question, Ms. McMullen, if you know, but this isn't a -- but I did look back at my notes and I made a note and I believe it was when Mr. Van Dyke was testifying or perhaps you that number 15, poor well from beginning and I thought there was some reference to R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 53 • 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 permeability in well number 15. But this isn't central to our determination, I just..... MS. McMULLEN: No, my -- the information that I know about 15 is -- I don't know the historical production history on here other than the lower Barrow sand was water wet here and so the upper Barrow sand, which is of lower quality and more in the transition zone here. So as far as production goes, this was not one of the better wells, you know, more down dip on the flank. Does that answer your..... COMMISSIONER NORMAN: That answers. MS. McMULLEN: Okay. COMMISSIONER NORMAN: Thank you. CHAIR SEAMOUNT: Commissioner Foerster, questions, comments? COMMISSIONER FOERSTER: Nothing. CHAIR SEAMOUNT: Do I hear a motion to adjourn? COMMISSIONER FOERSTER: Moved. COMMISSIONER NORMAN: Second. CHAIR SEAMOUNT: All opposed. Hearing none I would like to thank Mr. Lowe, Mr. Walsh, Ms. McMullen, Mr. Stokes and Mr. Van Dyke for a very professional, complete presentation. This hearing is adjourned at 10:37. (Recessed - 10:37 a.m.) R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 54 • 1 C E R T I F I C A T E 2 UNITED STATES OF AMERICA ) )ss. 3 STATE OF ALASKA ) 4 I, Rebecca Nelms, Notary Public in and for the State of Alaska, residing at Anchorage, Alaska, and Reporter for R & R 5 Court Reporters, Inc., do hereby certify: 6 THAT the annexed and foregoing PUBLIC HEARING In the Matter of the North Slope Borough's request for Disposal 7 Injection Orders for South Barrow No. 13 and East Barrow No. 15, was taken by Lynn Hall on the 18th day of May, 2010, 8 commencing at the hour of 9:00 a.m., at the Alaska Oil and Gas Conservation Commission, 333 West Seventh Avenue, Anchorage, 9 Alaska; 10 THAT this Hearing Transcript, as heretofore annexed, is a true and correct transcription of the proceedings taken and 11 transcribed by Lynn Hall; 12 IN WITNESS WHEREOF, I have hereunto set my hand and affixed my seal this 26th day of May, 2010. 13 Notary Public in and or Alaska 15 My Commission Expires: 10/10/10 16 17 18 19 20 21 22 23 24 25 R& R C O U R T R E P O R T E R S 811 G STREET (907)277-0572/Fax 274-8982 ANCHORAGE, ALASKA 99501 • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Disposal Injection Orders South Barrow #13 and East Barrow 15 May 18, 2010 at 9:00 am NAME AFFILIATION PHONE # TESTIFY (Yes or No) ~v4 I~5 (sLl ~YZ/a- 2~~z-232 7 JQ c r~ ~~ ~ ~~ h/S.13 ~-9~J7 8~~ ~ So ~/~ I f .~3 • FedEx Express U.S. Mail: PO Box 727 Customer Support Trace Memphis, TN 38194-4643 ~, _ c~ 3875 Airways Boulevard (.~ Module H, 4th Floor Telephone: 901-369-3600 Memphis, TN 38116 May 13,2010 Dear Customer: The following is the proof-of-delivery for tracking number,rl24~51974. 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Fed&Aca No. C:adn Cab No. Dem kages Total Weight Tonal Declared Valuer Total Pa c l S ~ ~ tour liability is limeedm3100 unless you der.Iareahigher~.alue.See beck for details. ay using Ibis Airhdl you agreemdre fed Ex Use Unly service condNOns on Ne back of this Airbill and in me curtain Fegfx Service Guide, including [enns ma[ lima our!iatileY 8 Nf'N Residential Delivery Signature Options ityouregmraaaignamm,crackoiremarlndira NoSlgnature DirectSlgnature r- IndvectSltganature Required I I A yp t e-pieiRS I .rn a meat 51, 9 ackage may be len wM ddr y gn `cr delivery. J 'e p t dd ass, anyone ou[obm trig asgnamre '-} cm :ghb -9address may n fnr dalrveiv:~~ .; totem's ~ ~ ~ ~ ~ `7 ~~V Br' ~ ! O / tress ennot deliver to P.O. boxes or P 0. ZIP codes. pep4Aoor/Suhe/floom ~2 ~~ STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE A O_03014030 M SEE BOTTOM FOR INVOICE ADDRESS F R A~GCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. March 26, 2010 ° M Anchorage, AK 99501 907-793-1238 PHONE - PCN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News PO Box 149001 Anchora e AK 99514 g ~ March 29, 2010 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal® ^ Display Classif ied ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchora e AK 99501 PAGE t OF 2PAGES TOTAL OF ALLPAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN s ARn 02910 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID ~ t0 02140100 73451 2 REQUISITIONE~Y: I ~\\ 1n ^ DIVISION APPROVAL: 02-902 (Rev. 3/94) ~, v W y Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM ~ ~ Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservation Commission Re: Docket No. DIO 10-01 and DIO-10-02. Request for Disposal Injection Orders for South Barrow 13 and East Barrow 15 located North Slope, Alaska The North Slope Borough (NSB), by letters dated February 24, 2010 and received March 1, 2010 has applied for disposal injection orders in accordance with 20 AAC 25.252. Orders would authorize disposal of Class II drilling and production wastes into depleted portions of the developed gas reservoirs using existing wells South Barrow 13 and East Barrow 15. South Barrow 13 is located within Section 14, T22N, R18W, UM and East Barrow 15 is located within Section 23, T22N, R17W, UM. The receiving zone for South Barrow 13 well is proposed at an approximate depth range of 2184 to 2347 feet true vertical depth and the receiving zone for East Barrow 15 at an approximate depth range of 2054 to 2151 feet true vertical depth. The Commission has tentatively scheduled a public hearing on this application for May 18, 2010 at 9:00 a.m. at the Alaska Oil and Gas Conservation Commission, at 333 West 7`~' Avenue, Suite 100, Anchorage, Alaska 99501. To request that the tentatively scheduled hearing be held, a written request must be filed with the Commission no later than 4:30 p.m. on April 19, 2010. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the hearing, call 793-1221 after Apri127, 2010. In addition, written comments regarding this application may be submitted to the Alaska Oil and Gas Conservation Commission, at 333 West 7`h Avenue, Suite 100, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on May 3, 2010, except that, if a hearing is held, comments must be received no later than the conclusion of the May 18, 2010 hearing. If, because of a disability, special accommodations may be needed to comment or attend the hearing, contact the Commission's Special Assistant, Jody Colombie, at 793-1221, no later than May 13, 2010. Daniel T. Seamount, Jr. Commissioner/Chair • ;na!~ln ~~ Anchorage Daily News MAR ~ 1 201t~ Affidavit of Publication ~_+,,.~~++..~~.,~ 1001 Northway Drive, Anchorage, AK 99508 ~~67WMAw• PRI E OTHER D # DATE PO ACCOUNT PER DAY CHARGES 752667 03/29/2010 AO-03014 STOF0330 $202.52 $202.52 $0.00 STATE OF ALASKA THIRD JUDICIAL DISTRICT Shane Drew, being first duly sworn on oath deposes and says that he is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and dunng all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed n~ Subscribed and s~n~orn to me before this date: MAR 3 0 2010 Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: ~ ~Y~_~~ _ --_ • ~F AL.P` . 11,E s'~f ~~~~11~1) j )1>>>l`1 OTHER OTHER GRAND CHARGES #2 CHARGES #3 TOTAL $0.00 $0.00 $202.52 Notice of Public Hearing StateofAlaaka Aiaeka 4ttand G~ Conseivation Commte®fop Re: Docket No: DI010-01 anllDlO-10-p2. Request for Disposal Injection Orders for souttf 9arrow 13 and East Barrow 1S located NOrtll:Sk>pe, AI~i(a The North Slope Borough (NSB), by letters dated February 24, 2010 and received March 1, 2010 has.. applied for disposal iryection orders in accordance di5posa0l o Class ~li driBing darefd produ~on vnastes into depleted porttons of the developed gas reservoirs using existing welts South Barrow 13 and East Barrow 15. South Barrow 13 is located within Section 14, 722N,. R18W, UM and EasfiBarrow 15 is located within Section 23, t22N, R17W, UM. The reCeMhg zone for South Barrow 13 welt is proposed at an approximate depth range of 2184 to 2347 feet true verfical depth .and the receivingg zone for EasfBarrow 15 at an approximate depth range of 2054th 2151 feet true ve[tlcal depth. The Commission has tentatively scheduled a public hearing on thisapplicatipn for May 18,.2010 at9t00 a.m. at the Alaska Oil and Gas Conservation. Commission,. at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 49501. To request that the tentatively scheduled hearingg~be held, a written request must be filed with the Commission ho later than 4:30 p.m. on April 19, 2010: If a request for a hearing is not timely filed, the Commission may consider the issuance of art order without a hearing. Toiearnif the C mmissionwill hold the hearing, Ca11793-1221 after Aril 27, 2010. Inadditioh; written comments re arding this application may be submitted to the Alaska Oil and Gas Conservation Commission, at 333 west 7th Avenue, Suite 100, Anchorage, Alaska 99501: Comments must be received no later than 4:30 p.m. ^' on May 3, .2010, exceptthat, if a hearing is held, commentsmust be received no later-than the conclusion of the May 18, 2ti10 hearing: ; If, because of adisability, special accommodations may be needed to comment orat#end the hearing' contact the Commission's Special Assistant, Jody Colombie at 793-1221, no later than May 13, 2010: Daniel T. Se1rh0Unt, Jr. Chair AO-03014030 Published: March 29, 2010 • STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ O-03014030 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ~'1 ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC D Division of Personnel R 333 West 7th Avenue. Suite 100 ° Anch~rage_ AK 99S()1 M 907-793-1238 o Anchorage Daily News PO Box 149001 Anchorage, AK 99514 AGENCY CONTACT I DATE OF A.O. PHONE IPCN 1 7 V/ 1 / 7 _) ~ 1 GG 1 - DATES ADVERTISEMENT REQUIRED: March 29, 2010 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account # STOF0330 United states of America State of AFFIDAVIT OF PUBLICATION REMINDER ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2010, and thereafter for consecutive days, the last publication appearing on the day of , 2010, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2010, Notary public for state of My commission expires _ r STATE OF ALASKA r• ~ NOTICE TO PUBLISHER ~ ADVERTISING ORDER NO. ADVERTISING ORDER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE A O_03014031 /'1 SEE BOTTOM FOR INVOICE ADDRESS F R A~CTCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. March 26, 2010 ° M Anchorage, AK 99501 907-793-1221 PHONE - PcN DATES ADVERTISEMENT REQUIRED: o The Arctic Sounder April 1, 2010 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement Legal® ^ Display Classif ied ^Other (Specify) SEE ATTACHED SEND INVOICE IN TRIPLICATE TO AOGCC, 333 W. 7th Ave., Suite 100 Anchora e AK 99501 PAGE 1 OF 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN s AR1~ 0291 0 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID ~ 10 02140]00 73451 2 REQUISITIONED BY: DIVISION APPROVAL: 02-902 (Rev. 3/94} (1 v Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM r Notice of Public Hearing • State of Alaska Alaska Oil and Gas Conservation Commission Re: Docket No. DIO 10-01 and DIO-10-02, Request for Disposal Injection Orders for South Barrow 13 and East Barrow 15 located North Slope, Alaska The North Slope Borough (NSB), by letters dated February 24, 2010 and received March 1, 2010 has applied for disposal injection orders in accordance with 20 AAC 25.252. Orders would authorize disposal of Class II drilling and production wastes into depleted portions of the developed gas reservoirs using existing wells South Barrow 13 and East Barrow 15. South Barrow 13 is located within Section 14, T22N, R18W, UM and East Barrow 15 is located within Section 23, T22N, R17W, UM. The receiving zone for South Barrow 13 well is proposed at an approximate depth range of 2184 to 2347 feet true vertical depth and the receiving zone for East Barrow 15 at an approximate depth range of 2054 to 2151 feet true vertical depth. The Commission has tentatively scheduled a public hearing on this application for May 18, 2010 at 9:00 a.m. at the Alaska Oil and Gas Conservation Commission, at 333 West 7`~' Avenue, Suite 100, Anchorage, Alaska 99501. To request that the tentatively scheduled hearing be held, a written request must be filed with the Commission no later than 4:30 p.m. on April 19, 2010. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the hearing, call 793-1221 after April 27, 2010. In addition, written comments regarding this application may be submitted to the Alaska Oil and Gas Conservation Commission, at 333 West 7`'' Avenue, Suite 100, Anchorage, Alaska 99501. Comments must be received no later than 4:30 p.m. on May 3, 2010, except that, if a hearing is held, comments must be received no later than the conclusion of the May 18, 2010 hearing. If, because of a disability, special accommodations may be needed to comment or attend the hearing, contact the Commission's Special Assistant, Jody Colombie, at 793-1221, no later than May 13, 2010. Daniel T. Seamount, Jr. Commissioner/Chair l~ Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservatio Commission n Re: Docket No. DIO 10-01 and DIO-10-02 . Request for Disposal1njection Orders for ~ S ~~ outh Barrow 13 and East Barrow 15 local- ~,•' ed North Slope Alaska , The North Slope Borough (NSB), by letters dated February 24 2010 , and received March 1, 2010 has applied for disposal ~~ injection orders in accordance with 20 AAC 25.252.Orders would auth i .~ i-~ or ze disposal of Class II drilling and production ~ wastes into depleted portions of the developed gas res- / ervoirs using existing wells South Barrow 13 and East Barrow 15. South Barrow 13 is located within Section 14, T22N, R18W, UM and East Barrow 15 is located within Section 23 T2 , 2N, R17W, UM. The receiving zone for South Barrow 13 ~ z n ~ Q well is proposed at an approximate depth range of 2184 to v y 2347 feet true vertical depth and the receiving zone for East ~ Y ~ y ' b Barrow 15 at an approximate depth range of r y ~C 2054 to 2151 feet true vertical depth. ~ z The Commission has tentatively scheduled ~ n a public hearing on this application for May 18, 2010 at 9:00 a.m. at the Ala k ~ n ~ ~"~ s a Oil and Gas Conservation Commission, at 333 West 7th Avenue Suite 100 a ~ ~ y Z , , nchorage, 4laska 99501. To request that th t ~ ~ e esta- ively scheduled hearing be held a written ~ ~ +'Q , equest must be tiled with the Commission ~ d io later than 4:30 p. m. on April 19, 20.10. y ~ a rggyesl for a hearing ig rat tim~y flied, ~ ~~, the Commission may consider the issuance n ~ ~f an order without a hearing. To learn if the Z y ' Commission will hold the hearing, call 793- , ~ 1221 after ApriF27, 2010. a In addition, written comments regarding this plication ma be submitted to the Alaska a b y .- p Oil and Gas Conservation Commission, at -~ -xj 333 West 7th Avenue, Suite 100, ,r ' Anchorage, Alaska 99501. Comments ~ ' must be received no later than 4:30 p.m. on ~ . iy. . May 3, 2010, except that, if a hearing is i l h ld e t t b d t W , comm n s. mus e rece ve no er e a than the conclusion of the May 18, 2010. ~ hearing. If, because of a disability, special accom- modations may be needed to comment or attend the hearing, contact the Commission's Special Assistant, Jody Colombie, at 793-1221, no later than May 13, 2010. Daniel T. Seamount, Jr., Commissioner! ;,hair Published 04/01/i0 X82939 04/0 ~~ ~Hy a ''d ~~ ~~ ~ t7 N ~ O d O 0 °z r C~ zed O~ ~a~ Z y 'id °zy ~bl7i o~~ `~ id O ~ ~ ~ %~oa y ~~o o r ~+ ~ ~ O d d Ir/ ~a°z C`~~ ~ ~ f~ m~~ r-r ~ C ~~~ C('~~ t~ ~~~ o~ ~ .~ zay~ro~ m~~~~o ~yh,~dy~m t7yy~d~ ~ ~ ~ ~ ~ ~ ao~~~~ ~~°~~~ ~a~~~~ nCn~~ro~ b ~ ,b -~ ~ ~ -C ~ ~~r~xz ~~„ ~'nOd H ~ to " ~yd~m~ ry~ozz ~yyz~oyy ~ax~~`~ ZdO~y~d a ~, d~ b ~ ~~ Gd ~ r_ z n H y °z~ ~~°z Or9i,° zoo Ord[ Y ~ ~ bd ~~~n z d d ~-+ C/1 0 r~ ~_ (7 x y O z (7 d y 0 x -~ v~ a `~ °z r z C~i d a a 0 C~ H x d d C O z !~ I C y O ~~.. l 1 ~ W ~ 0 Q ~~ a ~ ~ ~ ~ ~ ' lea O ~ O ~ ~ ~ ~ x~~ o ~ ~~~ ee c ~ Z ° ~ ~ ono ~ r.r O ~ ~• n V ~ D nr N ~~~ Z mD m - o _~. _ * r n y~yd ?^7C70 ~Ot~'ri~ ~ cfl~~ ~ ~~~ ~~~~ N~~ ~~ o rn ~ yoo~ ('1~~N No rn ~~ E ~ p°oo~ Cowo'''~ NN ~ Z w • / ~ s ~~ . ~; ~~~ ~~ c ~~ • STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ 0_03014031 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF I'1 ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC R 333 West 7th Avenue. Suite 100 ° Anch~ra~e. AK 99501 M 907-793-1238 o I The Arctic Sounder AGENCY CONTACT DATE OF A.O. PHONE PCN DATES ADVERTISEMENT REQUIRED: April 1, 2010 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America State of __ AFFIDAVIT OF PUBLICATION REMINDER ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. division. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. Before me, the undersigned, a notary public this day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2009, and thereafter for consecutive days, the last publication appearing on the day of , 2009, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2009, Notary public for state of My commission expires _ • i Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Friday, March 26, 2010 3:00 PM To: Ballantine, Tab A (LAW); 'Aaron Gluzman'; Bettis, Patricia K (DNR); caunderwood@marathonoil.com; 'Dale Hoffman'; Frederic Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; Ostrovsky, Larry Z (DNR); P Bates; Randy Hicks; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; Talib Syed; 'Tiffany Stebbins'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR); (foms2@mtaonline.net); (michael.j.nelson@conocophillips.com); (Von.L.Hutchins@conocophillips.com); Alan Dennis; alaska@petrocalc.com; Anna Raff; Barbara F Fullmer; bbritch; Becky Bohrer; Bill Walker; Bowen Roberts; Brad McKim; Brady, Jerry L; Brandon Gagnon; Brandow, Cande (ASRC Energy Services); Brian Gillespie; Brian Havelock; Bruce Webb; carol smyth; Charles O'Donnell; Chris Gay; Cliff Posey; Crandall, Krissell; Dan Bross; daps; Daryl J. Kleppin; David Boelens; David House; David Steingreaber; 'ddonkel@cfl.rr.com'; Deborah J. Jones; doug_schultze; Elowe, Kristin; Evan Harness; eyancy; Francis S. Sommer; Fred Steece; Garland Robinson; Gary Laughlin; Gary Rogers; Gary Schultz; ghammons; Gordon Pospisil; Gorney, David L.; Gregg Nady; gspfoff; Harry Engel; Jdarlington Qarlington@gmail.com); Jeff Jones; Jeffery B. Jones Qeff.jones@alaska.gov); Jerry McCutcheon; Jim White; Jim Winegarner; Joe Nicks; John Garing; John S. Haworth; John Spain; John Tower; John W Katz; Jon Goltz; Joseph Darrigo; Julie Houle; Kari Moriarty; Kaynell Zeman; Keith Wiles; Larry Ostrovsky; Laura Silliphant; Marilyn Crockett; Mark Dalton; Mark Hanley (mark.hanley@anadarko.com); Mark Kovac; Mark P. Worcester; Marquerite kremer; 'Michael Dammeyer'; Michael Jacobs; Mike Bill; Mike Mason; Mikel Schultz; Mindy Lewis; MJ Loveland; mjnelson; mkm7200; nelson; Nick W. Glover; NSK Problem Well Supv; Patty Alfaro; Paul Decker (paul.decker@alaska.gov); PORHOLA, STAN T; Rader, Matthew W (DNR); Raj Nanvaan; Randall Kanady; Randy L. Skillern; Rob McWhorter; rob.g.dragnich@exxonmobil.com; Robert A. Province (raprovince@marathonoil.com); Robert Campbell; Roberts, Susan M.; Rudy Brueggeman; Scott Cranswick; Scott, David (LAA); Shannon Donnelly; Sharmaine Copeland; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); Sondra Stewman; Steve Lambert; Steve Moothart; Steven R. Rossberg; Suzanne Gibson; tablerk; Tamera Sheffield; Taylor, Cammy O (DNR); Ted Rockwell; Temple Davidson; Teresa Imm; Terrie Hubble; Thor Cutler; Tina Grovier; Todd Durkee; Tony Hopfinger; trmjr1; Walter Featherly; Williamson, Mary J (DNR); Winslow, Paul M; Aubert, Winton G (DOA); Brooks, Phoebe; Crisp, John H (DOA); Darlene Ramirez; Davies, Stephen F (DOA); Fisher, Samantha J (DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA); Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, Bren (DOA); McMains, Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L (DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve, Charles M (DOA); Schwartz, Guy L (DOA); Seamount, Dan T (DOA) Subject: Public Hearing South Barrow #13 and #15 Attachments: Public Notice South Barrow 13 and 15.pdf .Ioczy J. Colomhie Special Assistant .Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907)793-1221 (phone) (907)276-7542 (fax) Mary Jones David McCaleb George Vaught, Jr. XTO Energy, Inc. IHS Energy Group PO Box 13557 Cartography GEPS Denver, CO 80201-3557 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates Halliburton 408 18th Street President 6900 Arctic Blvd. Golden, CO 80401-2433 PO Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Schlumberger Ciri Baker Oil Tools Drilling and Measurements Land Department 4730 Business Park Blvd., #44 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99503 Anchorage, AK 99503 Anchorage, AK 99503 Ivan Gillian Jill Schneider Gordon Severson 9649 Musket Bell Cr.#5 US Geological Survey 3201 Westmar Cr. Anchorage, AK 99507 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99508 Jack Hakkila Darwin Waldsmith James Gibbs PO Box 190083 PO Box 39309 PO Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Cliff Burglin Refuge Manager 399 West Riverview Avenue 319 Charles Street PO Box 2139 Soldotna, AK 99669-7714 Fairbanks, AK 99701 Soldotna, AK 99669-2139 Richard Wagner Bernie Karl North Slope Borough PO Box 60868 K&K Recycling Inc. PO Box 69 Fairbanks, AK 99706 PO Box 58055 Barrow, AK 99723 Fairbanks, AK 99711 ~~2- ~~ NORTH SLOPE BOROUGH Department of Public Works P.O. Box 350 Barrow, Alaska 99723 Phone: 907-852-0489 Fax 907-852-0251 Marvin L. Olson, Director February 24, 2010 Mr. Daniel T. Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 RE: North Slope Borough Barrow Gas Fields Application for Disposal Injection Order, and Application for Approval of Two UIC Class II Disposal Wells Dear Chairman Seamount: ~~~EIV~D Ale~k~ ~~ ~ 6~s Cor-~. G~mmission ~~~~~~~ In accordance with the Commission's regulations, enclosed are the North Slope Borough's {NSB) applications for a disposal injection order and two UIC Class II disposal wells located in the Barrow Gas Fields. The NSB is the open of the wells and the Barrow Gas Fields. Wells South Barrow (SB) 13 (Permit #100-037) and East Barrow (EB) 15 (Permit 100-045) are existing depleted gas wells we plan to convert to disposal wells while our 2010/2011 in-fill drilling program is underway. Upon completion of the drilling program, the two disposal wells will be plugged and abandoned. Note that the EB 15 well is referred to as the SB 15 well in some files. The Barrow gas fields are addressed in Conservation Order #233. The wells will be operated similar to disposal well South Barrow #5 which was approved by the AOGCC as a dispo well in 1987. See DIO #5. Well SB #5 was used successfully by the NSB as a temporary disposal well during on the past Barrow drilling campaigns, then plugged and abandoned. We will not begin to inject into the wells until the applications and other required authorizations are approved by the Commission. Either or both of the wells will be used as injection wells. We have not finalized our plans and at this time we do no know if only one of the wells is required or if both wells will be operated over the course of our drilling campaign. SB well is located in the South field and the EB well is located in the East f eld. The Barrow Gas Fields do not require an AOGCC or EPA Aquifer Exemption. In-situ water salinities are far above the EPAlAOGCC lower-level trigger levels. Data are provided with this submittal showing the high salinities of the tested water samples. In fact, all observed water salinities anywhere below the base of the permafrost appear to exceed the EPA/AOGCC lower-level trigger levels in the East and South field areas. These disposal wells will be used for a time period of less than 12 months and the total volume of injected fluids will be small in relative terms compared to most other disposal wells on the North Slope. The intended purpose of the disposal wells is to safely and efficiently dispose of liquid wastes generated from the drilling and P&A programs. Only fluids authorized to be injected into Class II disposal wells will be injected. Petrotechnical Resources Alaska (PRA) has been retained by the NSB to provide technical and management services for this project. PRA prepared these applications. Any technical questions related to this application should be addressed directly to PRA at the attention of Mr. Bill Van Dyke. If you have any general questions related to this application please contact me immediately. We are making plans to barge the rig and heavy equipment to Barrow this coming summer and spud our first new gas development well as early as September 2010. The enclosed applications follow the framework set out in the AOGCC regulations. We understand that we need both a Disposal Injection Order for injection of waste into the Barrow gas sands as well as approval for the Class II wells. Sundry Notices to convert the two existing wells to Class II injection wells will be filed in the near future. Sincerely, ~~ ~ v~ Marvin L. Olson, Director NSB Public Works Enclosures CC: William Van Dyke, PRA North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields CONTENTS SECTION 1. Letter of Application (20 AAC 25.252 (a)) 2. Burden of Proof (20 AAC 25.252(b)) 3. Location/Plat Maps (20 AAC 25.252 (c )(1)) 4. Operator and Surface Owners (20 AAC 25.252(c) (2)) 5. Affidavit of Notice to Surface Owners and Operators (20 AAC 25.252(c )(3)) 6. Geological/Reservoir Information Concerning Injection Zone (20 AAC 25.252(c )(4)) 7. Well Logs for South Barrow 13 and East Barrow 15 Wells (20 AAC 25.252(c )(5)) 8. Well Casing Information and Mechanical Integrity (20 AAC 25.252(c )(6)) 9. Injection Fluids (20 AAC 25.252(c )(7)) 10. Average/Maximum Injection Pressures (20 AAC 25.252(c )(8)) 11. Fracture Information (20 AAC 25.252(c )(9)) 12. Formation Water Quality Information (20 AAC 25.252(c )(10)) 13. Aquifer Exemption (20 AAC 25.252(c )(11)) 14. Mechanical Integrity of Other Wells Within 1/ mile Radius (20 AAC 25.252(c )(12) and (h)) 3 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields 15. Mechanical Integrity Demonstration and Testing (20 AAC 25.252(c )((d) through (g))) 16. Mechanical Integrity of Other Wells Within 1/ mile Radius (20 AAC 25.252 (h)) 17. Well Design, Construction and Testing (20 AAC 25.412(a) through (e)) 18. Notices (20 AAC 25.420 and .432) LIST OF ATTACHMENTS 1. Geologic Report 2. Plat of Well Locations 3. & 3A. Plat of Nearby Wells 4. Affidavit of Notifications 5. & SA. Annotated Well Logs 6. & 6A. Well Construction Details 7 & 7A. Wellhead Details 8. & 8A. Tubing and Casing Details 9. Water Analyses 10. FIT for Well EB 15 11. & 11A. Well Production Histories 4 • North Slope Borough • Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields Discussion of Approval Criteria 1. Letter of Apulication (20 AAC 25.252 (a)) The NSB is making application for two UIC Class II disposal wells. See enclosed cover letter. The wells, SB 13 and EB 15, are existing wells and have approved permits to drill (100-037 and 100-045, respectively). Note that the EB 15 well is also referred to as the SB 15 well in some files. The SB 13 and EB 15 wells are depleted gas wells in the South and East Barrow gas fields respectively, and we plan to convert them to temporary disposal wells, which will then be plugged and abandoned once our drilling program is completed in mid 2011. The wells will be used to dispose of produced fluids, spent drilling mud, cement contaminated drilling mud, reserve pit fluids, pipe scale, production waste, rig and camp wash fluids, storm water, plug and abandonment fluids, excess cementing fluids, completion fluids, formation fluids associated with the act of drilling a well, excess and makeup water necessary to facilitate injection, new product cleanup fluids, mud and brine pit rinsate, diesel, arctic pack, pipe scale and pipe dope, treated domestic waste water, miscellaneous work over fluids originating from any wells we plan to plug and abandon in the Barrow Gas Fields and the Walakpa Gas Field and other substances the Commission determines on application are wastes associated with the act of drilling a well permitted under 20 AAC 25.005. It is possible that slurried/ground drill cuttings will be injected into the wells. At this time we do not plan to install a grind and inject facility; instead we plan to dispose of our dried drill cuttings in the local landfill. Should the landfill option not be available, we want the option to utilize a G&I facility. We will also consider backhauling the cuttings to Deadhorse. In all cases, spent liquid drill mud will be injected into the wells. The proposed injection interval is the Barrow gas sand. The top of the interval is located at a true vertical depth subsea of -2250 feet in the South Field SB 13 well and -2060 feet in the East Field EB 15 well. This interval is a combination of water-wet sands and depleted gas sands. A detailed description of the disposal interval and confining layers is included in this application in the Geologic Report-- Attachment 1. The SB 13 well was drilled in 1976 to a total vertical depth of 2534 feet (measured depth of 2475 feet). The well is very slightly deviated. The perforated interval in the well is between 2224 to • North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields 2387 feet MD. The well is located on oil and gas estate owned by the NSB. The surface estate is owned by UIC. The EB 15 well was drilled in 1980 to a total vertical depth of 2278 feet (measured depth of 2278 feet also). The perforated interval in the well is 2054 to 2151 feet MD. The well is located on oil and gas estate owned by the NSB. The surface estate is owned by UIC. Either or both of the wells will be used as disposal wells. We have not finalized our plans and at this time we do not know if only one of the wells is required or if both wells will be operated over the course of our drilling campaign. Both wells are depleted gas wells and are no longer used to produce gas. Converting both wells to disposal wells and then plugging and abandoning the wells will not result in waste. 2. Burden of Proof (20 AAC 25.252(b)) The NSB believes that the information and data contained in this application meet the burden of proof to show that the well designs and construction and their proposed operation protect the public interest and demonstrate that the oil field waste will be isolated and not move into sources of freshwater. No sources of subsurface fresh water are present in the area. Conversion of the wells to disposal wells will not create waste. There are no other commercial hydrocarbon bearing zones above or below the proposed disposal interval. 3. Location/Plat Maps (20 AAC 25.252 (c )(1)) Well SB 13 is the only well drilled from the existing SB 13 drill site in the South Barrow Gas Field. Well EB 15 is the only well drilled from the existing EB 15 drill site in the East Barrow Gas Field. See Attachment 2 for a plat of the locations. The surface location for well SB 13 is 807 feet FWL, and 552 feet FSL, Sec. 14, T22N, R 18W, UM. The bottom hole location is approximately 24 feet south and 366 feet west of the surface location. 6 • North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields The surface location of well EB 15 is 2640 feet FEL, and 990 feet FNL, Sec. 23, T22N, R 17W, UM. The bottom hole location is the same as the surface location. Attachments 3 and 3A show the location of wells nearby the SB 13 and EB 15 wells. All the nearby wells are operated by the NSB. No other active, shut in or P&A'd wells are located within '/ mile of the SB 13 and EB 15 wells. The SB 13 and EB 15 wells are about 6 miles apart. 4. Operator and Surface Owners (20 AAC 25.252(c) (2)) Both the surface and subsurface ownership for all owners within one-quarter mile of both the surface and bottom hole location of each well is shown below: O erp ator: The North Slope Borough (NSB) P O Box 69 Barrow, Alaska 99723 Attn: Land Department Surface Owners: Ukpeagvik Inupiat Corporation (UIC) P O Box 890 Barrow, Alaska 99723 Attn: Land Department 7 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields Oil and Gas Operator, Mineral Rights Owner and Roomy Owner: The North Slope Borough (see above) 5. Affidavit of Notice to Surface Owners and Operators (20 AAC 25.252(c )(3)) A signed affidavit affirming written notice and a copy of this application have been provided to the Owners and Operators is enclosed as Attachment 4. 6. Geolo~icaUReservoir Information Concerning Infection Zone (20 AAC 25.252(c )(4)) A geologic report describing the proposed injection interval and confining layers is enclosed as Attachment 1. The SB 13 well is located in the South Field structurally down dip in an isolated fault block along with the NSB 02 well. The NSB 02 well is planned for P&A. The EB 15 well is structurally the most down dip well in the East Field. The SB 13 well last produced gas in 2006. The EB 15 well last produced gas in 1993. Both wells are very marginal producers at best and both are planned for P&A after disposal operations are complete in 2011. The SB 13 well was drilled to argillite basement at 2472 feet MD in 1976. The EB 15 well was drilled in 1980 and did not quite reach basement. The base of the permafrost in the two fields is calculated at a minimum to be at -1000 feet subsea and possibly as deep as -1300 feet subsea based on temperature surveys run in wells in the fields. In the South field area, a thin finger of sand correlatable to the Walakpa sandstone immediately overlies the Barrow sandstone. For purposes of this report, in the South Field area the Walakpa sandstone equivalent is included with and treated as part of the Barrow sandstone. Both sandstone intervals are perforated and open to injection in the SB 13 well. Early geologic reports did not recognize the Walakpa sandstone as a separate, distinct interval in the South field area. 8 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields In the East field area the Walakpa sandstone is separated from the Barrow sandstone and in this report is not considered part of the Barrow sandstone. The Walakpa sandstone is not open or perforated in the EB 15 well. 7. Well Logs for Wells South Barrow 13 and East Barrow 15 (20 AAC 25.252(c )(5)) Well logs for the SB 13 and EB 15 wells previously have been submitted to the Commission and are available in-house. Enclosed, as Attachments 5 and SA, are a portion of the well logs showing the disposal interval, the perforated interval, and the upper and lower confining intervals for both proposed disposal wells. 8. Well Casing Information and Mechanical Integrity (20 AAC 25.252(c)(6)) Attachments 6 and 6A show the well construction schematic for each well. The wells are cased and cemented in accordance with Commission regulations. The wells do not have packers in place so an exception is requested to the tubing and casing mechanical testing requirement. Schematic of the well heads are also enclosed as Attachments 7 and 7A. Specifications for the tubing and casing for each well are enclosed as Attachments 8 and 8A. All casing strings in Well SB 13 were cemented to the surface in 1976. The intermediate casing string in Well EB 15 was cemented to the surface and the long casing string was cemented from 1300 feet to 2198 feet MD in 1980. The upper portion (above 1180 feet MD) of the long sting casing annulus is filled with Arctic Pack. Well SB 13 was successfully fracture stimulated in the Barrow Sand in 1987. No mechanical problems were encountered with the wellhead or casing during the fracture operation. As previously noted, Well SB 5 was used successfully as a disposal well in 1987 in the Barrow Sand with no subsurface problems encountered. This well has a design and construction very similar to the SB 13 and EB 15 wells. See DIO #5. Well SB 20 was acid stimulated in the Barrow Sand in 1980 with no mechanical problems encountered. 9 • North Slope Borough • Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields The Commission is authorized to grant the waivers requested above. See 25 AAC 25.450 and 20 AAC 25.252(g). 9. Infection Fluids (20 AAC 25.252(c 1(7 Injected wastes will come directly or indirectly from operations in the Barrow and Walakpa gas fields and production-related activities. The wastes will be generated from gas-related E & P operations conducted by the NSB and its contractors. Typical sources of waste will be produced fluids, spent drilling mud (and possibly ground and slurried drill cuttings), cement contaminated drilling mud, reserve pit fluids, pipe scale, production waste, rig and camp wash fluids, storm water, plug and abandonment fluids, excess cementing fluids, completion fluids, formation fluids associated with the act of drilling a well, excess and makeup water necessary to facilitate injection, new product cleanup fluids, mud and brine pit rinsate, diesel, arctic pack, pipe scale and pipe dope, treated domestic waste water, miscellaneous work over fluids originating from any wells we plan to plug and abandon in the Barrow Gas Fields and the Walakpa Gas Field and other substances the Commission determines on application are wastes associated with the act of drilling a well permitted under ZO AAC 25.005. In addition to the typical sources of waste noted above, the NSB anticipates it will inject other waste determined by the EPA to be RCRA E & P Exempt Wastes per 53 CFR 25446 July 6, 1988 and Crude Oil and Natural Gas Exploration and Production Wastes: Exemption from RCRA Subtitle C Regulation, May 1995, EPA 530-K-95-003. Operational Assumptions: Planned Injection Rates: 2-7 BPM Daily Average Volume: 1000 bbls per day while drilling Daily Maximum: 10,080 bbls per day (if injection is continuous at 7 BPM which is not planned) Maximum Volume of Waste to be Injected assuming drill cuttings are not ground and slurried and injected----------30,000 bbl from a total of 6 new wells and 8 P&A operations Maximum Volume of Waste to be Injected assuming drill cuttings are ground and slurried and injected----------50,000 bbl from a total of 6 new wells and 8 P&A operations 10 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields 10. Avera~e/Maximum Infection Pressures (20 AAC 25.252(c )(8 Expected average injection pressure is estimated to range between 400 to 800 psi at the surface. The maximum injection pressure will be limited by the working pressure of the injection pump, which will be equipped with a pressure safety relief valve set at a pressure below the maximum working pressure. It is anticipated that we may at times have to inject at pressures higher than the natural fracture pressure of the receiving interval if the receiving formation temporarily bridges or plugs off. These will be short term events. Maximum wellhead injection pressures experienced when Well SB 13 was fracture stimulated did not exceed 1300 psi. Maximum wellhead injection pressures experienced when Well SB 5 was used as a disposal well did not exceed 700 psi. 11. Fracture Information (20 AAC 25.252(c )(9)) We have not prepared a separate fracture simulation report/analysis. Based on previous fracture stimulation treatments in Barrow gas field wells and the successful operation of disposal well SB #5, the NSB believes that based on its proposed operations plan that migration of fluids and injected wastes beyond the intended injection interval (the Barrow gas sands) has not occurred and will not occur. The NSB believes that no fresh water aquifers are at risk of being affected by the proposed injection activity. The area has an extensive subsurface permafrost layer as well as sufficient confining layers above the injection interval. In addition, there are no fresh water subsurface aquifers used by local communities in the area. Well SB 5 was successfully used as a disposal well for injection of approved waste streams in the Barrow Sand. Well SB 13 was successfully fracture stimulated in the Barrow Sand and Well SB 20 was successfully acid stimulated in the Barrow Sand Given the relatively small volume of fluids that will be injected, and the intermittent (on and off cycles) operation of the injection well or wells, fracture formation and growth will be very limited. No fresh water aquifers will be impacted by fracture propagation since no fresh water aquifers are present and there are sufficient confining intervals present above the injection interval to prohibit significant upward fracture propagation. 11 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields The Commission is authorized to grant a waiver requiring a separate fracture propagation study. See 20 AAC 25.450 and 20 AAC 25.252(g). 12. Formation Water Quality Information (20 AAC 25.252(c )(10)) Attachment 9 includes analyses of water samples taken from the Barrow gas fields. The data show that the disposal interval does not require an aquifer exemption. There have been no indicated incompatibility problems between the injected waste streams and the in-situ formation fluids over the many years the NSB has injected waste, stimulation and fracture fluids at the Barrow gas fields. 13. Aquifer Exemption (20 AAC 25.252(c )(11)) None issued or required. 14. Mechanical Condition of Adiacent Wells (20 AAC 25.252( c)(12) No other wells will be affected. There are no other wells with one quarter mile of the proposed disposal wells. 15. Mechanical Integrity Demonstration and Testing (20 AAC 25.252.(d ) Both wells are completed without down-hole packers. This is the common production practice in the two fields. We are requesting that a mechanical integrity test in accordance with 20 AAC 25.412 be waived by the Commission as provided for in Commission regulations (see 20 AAC 25.252(g) and 20 AAC 25.507 and 20 AAC 25.450). The tubing and casing/tubing annulus pressure will be monitored on a daily basis while operations are underway and reported to the Commission on Form 10-406. The wells will be plugged and abandoned according to Commission requirements once the overall Barrow drilling program is complete in mid 2011. We believe the wells meet the standards set forth in the Commission's regulations and do not pose a risk to the environment. These wells will be temporary disposal wells and the volume of fluid injected will be relatively small. 12 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields There are no records of any formation integrity tests run in the SB 13 well. One FIT test was run in the EB 15 well at 1514 to 1524 feet MD after the intermediate casing string was set. In that test the formation held pressure at an equivalent mud weight of 0.61 psi/ft. See Attachment 10. The intermediate casing string in both wells was pressure tested before drilling out deeper and the long casing string was pressure tested before perforating. No mechanical problems have occurred in previous waste disposal, fracture stimulation and acid stimulation operations in the Barrow gas fields. See Attachments 11 and 1 lA for the well production histories. 16. Mechanical Integrity of Other Wells Within 1/ mile Radius (20 AAC 25.252 (h)) There are no wells with a 1/ mile radius of the SB 13 and EB 15 wells. See Attachments 3 and 3A for the wells and well locations. 17. Well Design, Construction and Testing (20 AAC 25.412(a) through (e)) The SB 13 and EB 15 wells are constructed in accordance with 20 AAC 25.412, existing Pool Rules and prudent engineering practices. The wells will be monitored in accordance with this regulation during injection operations. Tubing in the SB 13 well is 2 7/8 inch, 6.5 lb N-80. Tubing in the EB 15 well is 2 7/8 inch, 6.5 lb N-80. The wellheads are rated for 3000 psi. The wells do not have a packer installed. Casing and tubing specifications are shown on Attachments 8 and 8A. Wellhead specifications are shown on Attachment 7 and 7A. The wells are cemented across the injection interval. In addition, the wells are properly cemented above the injection interval and the outer strings of casing are properly cemented. The cementing of the wells insures that the injected fluids will be confined to the injection interval. We believe that the well construction provides that injected fluids will be limited to the intended interval. See Attachments 6 and 6A. Cement bond logs were run on both wells after the long string casing was cemented. All casing strings in Well SB 13 are cemented to the surface. The intermediate casing string in Well EB 15 is cemented to the surface while the long casing string is cemented from 1300 feet to 2198 feet MD and filled with Arctic Pack from surface to 1180 feet MD. 13 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields Given that the wells are already completed and open to the desired injection interval we request a waiver that the wells be completed with a packer and pressure tested prior to commencing injection. No fresh water aquifers will be affected since no fresh water aquifers are present. The Commission is authorized to grant such waivers under 20 AAC 25.450. 18. Notices (20 AAC 25.420 and .432) To be provided to the AOGCC prior to and during operations as required. END 14 Geology ATTACHMENT 1. Geologic Report The Barrow Sandstone, found in the lower portion of the Jurassic Kingak Shale, is interpreted to be a series of near-shore marine sands and shales. These consolidated sands have relatively low porosity and permeability values compared with other shallow sands found on the North Slope, because they were buried to an estimated depth of about 10,000 feet subsea. Uplift and subsequent erosion along the Lower Cretaceous Unconformity (LCU) removed varying amounts of the Kingak Shale, but left the Barrow Sandstone at the East and South Barrow Fields. During the Tertiary, the Barrow Sandstone was uplifted to its current depth of about 2,000 feet subsea in these fields. Reservoir properties and lateral continuity of the Barrow Sandstone are well understood, based on seismic and core data from numerous well penetrations. See Attachment lA-- North Slope Stratigraphy and Attachment 1 B-Field Location Map The Barrow Sandstone, averaging 100 feet in total gross thickness, is divided into an Upper and Lower package. Both packages contain very fine to fine-grained, glauconitic sandstones with siltstone and shale interbeds. The Upper Barrow, 30 feet thick at SB#13 (South Field) and 80 feet thick at SB #15 (East Field), has porosity values between 4% and 20% and permeability values between 0 and 114md. The Lower Barrow, 25 feet thick at SB #15 and 55 feet thick at SB#13, has porosity values between 15% and 24% and permeability values between 33-364 md. See Attachments 1C and 1D-South Barrow 13 and East Barrow 15 Well Logs. Structurally, the Barrow Sandstone interval is found between 2065 and 2170 feet subsea in SB #15, the deepest penetration on the flank of the pool, and between 2250 and 2335 feet subsea at a mid-pool penetration in SB #13. Faulting is minor in both fields and so, the reservoir structure is relatively uncomplicated. See Attachments lE and 1F-South Field and East Field Structure Maps. The LCU removed. the upper section of the Kingak Shale in both fields, leaving 90 feet and 195 feet of Kingak Shale at SB #13 and SB #15, respectively. The Cretaceous age Walakpa Sandstone, typically 15 feet thick and found at 2150 feet subsea, sits above the LCU and is perforated in SB #13. Above the Walakpa Sandstone, a massive package of Cretaceous shales and thin sand stringers occur all the way up to the permafrost, which is typically found around 1,000 feet subsea. This thick sequence of laterally extensive shales provides a seal above both the Barrow and Walakpa Sandstones. See Attachments 1 G and 1 H-South Field and East Field cross Sections. No commercial hydrocarbon bearing zones underlie the Barrow sandstones in either the South or East Fields. Below the Barrow sandstone in the South field, some 50 to 80 feet of Triassic age interval is present, and underlying that is argillaceous basement. Below. the Barrow sandstone in the East field, some 150 to 200 feet of Triassic age interval is present, and underlying that is argillaceous basement. No commercial hydrocarbon bearing zones are present above the Walakpa sandstones in either the South or East Fields. Both the SB 13 well and the SB 15 well are depleted gas wells. Converting both wells to disposal wells and then plugging and abandoning the wells once disposal operations are complete will not result in waste. For reference, Attachments lI and 1J are excerpts from the original geologic reports for the SB 13 and EB 15 wells. C~ CENOZOIC U' ~Z ~W ~7 Q: ~W i ~: ;Z ;Q IY ~ D 1 Q' CRETACEOUS m ~lOATH SLOPE STRATIGRAPHY sa~rm~sr rumf+E~ ~ Gubik Fm. Q _-..,...:- L _ Z C Q ~. Utz 0 Q JURASSIC W',W ~~fD ~~- N z ! TRIASSIC ¢; ¢' w: ~'. ~, ~ ~ PEAMfAN J W~ ~ I 320 CARBOMFEROUS PRE CAABONIFtAOUS Walakp~l ss Barrow ss r~.~~ 'Local usage Marine and nonmarine ~ Limestone ~ Marine shale classic deposits I ar~d dobmite i `: d~ E~ z ~ ~ r~ Ix Q •O ~'" O E-~ ~ d CJ Hiatus or Condensed erosion .Granite marine shale Location Map -South and East Barrow Fields \~ ~+ f \` '..V' .. ~ /' r'` 1 3 t r ~'~; ~ 1 .a' j r ^. NSB ~1 .~-~11 `--~ ~~` die ~~ _., . _.~...~... _ ~a ..- iV ~.t3 -UG ..' "`` ~' a~ ._..~w...~..._..,w.~._ ~,... ,. f ~' ~' ~''~~ ~ '` .. r,, fir' t ! r t r` / /. /` ., ~~ .'~'`,: ; ~~,,,~,.`, rte' ~,: ,, ~ , .. .,~~ . . / R } ."' ' m ~v ~~ 35D ` P ,~ .< .w.,~~.. ~,~. ~l'SB -d4 ~' ~' ~` ~N ~ ~~ ~ ATTACHMENT 1B. ';~ ,~ r eol rt ~,~; , `~ ~ ,, f G ogic Repo ;~ ~ ~ ~ , ~" ~ ~ ~~ a r s ,- J ~ ,, ~W, ~ ~, . , : r i • South Barrow #13 Well Loc U F z w a~ x ~ d o ~ o Q C7 A H z ~ a x x ~ .o ~ o d c~ South Barrow #15 Well Log Structure Map -East Barrow Field -Top Barrow SS r •I Structure Map -South Barrow Field -Top Walakpa SS ~, ~. I F 't } 1 Lt' ~ ~ l P .~ {~~ ~ r `~~~~~ '~ ., ~~ ~,, .. . ,~,, ~ ~ ~~f~~ .. ~, r ~ ~ r~ p r i , . ~ _L. . ,~' _ - ~' ~ .-- ---- ~ ~ x ~ . ~~,- `.' r t'` ~ ~~~,~ t ,. ~~.. ~ J, ~~ ~ .~.~ } ~ (~ ~ ' K . 5 t { i ~ ~' ~~ .~ ^"` it r~ f,~.. }' .~+,~ ~,~ t ,4 ~, 1 ;, ~, i , 6 ...3~ i ..~k ,...1 ~ ~ ~ ,~ ~. 4 i ~° 3 t ~~,~~.~ _. "~ 1 _~y [ _ { s. NSA, ~ti ' f t"~ R ~ 1y _ 4 ~8 ~ ~~ ~ i ~ ,j '~ i ~'t ' Iy ~ r , ~ ~~~ ~ '~ t '{' ~- ~ t q South Barrow #13 ~~; ~ t ~ w-°~ ,~<~ ~~ ~gg ~ ~ ~~~ ~ ~ ~ ~ ~ ~ i C / ... ~ ~ , ~. ~~ - t z ~„ W ~ ~~ ~ ~ V ~ .., ,~ t d' , , ' I , s ~ ~ ~ an , ~ f } 1 ? ~ ~"~r~.,,,~,.~.r~~ Vii, f ~ i ~ t tf t+~ i 'i ........ -.._f t>. ~ J [~ y~ 1 ~{ 1 " Y ~~~..~~ ~ ~~ ~ ~~° ~ ~ North ~~ Y' 4 a ~ 9 ~ ~ ~~~ ~ ~ ~ ~~ t °~„ a , ~-'~~ ~ + ~~ ~ ~ • • South Barrow #9 l;.M'• Asa ,•, ,0 5a~vrva Tvi!'. ;> ~ 144 R/l h+' MD- `F llWw11 CwU WI1a1 -1(00 1250 -7750 t~00 -19J0 . 13r) ~ t 1J5U ~ ~a~ -law 'tww ~ I 9650 ~ 1650 t N l eoa ,l4 ? ~tso9 1650 ~ t 650 nag } 1700 >`1 1150 ~ t... -1750 ~~, 1800 c 10riU i r?~',n I65U v.n.;9 -t Sigl rN[959 __-_- ~ -___ ___-_ 6... M'150 2ooa e OJU -2060 21ao -ztu5 also ~ ~21A ~ 2'00 -+ zzeu ~? z2so ;~ 2250 aco tN:U <SSo e:.,w. ~ ~- Barrow SS South Barrow Field Cross-section (N - S) South Barrow #11 1 7W~$> CA RItIID) '419 4W cf.wl Za IADa ~ IIGNM) -_- - ul .139 2a[ iul wa Nw ...a.a) •1:50 _ ~30J 13W1 ~ ~~ / 1350 ~ QUU t -wsu { ,o 1500 L -t550 ~{ ouJ (tl -1600 -1650 L ~ vou f 1S(1 a 1 lnr) 750 6a:. rPZ>a - -aaoa so ~ ,3'` ~ run_e1 -18w _ f9aa f j { •1900 ~ ~ iy~U t it 1959 a-:lao 6ua - f i s = =° i + •2050 >I ! ca ~ < i -ztoo 2150 .i~ , Jwn4,a "-~1a00 ,a,,,« lau j 22so U 13srtww Barrow SS -z756 23(19 ~- ^+ } South Barrow #13 UzIW~ Cwra~ua A':. w.Y'.~y TVD~Sx OP HMO) 9W 6Ar1 iMSt4 t[tl MID* 5- llGro++~l 4v -1 d?1 lKl rwyW1) 900 ~ - N - - 18009 1 ~i iwi3w) ` t~}'~ f J 1~ ^~'-~- ~~~~ ~ tea" ,~#-. ''-~~d t . ~x ~t$rUU ~~ 1600 t950 ~{ • y 1650 >` -1600 ~ noo t' -t>;so N+Z 6.w 1RI5U -t ]a~ ~ ~~ 1600 -t ]w k ~ 16~o t -teuo j t 1900 -te6o 1950 °-' •~ • , -+eoo ~ ~ acw }~ -1950 z6oo :,rin ~ -2060 ~~,...-- 7156 2100 • 2200 w.rlwax50 lv' - ~_- z2go -nau .'~Da r d ~ --..-._- U.@new Sa i , uaalo~w.no , ~ Barrow SS 2JUG r~ n b sn~a~x :,nso 0'x"n J90 ATTACHMENT 1 G. Geologic Report NSB-02 apPr Wr1~>1 A x T~I(1$$> G6 H1lF[ I UW InD> Sa llG1WA1 Ix cwcx) 900 --- _ --1881 "1 L =~ x~ ~` .` ~Affd _ ~.i ~~~ t ~ ,[.tid tf ~~~ ~ _ r~ -•c- _ rrm ~ v .~ 1~d / ~=' z i tf6R9 H+ l IN]' ~ t ssa . 1%f6 i t _~ ~-ram--- ~>7C4q ~ ~ 1 ~m ~ ~- 110519 ~' 9 1 --~ -- -4dfA - 1 (r!{YJ ~~ at0f9 -~'.. .- < ~" - --- «ugg)9 a3Qftl ! _ ,r 2j~ ~~ r U Odle Z uLanuw ar Barrow SS l.BSxaw i,lB ( - T 2d2f9 ~ ~ ~ • • East Barrow Field Cross-section (NW - SE) South Barrow #15 South Barrow #19 South Barrow #12 South Barrow #20 South Barrow #18 _. -~ 500232001600 3251 K 5()0232001200 1368 fi 50023200t1ti00 2009 h 500232001500 3931 H 5002.32001700 :'-~' NORTH SLOPE BOROUGH NORTH SLOPE BORWGN NORTIi SLOPE BOROUGH NORTH SLOPE BOROUGH NORTH SLOPE BOROUGH S BARROW 15 S BARROW 19 S BARROW 12 S BARROW 20 S BARROW 18 I`! ~ . `1_ ~ i ~ 17i, ' ~'._~ 1. t ~ s - - -- - -_-•- - - -- ~-~-1-- - ----- -_ ...___ _ ~_ __ - - -- -- ---_ ~~ ; T 2135 Barrow SS IIi •. ~ ..'~: ::(: :~ f: i~.. -1-: -. _ __. _._ _ _. _-_:._.... _ _ _._.. _ ___ ~___ ` ._ . `~ ::_ _ _. _~._ _ .: ATTACHMENT 1 H. ;. - ~ - -_ ro=226 ' ~ `~ TO=2325 TD~2287 `r ~..{ TO=2358 Geologic Report 1 1 0 N A T I O N A L PETROLEUM RESERVE ! N A L A S K A ATTACHMENT II. Geologic Report GEOLOGICAL REPORT SOUTH BARROW WELL NO. ~5 .~: > r ; t, _.. ~•. HUSKY OIL NPR OPERATIONS, ING. Prepared by: R. G. Brockway For the U. S. GEOLOGICAL SURVEY' Office of the National Petroleum Reserve in Akaska Department of the Interior AUGUST 1983 •• •• TABLE OF CONTENTS GEOLOGIC SUMMARY Page f ntroduction . . 1 Pre-Drilling Prognosis . 1 Post-Drilling Summary . . . 1 Location Map (Figure 1} . . 3 Certificate of Surveyor (Figure 2) . 4 Structure, Top of Lower Barrow Sand (Figure 3} . 5 WELLSITE GEOLOGIST'S REPORT Introduction . . 6 Stratigraphy Wireline Tops 6 Cretaceous Torok Formation . 6 "Pebble Shale" 8 Jurassic Kingak Formation 8 Upper Barrow sandstone 9 Lower Barrow sandstone 10 Hydrocarbon Indications . . 10 Structu raI Data . . 11 Conc{usions . . 12 LIST OF F{GURES Figure 1 - Location Map . . . . 3 Figure 2 - Certificate of Surveyor 4 Figure 3 -Structure, Top of Lower Barrow Sand 5 PERTINENT DATA AND APPENDICES APPENDIX A. Summary of Pertinent Data A-1-2 B. Drill Cuttings and Core Descriptions B-1-10 G. Log Analysis Report of September 16, 1980. C-1-2 D. Logging Report, September 10-11, 1980 D-1 •~ •r PERTINENT DATA AND ANALYSIS (Continued} E. Core Analysis E-1-2 F. Drill Stem Test Reports Report of September 7, 1980, DST Na. 1 F-1 Report of September 7, 1980, DST No. 2 F-2 Report of September 9, 1980, DST No. 3 F-3 Report of September 12, 1980, DST No. 4 F-4 G. Gas Analysis Reports Report of September 22, 1980 . G-1 Report of September 24, 1980 . . G-2 Report of September 24, 1980. . . G-3 H. Analytical Reports Report of -September 16, 1980 . H-1 Water Analysis Report, October 8, 1980. H-2 Water Analysis Report, October 8, 1980. H-3 COMPOSITE LITHOLOGY LOG (In Pocket} •~ •• 1 1 iNTRODUGTION GEOLOGIC SUMMARY The South Barrow Wel{ No. 15, 2640' FEL and 990' FNL, protracted Section 23, T22N, R17W, Umiat Meridian, is approximately 10 miles southeast of Barrow, Alaska (Figures 1, 2, and 3}. ft was drilled in an effort to extend the East Barrow Gas Field in a northerly direction. drilling below conductor casing began on August 23, 1980 and Cretaceous and Late Jurassic age rocks were drilled. The well terminated as a producible gas well in Lower Jurassic(?) strata at a total depth of 2, 278 feet on September 10, 1980. Six conventional cores were cut. Four drill-stem tests (including 2 misruns) and one production test were undertaken. In each of the South Barrow wells drilled after No. 13, an inhibitive mud system,. containing calcium' chloride, was used below the intermediate casing (commonly 9-5/8" to about 1500'}. This was done to minimize damage to potential reservoirs caused by swelling clays, which are present in the Barrow sandstones and Sag River Sandstone (determined by water-susceptibility tests on cores from South Barrow Nos. 12 and 13). The high concentrations of calcium chloride (68,000 to .118,000 ppm) used in the drilling mud below intermediate coring necessitated running a dual laterolag as the high calcium- and chloride-ion concentration in the mud adversely affects the conductivity measurement. by the daul induction log. The dual induction log was run in the upper part of each well where fresh-water mud was used. PRE-DRILLING PROGNOSIS Pr'smary objective of the well was the Lower Barrow sandstone. Approximately 20-25 feet of good porous sandstone was expected at a depth of approximately 2060`. Secondary objectives were the Upper Barrow sandstone and possibly thin sandstones in the lower "Pebble Shale" . POST-DRILLING SUMMARY Resu{ts obtained from the drilling of the South Barrow Well No. 15 proved to be disappointing as it was discovered that the Lower Barrow sandstone was 128 feet Lower than indicated by prognosis and 153 feet Lower than South Barrow Well No. 19, approximately one-half mite to the southeast. Because the the field, it and 18. i South Barrow Well No. 15 is so much lower than other wells in is concluded that a fault must pass between Wells Nos. 15 The Lower Barrow sandstone (primary objective) had porosities of 15-180, but it computed to be water wet. This was confirmed by Drill-Stem Test No. 4 (2188-2278'), which recovered 2090' of formation water. ~ ' • The Upper Barrow sandstone, with porosities of 11.1 to 24.40 but generally low permeabilities, contained fair to good hydrocarbon shows. Drill-Stem Test Na. 3, through perforations 2105-2136', recovered gas at a calculated rate of 500 MCFGPD. A production test through perforations (2054-2064', 2110-2151`} in the Upper Barrow and a sandstone in the Kingak recovered 1.0 MMCFGFD. This well was completed as a gas well in the Upper Barrow sandstone. t i WELLSITE GEOLOGIST'S REPORT BY: R. G. BROCKWAY INTRODUCTION The South Barrow Well No. 15, was drilled approximately 10 miles southeast of Barrow, Alaska. Primary objectives of the well were the Barrow sandstones, particularly the Lower Barrow, which is the main producing sandstone of the East Barrow Gas Field. " Upon drilling the well, it was discovered that No. 15 was 155 lower than South Barrow Well No. 19 at the top of the Upper Barrow sandstone. It was then concluded that these two wells are separated by a fau lt. Porous zones were observed in both the Upper and Lower Barrow sandstones. -Hydrocarbon shows were fair to good in the Upper Barrow with only a trace in the Lower Barrow. Porosities varied from 11.1$ to 24.4$ in the Upper Barrow. A production test of the Upper Barrow recovered 1.0 MMCFGPD. The Lower Barrow had fair porosities, but computed to be water wet. . STRATIG RAPHY W1RELiNE TOPS Drilled Subsea Depth (BKB} KB 30' CRETACEOUS Torok Formation 110' -$0' Samples start "Pebble Shale" 1480` -1450` JURASSIC Kingak Formation 1911' -1881' Upper Barrow sandstone 2107' -2077' Lower Barrow sandstone 218$' -2158' Total Depth 2278' -2248` CRETACEOUS Torok Formation: 110-1480` Samples throughout the Tarok Formation -were very poor or missing. The sediments are very susceptible to water, and water without used to drill the upper 1510' of South Barrow Weli Na. 15. additives was Nearly al! the samples went into suspension and through the shaker screens. With the use of electric fogs and those samples that were obtained, it appears that the upper 700' of the formation consists of interbedded ~ 6 • i siltstones, claystones and sandstones, with the sandstones and sittstones most prominent. One zone from 372-505' appears to be a sandstone section with interbedded siltstone and etaystone stringers. A light tannish-gray, sandy siltstone with coat chips, scattered light and dark gray chert pebbles and lnoceramus fragments, was present to a depth of 250'. From 250-373', the samples were primarily sandstone with brownish-gray, very argilfaceous limestone. These sandstones are light to , medium gray, very fine to fine grained, subangular, sightly carbonaceous, partly very carbonaceous on what appears to be bedding planes, very calcareous, micaceous and have scattered fossil fragments. The limestone probably occurs as thin interbeds in the sandstone. Electric logs indicate the presence of passible siltstones and claystones, although they were not present in the samples. In the interval 373-505', sandstones were observed which were tight to medium gray, very fine to medium grained, with the medium grained sand in the upper 25', very clayey to very calcareous, subangular, with scattered limestone nodules and coal stringers. Traces of siltstone and shale were observed in the samples. A few chips contained calcite crystals an what appeared to be fracture faces. The interval 505' to 700' appears , on the logs to be thin bedded sandstones, sittstones and claystones. Only very light to medium gray, very fine grained sandstone and' some very argillaceous limestone were present in the cuttings. A trace of gray argiflaceous siltstone was observed, which increased slightly in the interval Tao-boo' . At 800', Core No. 1 (800-825') was cut, and 9' of soft, flaky micromicaceous shale was recovered. A and rare sandstone inclusions and partings occurred. brownish-gray, very few very silty streaks Below 825', samples were very poor or unobtainable, but the drifting mud was composed of a very high percentage of fine sift. Shales from Core No. 1 were very susceptible to water, so it is assumed that the interval 800-1329` is composed of very soft clayey siltstones and soft silty claystones or shales, with occasional sandstone beds and partings. These assumptions are supported by .the electric-tog responses. Core No. 2 (1329-1389') was taken in an effort to recover the contact of the Torok Formation and the "Pebble Shale". Recovered in this core were thin bedded and interlaminated dark brown, silty, "poker chip" shales, brown micaceous siltstone and dark to tight brawn, very fine to fine grained, subangular, very shalt' and silty sandstones with hydrocarbon shows. The contact was not present. Samples below 1389' to a depth of 1480` were also very poor, but are probably similar to the strata found in Core No. 2. Rare chips of light brownish-gray, slightly carbonaceous siltstone were present in the drifting mud through this interval. 7 u n ~ ~R A "Pebble Shale": 1480-1911' The "Pebble Shale" is composed of dark gray to dark brownish-gray, fissile, carbonaceous, micromicaceous shales with same siltstone stringers and thin light gray bentonites and bentanitic shale in the upper 110'. Scattered throughout the shales are rounded quartz grains, dark chert granules and very fine crystalline pyrite inclusions. Below 1590', there is an increase in siltstone and sandstone interbeds and a decrease in bentonitic material. The siltstones are brownish-gray to dark gray, partly carbonaceous, shalt', soft to moderately hard and generally very thin bedded. The sandstones, in beds up to 5' thick, are light brownish-gray to medium gray, very fine to fine grained, subangufar, occasionally partly subrounded, slightly silty and clayey with argillite and carbonaceous grains and scattered glaucoriite grains. Light and dark chert pebbles and rounded quartz grains increase slightly in abundance in a downward direction. Porosity in the sandstones reaches a high of approximately 1$$ (Density porosity log) with hydrocarbon shows present in all the sands. In an effort to cut the Cretaceous-.Jurassic contact, Core No. 3 (1$38-18$1') was taken, but did not recover the contact. Interbedded siltstones and sandstones were recovered in the 'interval 183$-1872'. The siltstones are dark brown, sandy and shalt', and the sandstones are brown to dark brown, very fine to fine grained, subangufar and slightly glauconitic and contain fair to good hydrocarbon shows. Sandstone beds obtain thicknesses of 2'. The lower 6.8' of the core is gray-brown fissile shale with fish fragments. Rounded light and dark chert granules and pebbles and rounded quartz grains are scattered to common throughout. At 1900', a thin, sandy, '"salt and pepper" chert and quartz pebble conglomerate was encountered in the drill cuttings. This has been designated as the basal "Pebble Shale" conglomerate. The Cretaceous-Jurassic contact has been placed at the base of the conglomerate at 1911'. JURASSIC Kingak Formation: 1911-2278' The Jurassic Kingak Formation, to a depth of 2058', is composed of interbedded siltstones and shales with occasional sandstone stringers. The siltstones are light brownish-gray, soft, carbonaceous, with a trace of glauconite grains and pellets. The shales, varying in color from light to dark gray and gray-brown, are fissile, soft, and also contain traces of g(auconite grains and pellets and pyrite inclusions. In the interval 2058' to 2107' (top of the Upper Barrow sandstone), there is an increase in sandstone interbeds, but only two attain thicknesses up to 4'. One at 2058-2002', which had no shows, was very fine grained, subangufar, and clayey. The second was encountered in a drilling break at 2092' (driller's depth), and was circulated up at 2096`. Samples from ~ e r• I• ~ this interval contained a light gray to light tannish-gray, very fine to fine ' grained, subrounded to rounded, silty, argillaceaus sandstone with a slight hydrocarbon show, and lignitic coal and wood fragments. Same coal chips were coated with a green mineral (glaucanite?). Core No. 4 (2096-2136') recovered the lower 13' of the sandstone, siltstane and shale sequence which is indicated an the sonic log at 2093-2107'. Hydrocarbon shows were observed in the sandstones of the 13' interval. The contact of the Upper Barrow sandstone (a secondary objective} has been picked at the base of a brawn shale which occurs in the core at , 2107.9-2109' (2105-2107' sonic log) . Upper Barrow sandstone: 2107-2172' Twenty-three feet of the Upper Barrow sandstone were recovered in Core No. 4. These sandstones were light to medium brown, very fine to fine grained, glauconitic and contained hydrocarbon shows. Porosities far the Upper Barrow section of Core No. 4 ranged from 12.90 to 23.8°b. Permeabifities averaged 10.2 millidarcies with the exception of two one-foot intervals which had 133 and 188 miElidarcies. Three drill-stem tests were attempted over the intervals 2080-2136', 2095-2136', and 2105-2136'. The first two were miruns, the third (2105-2136') had a calculated rate of 500 MCFGPD (Appendix F) . A production test of the Upper Barrow and. a thin sandstone of the Kingak had a calculated recovery of 1 .0 MMCFGPD. , From 2136' to 2165', sandstones, similar to those in Core No. 4, were interbedded with light brown to brownish-gray shales and siltstones. Thin zones of porosity (estimated up to 200} were observed in the sandstones. Core No. 5 (2165-2187') was taken in what was thought to be the Lower Barrow sandstone. It was not discovered until after the electric fogs were run that the core was terminated immediately above the Lower Barrow. This care was primarily light brawn to gray-brown, subangular, fine grained- sandstone with porosities varying from 10.9°a to 24.40- (Appendix E} . Permeabilities were generally (ow. The base of the Upper Barrow sandstone has been placed at 2172' (a , brown shale at 2172.5' in the core) to correlate with other wells in the East Barrow Gas Field. Sandstones of the Kingak Formation below 2172.5' (Core Na. 5) are very similar to those of the Upper Barrow, but had, in addition, scattered fossil and wood fragments. Hydrocarbon shows were present throughout. The lower 4.9' (2180-2184.9`} of recovered core appeared oil saturated and was fractured and shattered. Spotty accumulations of live ail were present on some fracture faces and this portion of the core exhibited bleeding oil. Core analysis and electric logs show that this zone is thin and water-wet. , Generally there is a thin shale bed overlying the Lower Barrow sandstone and it is indicated on the electric log at 2186-2188'. It was not present in the care or samples but may have been in the unrecavered portion of the care. -~ ,: s ~ ~ A w Lower Barrow sandstone: 2188-2208' The Lower Barrow sandstone, the primary objective and main producing reservoir of the East Barrow Gas Field, is 20' thick in this well. It is a tight brown and tan, fine grained friable sandstone, partially filled with clay. Scattered carbonaceous and glauconitic grains are present. Poor hydrocarbon shows were observed. The formation density porosity log shows that porosities vary from 15-18°o and have ca[cu{aced water saturations of 79-100°-0 (Appendices C ~ D). Below the Lower Barrow, -the Kingak Formation, which appears to extend to total depth of the well,* is a zone of .interbedded sandstones, siltstanes and shales. The sandstones vary from buff to 1`rght tannish-gray, are very fine to fine grained, very clayey and contain scattered carbonaceous and glauconite grains. No hydrocarbon shows were observed. Interbedded siltstones are fight gray to dark gray-brown, shalt', partly sandy and contain carbonaceous flakes. The shales are light brown to dark brownish-gray, fissile and carbonaceous. A drill-stem test of the Lower Barrow sandstone and underlying rocks recovered 2490' of formation water (Appendix F, DST No. 4}. * Biastratigraphic studies were not made on this welt but correlations with South Barrow No. 19 indicate that No. 15 was probably terminated in lower Jurassic rocks. i HYDROCARBON INDfGATIONS By use of a binocular microscope, ultra-violet light and hydrogen flame ' chromatograph, the samples from South Barrow Well No. 15 were monitored for hydrocarbon shows. Shows were minimal in the Torok Formation, although Gore No. 2 (1329-1389`) had fair to good fluorescence and cut in chloroethane from very thin bedded and interlaminated sandstones and siitstones. No sandstones of substantial thickness were encountered to warrant testing. Sandstones of the "Pebb{e Shale", although not exceeding 5' in thickness, began to show an increase in hydrocarbon shows. Gas readings up to 360 units were recorded an the chromatograph with bright yellow to light yellow fluorescence and instant b{uish-yellow to light yellow streaming cut observed under the ultra-violet light and .immersion in ch(oroethane. Because these sands were thin and relatively far apart, they were not tested . Background gas increased from 20 units to 80 units at 1885' and remained relatively high throughout the upper part of the Kingak. Occasional higher readings up to 480 units were Hated, but fluorescence and cut were not observed until the sandstones at 2092-2096' were drilled. These sandstones had light to dull yellow fluorescence and very slow duff yellow cut in the circulated drill cuttings, and had an increase in gas up to 280 units. ld •• •• ~ Sands of the Upper Barrow sandstone all showed varying degrees of hydrocarbon fluorescence and cut under the ultra-violet light, although gas readings were cower than those obtained in the overlying part of the Kingak Formation. They averaged 100 units throughout. Two drill-stem tests, 2080-2136` and 2095-2136', were attempted. with the packers failing on each. A third test, 2105-2136', was good and recovered , preliminary rates of 300-500 MCFGPD on 20/64" choke (Appendix F} . A production test was later performed through perforations at 2110-2151' and 2054-2064' (a thin sandstone in the Kingak}, with a calculated recovery of i .0 MMCFGPD on 5116" choke (see History of Dr'riling, South Barrow Well No. 15, Husky Oil NPR Operations, lnc. , September 1982, pages 3 ~ 4} . Porosities obtained from laboratory analysis of Core No. 4 (2096-2136'} varied from 11 .1 o to 23.80 with an average of 13.70 for the upper 26' and 19.1 o for the next underlying 10' recovered. Permeability was generally very low except far the interval 2122-2131 `, where permeability reached a maximum of 188 millidarcies for 1' at 2126' and averaged 4i millidarcies. Core No. 5 (2i65-2187') exhibited hydrocarbon shows throughout with the bottom 4.9' appearing oil saturated. As mentioned previously, porosities varied from 10.9-24.40. Permeabifities were generally low, and water saturations were predominantly greater than 60°x. The lower three feet of the 4.9` interval had good porosity and permeability. Porosities were ' 2fl.6o to 24.40 for this 3' zone and permeabilities of 216 and _335 millidarcies recorded. Although some bleeding oi) was observed at the wellsite, core analysis ,- shows that this zone is water-wet (water saturations to 840). The electric. fogs indicate that the 3' recovered in the core was approximately the total , thickness of the good porosity-permeable interval. The Lower Barrow sandstone which had poor hydrocarbon shows, was not cored but electric-log calculations indicate 15-18o porosity and 79-100% water saturation . Drill-Stem Test No. 4 was taken over the interval 2188-2278' with a ' recovery of 2090' of formation water (Appendix F) . A chloride content of 14,000 ppm and a resistivity of 0.29 ohms at 58° was obtained from the water recovered from the test toot sample chamber. STRUCTURAL DATA South Barrow Well No. 15 is located on the north flank, as indicated from prognosis, of a small east-trending structural high (Figure 3). Drilling showed that the well is located on the down-thrown side of a fault that passes between Wells Nos. 15 and 19. A correlation between the two wells shows that No. 15 is 155' lower than No. 19 at the tap of the Upper Barrow sandstone. A correlation of the BHC sonic logs from the two wells indicates that the fault must be present in the upper 493` of Well No. 15. , From points at 493' in No. 15 and 330' in No. 19, correlations are good downward through the Lower Barrow sandstone with very little change in total interval (2-4'}. !t is the opinion of this writer that the fault should be placed at approximately 490'. 11 A A The dipmeter shows a high northeast dip (55° decreasing to 30°) from surface to 370'. Readings are sparce from 370-500` but indicate an increase in dip in a southeast direction. From 500' to 940' there is a reversal of dip to a west and southwest direction with dips averaging approximately 20°. At 940-970' there is a short reversal to the northeast at 1° to 2° dip. Below 970', the general trend of dip is to the northwest although occasional reversa s do occur. Dips average 2-6°. The writer feels that same of the reversals in dip are due to slump and fracturing, and some to possible crossbedding in the sandstone. Fractures and some slickensides were observed in aN but one of the cores recovered. It is also the writer`s feeling that same of the steep dips above 370' can be attributed to movement associated with the fault placed at approximately 490' . CONCLUSIONS. 1. The South Barrow Well No. 15 is a gas producer from the Upper Barrow sandstone of the Kingak Formation. ' 2. Well No. 15 is the only well in the East Barrow Gas Field to produce from this zone at the present time. 3. Because of the location on the down-thrown side of a fault, and ' thus 87` to .155' lower than other wells in the field, the Lower Barrow sandstone (principal gas-producing zone in the East Barrow field) is below the gas-water contact and will only produce water. [] '1 0 C u N A T I O N A L PETROLEUM RESERVE I N A L A S K A ATTACHMENT 1J. Geologic Report GEOLOGICAL REPORT U . S . NAVY SOUTH BARROW WELL NO. 13 ~~~~ ~ ~ ~~ ~~;g~ Oll ~- Gss Cans. ~a~R~tssias~ pna~arage HUSKY OIL NPR OPERATIONS, lNC. Prepared by: Ronald G. Brockway Edited by: Gordon W. Legg For the U. S. GEOLOGICAL SURVEY Office of the National Petroleum Reserve in Alaska Department of the Interior AUGUST 1983 ~. • TABLE OF CONTENTS GEOLOGIC SUMMARY .s Introduction . Pre-Drilling Prognosis ~-. Post-Drilling Summary Location Map (Figure 1) Certificate of Surveyor (Figure 2) WELLSITE GEOLOGIST'S REPORT Introduction . "' Stratigraphy Wi rel i ne Tops . C retaceou s ~-- Torok Formation "Pebble Shale" Jurassic ,~ Kingak Formation Upper Barrow sandstone Lower Barrow sandstone Triassic '"° Shublik Formation . Indeterminate --~ Zones of Hydrocarbon Shows . Testing . Conclusions w LIST OF FIGURES Figure 1 - Lacation Map ®' Figure 2 -Certificate of Surveyor PERTINENT DATA AND APPENDICES Appendix ,~ A. Summary Pertinent Data B. Drill Cuttings and Core Descriptions °' C. Electrical-Log Analysis . D. Core Analysis Results E. Analytical Report COMPOSITE L{THOLOGY LOG (In Pocket) i Pa e 1 1 1 3 4 5 6 7 7 8 8 8 8 9 9 9 10 3 4 A-1-2 B-1-17 c-1-z D-1-2 E-1-2 ~...- INTRODUCTION r \s GEOLOGIC SUMMARY -- The South Barrow Well No. 13, 552' FSL and 807' FWL, protracted Section 14, T22N, R18W, Umiat M eridian, is located in the South Barrow Gas Field, approximately four miles southeast of Barrow, Alaska. Drilling below conductor casing at 74' began on December 17, 1976 and terminated at a depth of 2534' on January 1, 1977. A suite ~of lithologies from Lower Cretaceous (Torok) to Pre-Mississippian (argillite) were '° penetrated . After attempting flow tests, the rig was released on January 16, 1977. PRE-DRILLING PROGNOSIS The primary objectives of South Barrow Well No. 13 were the lower Jurassic Barrow sandstones. A possible secondary objective was the Lower Unconformity sandstone at the base of the "Pebble Shale". The Barrow sandstones were predicted to be encountered at a subsea depth of -2195' and the argillite at -2320'. POST-DRILLING SUMMARY The South Barrow Well No. 13 was drilled through the Torok Formation and "Pebble Shale" to a deptfi of 2159' where two continuous cores ~. (2159-2219') were taken in an effort to cut the Lower Cretaceous-Jurassic unconformity. The contact was not observed in either care. The unconformity was encountered at 2240' (-2200' subsea). At the South Barrow Well No. 11, located approximately 3000' to the northeast, it was at -2160' subsea.. An additional 25' of section not present at the tap of the Kingak Formation "' in South Barrow Well No. 11 was noted in No. 13. The Barrow sandstones were encountered at 2296' with 52' of the Upper ..,. Barrow being cored. Fair to good hydrocarbon. shows were observed in the upper 34', then became spotty to nil downward. Porosities varied from 4.2 to 19.60, but permeabilities were generally very low. Susceptibility tests were performed on Core No. 4 (2318-2348'} and the clays in the sandstone matrix were found to be highly susceptible to damage from contact with fresh water (Appendix E} . The Lower Barrow sandstone was not cored, but an 1$' sandstone (2363-2381') had porosities of 16-18$ and water saturations of 66-75%. Hydrocarbon shows were limited to spotty dull yellow fluorescence. The Triassic Shublik Formation, 61` thick (not predicted in prognosis), was encountered overlying the argillite which was penetrated at 2472'. 1 WELLSITE GEOLOGIST'S REPORT BY: RONALD G. BROCKWAY INTRODUCTION Drilling below conductor casing began on December 17, .1976, on South Barrow No. 13 proposed gas well. The well was drilled to a depth of ~-- 1,166 feet on December 21, 1976, at which time 10-314" casing was set at a depth of 1,157 feet. Drilling rates from 74 feet (base of conductor casing) to 1,166 feet varied from 0.4 min. to 2.5 min. per foot. Drilling resumed December 24, after allowing -the cement to set on the casing and the well was drilled to a depth of 2,159 feet on December 25, 1976, at an average rate of 0.8 min. to 1.5 min. per foot. At this point °"" two 30-foot cores were taken in an effort to core the Lower Cretaceous-Jurassic unconformity. These cores, 2159-2219', were predominantly dark shale and did not cut the unconformity. A sand, °- black shale, and dark chert-pebble conglomerate comprised the last foot of core recovered (2218-2219`) . The conglomerate could possibly be an erosional remnant near the top of the unconformity. ,.. At 2,230 feet, a conglomeratic sandstone was encountered which was correlated to the Unconformity sandstone in South Barrow No. 11. At this point, it was discovered that South Barrow Welt No. 13 was about 40 feet `r structurally lower than No. 11 at the base of the sandstone. Two cores (Nos. 3 and 4) were taken December 29 and 30, 1976, from 2288-2348` to recover the porous zones of the Barrow gas sands. These cores were predominantly "dirty" sandstones with interbedded siitstones and shales. Occasional zones exhibited good porosity, up to 200 .... (estimated). Oil staining was observed throughout both cores, but became very poor in the tower portion of Gore No. 4. The well was then drilled December 30, 1976, with. a rotary bit from 2348' `- to 2410'. Drilling rates averaged 3.5 min. per foot, except for the last five feet which averaged 6 min. per foot. At this point a 15-foot core (2410-2425`) was taken to recover the argillite, which was postulated to be °- at this point. Some argillite chips were encountered in the ditch samples. Core recovery showed only shalt' sandstone .and siltstone, partly calcareous. Electrical fogs were run (December 31 and January 1) at this point to ascertain the correlations and porosities of the well and 'rt was discovered that the well was still in what was then thought to be Lower Barrow sand. An added stratigraphic section, not present in South Barrow No. 11, was discovered immediately below the Unconformity sand: at 2230'. This section was about 25 feet thick, which then put the well about 65 feet structurally -- lower than predicted by the prognosis. 5 At this time, it was decided to continue drilling the well with a conventional bit into the argillite. Black and very dark gray sedimentary rocks were observed in the 2475-2480' sample. These rocks were very soft and considered a claystone, probably weathered argillite, and drilled at an average rate of 2.5 min. per foot to 2510'. Drilling rates increased to approximately 4.0 min. per foot, and samples indicated the argillite becoming more siliceous and hard. Core No. 6 was cut from 2522-2534' in the argillite; recovery was only three feet. Drilling was suspended at 2534' on January 1, 1977. Final electrica{ (ogs and sidewall coring were performed January 1 and 2. No drill-stem tests were undertaken while drilling. Two flow tests were attempted after completion of drilling with negative results. Six conventional cores were cut, and 24 sidewall cores (17 recovered) were shot. The wel{ was suspended. STRAT{G RAPHY WI RELI NE TOPS Feet below Subsea Kel{y Bushing (KB 40') CRETACEOUS Torok Formation 200' -160' samples start "Pebble Shale" 1740' -1700' JURASSIC Kingak Formation 2240' -2200' Upper Barrow sandstone 2296' -2256' Lower Barrow sandstone 2363' -2323' TRIASSIC Shublik Formation 2411' -2371' INDETERMINATE A rg i I 1 ite 2472' -2432' TOTAL DEPTH 2534' -2494' NOTE: A discrepancy has been noted between the 2" DlL and 5" DIL logs. At depth of 1550', both logs are the same. At the base of the Unconformity sand (2240' 2" DIL) there is a 6' difference with the 5" (2234'). The Gamma Ray from the FDC/CNL !og matches closely with the 5" DlL log. Tops in this report are picked to correlate with 2" composite log . 6 ,~ CRETACEOUS Torok Formation: 200-1740' ~', The rocks of the Torok Formation were quite soft and had a tendency to a-- disperse in the drilling mud. Therefore the described samples may not be entirely representative of -the formation. At the same time, there were problems with the flow line freezing. Light gray, sandy, silty claystones _ are the main lithology of the Torok. Some thin-bedded light gray, very fine grained sandstones and siltstones were observed. Coal chips, pyrite inclusions, chert pebbles, limestone nodules and fossil '~' fragments were scattered throughout. The interval 200-1740'. has been given an Aptian to Albian age by --- Anderson, Warren >i Associates, Inc. Hydrocarbon shows were very minor in the Torok Formation. A very _, slight show of gas was noted at 1450' where a peak of 80 units, 50 units over background, was recorded. "Pebble Shale": 1740-2240' ~. ,:. At 1740', there was a ~ce~`y distinct change in lithology. A dark gray, fissile, carbonaceous s `ah le with "floating" rounded quartz grains was --- penetrated. This change was supported by a high gamma-ray reading on the Gamma-Ray log and also by biostratigraphic data. Thin scattered sandstone beds were present to approximately 2000' where they became _., more numerous. A thin sandstone at 2010-2020' had- a gas peak of 120 units and displayed a fair fluorescence and cut. Minor shows were recorded to 2065' . ~°' Starting at 2159', Cores Nos. 1 and 2 were cut .(2159.-2189', 2.189-2219'} with 57 feet recovered. Dark brownish-gray shale.. with.. some. dank.,. gray... and dark brown shale and "floating" quartz grains. was the predominate -- lithology. Some brown siltstone and sandstone beds, some with hydrocarbon shows, were present in the upper core. Both cores exhibited fracturing with slickensides common. -Free oil was noted in fractures at 21.77.4' to 2180' . One foot of conglomerate with a black shale matrix was recovered from the bottom of Core No. 2. This may be part of a transitional zone leading to the basal conglomeratic '-' sandstone which was encountered at 2230'. The conglomeratic sandstone (Lower Unconformity sandstone, 2230-2240') is light gray,. "salt and pepper", subrounded to subangular, and it contains pebbles- of light and dark chert. An estimated 15-2E3`so porosity (Density log shows a `maximum of 22°~s) was observed with slight hydrocarbon staining and a trace of gas recorded. 7 Biostratigraphic determinations by Anderson, Warren E Associates, Inc. have placed the interval 1740' to 2080' as probable Early Cretaceous (Neocomian) and 2080-2220' as Late Jurassic-Early Cretaceous (Neocomian) by microfauna. The interval 1710-2411' was indicated as probably Neocomian by palynology. JURASSIC Kingak Formation: 2240-2411' The Kingak Formation includes the Upper and Lower Barrow sandstones as intervals in the lower, sandy facies of the Kingak. The top of the section is composed of gray-brown shales, with siltstones and minor sandstones. The Kingak section below the Lower Barrow sandstone is a sequence of sandstone and shale in which the shales are a dark gray-brown. The main sandstone body (Upper Barrow) begins at 2296' in Core No. 3 (2288-2318`). After correlation with South Barrow No. 11, it was found that an additional 25` of extra section is present at the top of the Kingak in South Barrow No. 13, compared to South Barrow No. 11. Upper Barrow sandstone: 2296-2353' The Upper Barrow sandstones have been picked at 2296', where the main sandstone body starts in Core No. 3. Cores Nos. 3 and 4 (2288-2348'), recovered 60 feet, of which 52 feet was brownish-gray to light gray, very fine grained glauconitic sandstones with siltstone interbeds. Good hydrocarbon shows were present to a depth of 2330'; below this point they become spotty to slight. Fracturing was observed in bath cores. Core analysis of samples from Cores Nos. 3 and 4 showed porosities ranging from 4.2 to 19.6$. Permeabilities varied from 0.0 to 114 millidarcies with most below 5.0. Water saturations from the core analysis were generally over 60$ (Appendix D) . Lower Barrow sandstone: 2363-2382' The Lower Barrow sandstone has been picked at the top of an 18' sandstone that is light gray, very fine grained and contains siderite and calcite streaks. Porosities through this sand were 16-18$ as shown on the density porosity log with water saturations of 66 to 7$$ (Appendix C). Hydrocarbon shows were limited to a dull yellow spotty fluorescence. Paleontological data has p{aced the interval 2220-2411' into an Early to Middle Jurassic age. TRIASSIC Shublik Formation: 2411-2472' Sandstone is the main lithotogy of the Shublik Formation. The sandstone is light gray to light brown, very fine grained, partly calcareous, and 8 commonly fossiliferous. The formation also includes some interbedded shale and sittstone. The sandstones are shalt', have generally poor porosity and '"" contain no shows. Core No. 5 (2410-2425') apparently cut the contact between the Jurassic --~ and Triassic rocks. Anderson, Warren E Associates, Inc. place the microfaunal time line at 2411'. This contact was not observed in the core, but it may be at the top of the shale, with fossils described at ,,., 2412.5-2414.5' (Appendix B) . INDETERMINATE Argiflite: 2472-2534' The argillite was penetrated at 2472' (E-log pick), and the upper 25` was a ~-- very dark gray to black, carbonaceous claystone. Below this was black argillite, showing low-grade metamorphism and quartz-filled fractures. Core No. 6 (2522-2534') recovered 3' of black argillite with quartz veins ~~~- and pyrite inclusions. Traces of gas bubb{es were noted in the core. Chromatograph readings rose to 80-90 units. "°' Anderson, Warren & Associates, f nc. pick the base of the Triassic at 2460` . 1400-1480' 1810-1820' 2000-2100' 2230-2240' 2270-2300' ZONES OF HYDROCARBON SHOWS Slight gas show. Slight gas show. Slight gas show, spotty fluorescence, fair cut. Oil. stain., good. fluorescence, good cut, gas show 80 units. Spotty fluorescence, fair cut. 2300-2350' Good fluorescence, bright yellow, good cut, bright milky .~.. yellow, becoming dull yellow 2330-2340`, dull yellow cut. 2364-2385' Spotty fluorescence, dolt yellow, very faint, slight dull yellow cut. 2475-2534` Slight gas show, up to 90 units. Core No. 6 exhibited trace of gas bubbles after being washed. TESTING ._.. No drill-stem tests were performed on this well white drilling. After completion of drilling, an attempt was made to flow test the well through perforations at 2358-2368', 2330-2345', 2315-2330', and 2224-2234' . 9 ~ ~ Negative results were obtained even after being "rocked" with gas from South Barrow No. 10. The well was reperforated at 2383-2387', 2356.5-2376.5', 2315.5-2345.5` and 2224.5-2234.5'. Again the well was "rocked" with gas and recovered a very slight flow. The well was then suspended. In an effort to ascertain why the welt did not produce, samples were taken from Core No. 4, over the interval 2318-2344', for analysis of susceptibility to Liquids. It was found that the clays in the sandstone matrix were of the swelling type and very highly susceptible to fresh water; a fresh-water mud was used to drill the well. It was also noted that a diesel-based mud would have the least effect on the swelling clays (Appendix E) . NOTE: This well was flow tested again on July 20, 1978 at a calculated A.O.F. of 360 MCFPD. This improvement in gas flow indicates that, to some extent, the reservoir sandstones are "self healing", probably due to dehydration of the interstitial clay minerals by methane (Drilling History, ibid, Appendix II, pages 2-5). CONCLUSIONS 1. With South Barrow Well No. 13 being 65 feet structurally lower at the top of the Upper Barrow sand than originally predicted, the closing structure of the South Barrow Gas Field becomes much smaller and is confined mostly to Section 14. Possibly another structure may be present to the south in Section 23 with South Barrow No. 13 being located in the saddle between. 2. The Upper Barrow sand. appears to be the best source for gas production. Although the sandstone is shalt' and has shale banding and laminations, some thin zones have porosity up to 200. The upper portion (2296-2340') of the unit exhibited good to spotty bright blue-yellow fluorescence and cut, indicating that the hydrocarbons present are of high viscosity. 3. Below 2340', fluorescence becomes. spotty to nil and a very faint, very dull yellow. These sands appear to be flushed and water-wet and that production should be limited to those sands above 2340'. Electric-log computations show a high water saturation far the Lower Barrow sandstone at 2363-2381'. 4. Some gas was encountered at the top of the argillite with some kicks as high as 90 units on the chromatograph. 10 ~' ~~ SUMMARY OF PERTINENT DATA WELL NAME: `° API NO.: OPERATOR: LOCATION COORDINATES: ELEVATION: ,_, DATE SPUDDED: TOTAL DEPTH: '~ DATE REACHED TOTAL DEPTH: -- RIG RELEASED: STATUS: CASING: LOGGING RECORD: DlL/SP BRCS/GR/Caliper FDC/CNL/GR/Caliper FDC/GR/Caliper HDT Dipmeter CBL/VDL/GR CCL Mudlog South Barrow Weft No. 13 50-023-20008 Husky Oil NPR Operations, Inc. 552' FSL, 807' FWL protracted Section 14, T22N, R18W, Umiat Meridian, Alaska. Latitude: 71 °15`13.84"N Longitude: 156°37'40.41 "W X = 661,513 Y = 6,310,250 Zone 6 40' KB, 22' Ground, 26` Pad December 17, 1976 2,534 feet January 1, 1977 January 16, 1977 Suspended January 17, 1977 20" @ 74' 10-3/4" @ 1157' 7" -surface to 2514' 75-1093' 1157-2422' 1157-2527' 75-1080' 1157-2419` 1157-2523' 1157-2427' 1..1.57-2534' 1157-2427'. ` l 1` 57=2534' 1157-2534' 50-2464' 2224-2387' 200-2534' A-1 s -- • LOGGING RECORD: (Continued) .~ Computed Logs Dipmeter Arrow Plot 1165-2458' Saraband ~.. 1160-2504' SIDEWALL CORES: Shot 24, recovered 17. '~- CONVENTIONAL CORES: No. Depth Recovered Formation 1 2159-2189' 30' "Pebble Shale" 2 2189-2219' 27' "Pebble Shale" 3 2288-2318' 30' ~ Upper Barrow 9' 4 2318-2348' 30' Upper Barrow 5 2410-2425' 15' Shublik 6 2522-2534' 3' Argillite WELLSITE GEOLOGIST: R. G. Brockway -- WELL LOG ANALYST: Armour Kane CONTRACTOR: Husky Oil NPR Operati ons, Enc. MUD LOGGERS: Petro-Tec BIOSTRATIGRAPHIC °" ANALYSIS: Anderson, Warren ~ Associates, Inc. * Copies and/or reproducib les of all geological data are available from: °' National Oceanic and Atmospheric Administration EDISINGSDC (D62) 325 Broadway _.,. Boulder, CO 80303 `.. f ~~~~ A-2 Flow tests through perforations at 2358-2368', 2330-2345', 2315-2330`, and 2224-2234' were attempted with negative results (see testing information). ,,., The well was suspended. r 2 ..r tir No commercial hydrocarbon bearing zones are present above the Walakpa sandstones in either the South or East Fields. Both the SB 13 well and the SB 15 well are depleted gas wells. Converting both wells to disposal wells and then plugging and abandoning the wells once disposal operations are complete will not result in waste. For reference, Attachments lI and 1J are excerpts from the original geologic reports for the SB 13 and EB 15 wells. Location Map -South and East Barrow Fields ASF'. ~t~~'=~ Current vs of 9i_2i~9: sub~ecl to chance. limy? ~.wo-td?irn:. Ins 0n tone '.000 1.000 a.o00 5.000 Feet I i~.5?) NSB Barrow Gas Fields Upgrades Project ~ ~, ~ - ~ N East Field ~' ~~ Proposed Disposal Well ~ I Savik #1 and #2 Proposed Locations ~ ; ~ ~ ~;.~r~6 ~ ~ _ _ _. T22N R17W Quarter with Relevant Quarter Section Lines , ~ '$~~ ' Section ( ~"~~,~ ~~ Line ~ ~ ~ ., ~~~ , i NEW WELLS ' r . , ..._-. -~--- -----.-. --Sec.24~ - ---~-.-.. Sec. 23 :,~ ~ ~? ~ ~~~ ~~, ~~ ~ ~ ~ ~` SAVIK#2 ~ ~ SAVIK #1 • ~` ~~;~~ . , . • -. -- "- y9 , ~ - ri SAVIK #1 HEEL - ... } ~ ~ al,, fi ~ i Y. `~ `a„'ae ~ ~,~s ~ ~ - sAVIK #i roE `~ ' ~"" S AVIK #2 HEEL ~~ ~ +~ ~ l ~ ' ~ °~ $~~~ ,~ ~ ~"` ~ ,~ ,~ r EAST „&+ n. " ~~`~~` "~' ,•~ ~ FIELD , ~. t~ rn .i. E.. 'SAVIK #2tTOE ~ ~ ~ ~ 1 x ~' r '-~ ~' '' ` ° ~ .. .: .~~ Y ~ I 20 ~ ;; !ATTACHMENT 3A. a 4y`. i --i Le nd ~"° W kS ~ ~. ~ ge ~ ~" i Wells `~- Plat of Nearby ~ ~ ~ Proposed Wells-3urtaceLocatlons ~ ~ ~ Sec. 25 , Ice Road Access To Lakes P&A Wells RequiringlceAccess + .W..•------• m, ~ -~-^°'•-""` ~ f S t llit I G Li L ti ~ ~ ~ "' ' ~ ' mage oca rom a e e Existing as ne on ,,,,~ . ;, ,~~ ~~ ,,, ASP6, NAD27 0 200 400 E00 800 1,000 2000 3,000 4,000 Image: Aero-Metric, Inc. Feet 2/3/2010 Miles 0 0.125 0.25 1;12,000 D.5 North Slope Borough Application for Disposal Injection Order and UIC Class II Disposal Wells Barrow Gas Fields Attachment #4 Affidavit Comes now William D. Van Dyke, and being duly sworn upon his oath, states and deposes as follows: 1. That I am over the age of 21 years and mentally competent to make this affidavit. 2. That I am knowledgeable and fully informed concerning the facts contained in this affidavit. 3. That for approximately the last 3 years I have worked in Alaska for Petrotechnical Resources Alaska (PRA). 4. That I assisted in the preparation of the Application for a Disposal Injection Order and Two Class II UIC Disposal Wells to be located in the East and South Barrow Gas Fields (The Application). Such Application is intended to be submitted to the AOGCC along with a copy of this affidavit. I also prepared the notification list showing both surface and subsurface ownership interests within one quarter mile of each proposed disposal well. There is only one subsurface owner and only one surface owner. 5. On or about February 24, 2010, PRA employees mailed notice of the Application and a copy of the Application itself to the surface owner and subsurface owner, both return receipt requested. I believe that we mailed the materials to good current addresses. In view of the foregoing facts, PRA on behalf of the North Slope Borough as operator of the proposed disposal wells has made a reasonable and diligent effort to identify, locate and contact all parties legally due notice of the said Application. Further affiant sayeth not. William D. Van Dyk (affiant) Notary Stamp STATE OF ALASKA ,~ NOTARY PUBLIC ~~ Brenda Smith My Commission Expires Dec 4, 2G12 ~ ~ ~o~~ Date ~~~ ~~ • South Barrow #13 Weli Loc `~' a z ~ 3 x U ~ d ~' H ~ ~ d • South Barrow #15 Well Log ,, „ ... ..a.. Dtptn Cor~axion Res ~HrvA•y PaOSAy bg5 NDSS> GR RT Rhh;fl S~ Gaaf rY Ohnn+ 65 Gea 265 MD> SP LLD ~! r.M -1 OF11rMi 2QG ~ ~ _ ~ ~ _ VN 0 C.1LI rwYW3) DT r'CO - - M - - 75 Oa' 1 2G I:;O r~0 US+F 50 itCO rwfMlA) a 600 ~ 1550 r y -i 65D ~ 100 - ' {~ r -1700 _ ~"f 175J ~- _~ ~~ ~ ~_ ~ -t 750 -u O6 ~- l _a . ~ __..~ -t6oo ~ ,aso ~ y ~ ~ S 1 ~ ^ + i ~ •1850 „=r 'r, .-. as' ~- Paele4pe Walakpa SS ~~, Y~ __ asap ~ ~ 195J K ~ _~ ~ '~- ~ -1450 ~~ ? 2000 ~ S r -2000 2oso - ~Perforated ~ ~' ~ 2DSa ,. -~- - 210o f,, f s U. Barrow xi Upper Barrow SS Perforated U e erraw ~D ~ 2150 f f y L mow -c roD 2200 Bssa 8arro`v 3 ~ 4 ~ -220D r r 2250 ~ j d ~ ~ ~ z~^' W W x V ~ Q r..+ • ATTACHMENT 6. • Well Construction Details ,..ts. ~- U1'~"ED STATES s~~T ~ avP~6 " r - ~6 ~ " -- '- snd°`~sei s,~ ~.:z:-RSrs.s. - r>a. . - DEPARTMENT OF THE INTER[OR ur>:et~~ ~^ reverse dde, s. t.t.an z.r~s,enAr1DM ~,D sas,ar. NV. _ _ - GEOLOG [CAL SURVEY - ~ _ - N jA _ _ ` ~ _ WELL COMPLETION OR RECOMPLETtON RFPURT AND LOG * ~ ~' IYDIAN: ALLOTTti OR TuB!`NAYR ' ~ ' --- - - - --- N/A = _ = : • ~~ = ta. T E F W L otL csa WELL ^ wRt•L ® DRT ^ Other 7. ~Nti_ACRSRYLNT NAW ' ~ ` h TYPE OF COMPLETfON: = '' t _ - N jA - .csw WoRR oser- rLac Dtrr. - ^~ WILL ® Oc Rt ^ Cat ^ RACR ^ CSavtL^ Other ~ _ $- rasx- os'LSAas xaxs atYOna _ _ 2. X1Yi 0! OPLItATOR ~ n _ _ t~ _ petrOletlm ",ReSe°rVe ~ AK USES through Husky Oil NPR Operations, Inc. - a...aLL xo' - ~ _ _ •= a. ADORtBa o:-orttAZOR - ----- -- - - ------ , So. Barrow We12 No.-~ 15 2525 C Street, Suite 400, Anchorage, AR 99503 = ~ lO~rttLD3AND Foot. o!•~rrrLDC~=~ 4. LOCATION 0/ BELL (Report toesttaR stasrty snd fn aetordanee RaIA any Bta a rtgsireaatntt~• SO, $arrOw Gd3. F~iel.d At turtace 2640' FEL ; 990' FNL ~ { 11. asr.; z. a.. Y„ of suocR aND saavsT - At top Drod. latervat reported bete j ~ '' - ~: "< ~ r - s z . - Ac total depth Same (straight hole) ~ ~ 23;: T22N= ~RZ7W,~ UM Sec . 14. PtRYM NO. DATA I88UICD t.2.-COaNrT OR ~. .13. aTAiS= . _ _ _ _ _ _ .-- --~-_ :. - ~:_-N/A = -~ _ _--- _~_. -_ ~- -_ N/A North"Sloe orotigh, AK 15. osrs SPUDDED ! 16. DATC T.D. ssaexltD ( ti. DArt COYPL. (Ready to prod.) 1$. LttYATIONB (Dr• HSS, ET,-OR. iTC.)~ 18. Ltst'.`CAS[:t98aAD 8/23/80 i 9/1/80 1 9/10/80 ~ GL-7; Pad-12';KB-30' :'_ ~ ~ 12'=-~ ~ ~' 20. SOSAL DQ'rH, YD a 'rVD Yl. rtaq, sacs :.D., I[D a TYD 22. tr Mt'LTU'Lt COMP(... 23. lNTLRt'ALS • EOTART• TOOLS ': ~=CAYLa- T001.3 227.8' TVD 6 MD NOW -[ANT• DttLLSD SS __~ ~ ~ 2170' ~ N/A • ~ ~ ~, _ < ~ Rotary' `) >: - - _ _ L4. PRODLC3:Ia 3nTEHYA4(St. Or T73 iS WRPL8TW:1-TOl, HOT7.9Y. ~A3ii tMD AnD Tiur-~ - ~~ +••~~~~•~•~~ - - : aaEYaS;d[ADR- 2054'-2064' and 2110'-2151' 1~ID & TVD, Upper Barrow Sands = = _- _ ~. ' = - "- - ~`•~_ 26. TTPL ELLCTRtC A\D OrBLt LOGS TtB,P 2T. WAS WELL -0ORCD ,_ -= DLL/MSFL/GR, FDC/CNL/G'R/CAL, BHC/GR, DIF, MLL ~ = ~ =- - Yes " ° `~~~ 23. CASI~tG RECORD (Report act atrinpe aet {„ toed) - ~ -~ - CA 81T0 SIZE WZ30 NT. La./!r. DtPTH St:T (YD) MOLL S1ZL CENtNTttC RECORD-- ANOONT PULLED 13 3/8" 72~, S-45 80' KB 17 1/2" ` 230`Sx Cl G to Surface None - 9 5/8" 53.5 S-95 1514' KB I2 I/4" 1500 Sx Fertna€rost Rtrns None.:` 7" 3$~ S-95 2198' KB 8 I/2" 90 Sx C1 G w/2~ Cc12--' None-` ° 50 Sx Downsaueeze 2d-Staff None • - 29. A.IIgER RECORD 30. TCBI*IO RECORD ". - •• ati6 rOP (ND) •D7TOY (YD} SACSa CRYtCr! SCREEN (YD) 81Zt DLrTB StT (YD) PACSSIt SCr (!SD) 2 7/8" 2155'- KB N/A. ` ua. r.a.vs......w ~.ssu t+•••orvu., ..cc .ass n~anvcr, EZ. AGID. SFLOT. FRACTURE. CEMENT SQIIEEZE• 1:TG.. '- 2054' -2064' ; 21 I0' -2 I51' DLMH I\TLt~AL (YD) lYOCNT AND =IND. O!` NArittAL IIBtD' w/4" 'Hyperjet II Casitsg- Gulti .- -._._ .. _ _ . _ _ _ - _ . - _ - AN~I~~ JUL 2 3 2008 _ - _ :. - 83.' PRODIICTION - _ - - _ -. DATE rtasr rtooccrtoY PtotwcTSOx ysraoD (Ftotonty, 0a± t~Jt, prmpNtp-e{z6 and type o1 Pvm.p) - - WtL t s~Arca (Prodretny.or - 9/ 17/8a _ _ -, ___. _ _Gas -- - . _-- ___ - _ : _ k ~ - • at ts) _ - _ _ -_ ~ - stint =ln- DATE Or TtST HOCtB rLSTLD CHOSR RIZt PftOD'N. rot OIL--6tL. ~ .CAB-NCd. - WATtt-tSL _ - OAS-0tL' LTSO 9/ I7-18/80 ~ 36 ~ 1/8-5/ 16" ~ Tsar rssroa -~ ~ 0 - ' ~ 250 MCFD (= _ -U-" ~~ = :" ~ - =~ ~N/A PLOW. TVttNa Ptite. f CA8180 YRL88CtC CALCIILAT2D OIL-StG 6A8-llCl. - WATEI- SRL. OLL OtArITZ-AM (CORR.) { 24-HOUR CATS - _ _ _ - _ - - 34. atatKSSlrtoN or o/s (ffiotd, we Jor¢d, tre,ited, tte.) _ Tssr wtT~tsstD tT ;- =:. _ • Flared ~- I H. M. Peterson =-' 35. Lux or ArruHNSxrs - _ _ ` We ~ _- _-~~_ -__ - _ _ 38. I hereby ql that the for L ~ attached intormatfon L complete and correct-sa determtDed from alt a~aUabie morda ~ sterrsD - ~~ Chief of Operations, ONPRA -~ =lis~t~ }'t '(Sce lnsttactions and Space for Additional Data on Reverse Side) 1 ~ ~I IJ ' UNITED STATES DEPART~AENT OF T1-}E INTERIOR GEOLOGICAL SURVEY SUNflRY hOTiGES A~tD REPORTS ON WELLS 1wq~n or Nus beck to s dithr~wc a ~ ~ d P ~ ~ ) i7 s t"r sueN MOM rtsMwir We iere" 44- 31 ~ ~, o ~! ® her ~ 2. NAME OF OPERATOR National. Petroleum Reserve is Alasiw:a (through Husky OiI NPR Operations, Inc.1 3. ADDRESS OF OPERATOR 2525 C Street, Suite 400, Anchdrage, AR 99503 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 t-etaw.) AT suRFACE 2640' FEL; 990' FNL AT TOP PROD. INTERVAL: AT70TAL OEPTti: $~ (straight hole) IS CHECK APPROPRIATE 80X TO INDICATE NATURE OF NOTICE. REPORT, OR OTHER DATA it n C NOTICE OF INTENT T0: TEST WATER SHUTOFF i FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CJtSinG MULTIPLE COMPLETE CHANGE ZONE:i ABANDON' _ . SUBSEQUENT REPORT OF: S of Running 7" Casing Amended & LEAS% fi.NtFAiNDiAN, ALLaT i eE OP. TRl3E ti:::4E N/A ?.N~."AiIT AGREEMENT flAatE & FAi?M OR LEASE NAME National Petroleum Reserve in Alaska 9. JE NO. Sout~i ~errow blell No. 15 (East Area) S~~it~it`~Qt~~~~ (East Area) 22. SEC.. T.. R., M., OR 9LK. ANO SURVeY OR Sec.A~~ T22N, RI7W, UM iz. couNTY oR forth Slope E 14. APt NO. 23 STATE i Alaska 13. ELEVATIONS SHOW DF K03. AND WD) GL: 7'; Pad: I2'; KBc 30` tgOTI: R1freK rnWes W n+utNd" aenepl.dew w zbn~ eM"p o". Fsrn, 9 136J 27 DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Ctearry_state alt pa.-:srtx:t details. and ~w pertinent dstss, including estimated date of staRfng arty proposed work. It wei! is deraetionstty drfltad. Qive subsurface iocations and rrtea:ured and troe vertical depths for aU trurfcess end zones pertinent to this work.)' Drilled 8-1/2" hole to 2278' Loogggged with DLL/MSFL/GR, FDC/CNL/GR/CAL, BHC/GR, Dipmeter, MLL. Ran 58 points of 38#, 5-g5, BTC casing. Landed shoe at 2198', aOs at 1180.07` and 1300'. Cemented with 90 sacks of Class "G" with 2% CaC12 and lA CFR-2 at 14.9-15.2 ppg slurry weight. CIP at 3:15 PM, 9/14/x. Nippled up and tested BOPS to 3000 psi. Tested FO to 2000 psi OK. Arctic Packed 7" x 9-5/8" an-tclus. Circulated and dt~wnsqueezed through lower FO 50 sacks Class "6" with 2% CaCI2 and I% CFR-2. Subsuefaee Safety Valve: Maori. and Typo Sat (e~ Ft. IB. i hsreby certify that the foKiang is true anQ corrsc! Ori~inaol s/ ax G. Brewer TITLE Chief of,Slperationt3xTE ~~ ~y:e.~wer Qn Conforms with pertinent provisions of 30- CFR 221. Original signed by ~tO"a to r~er•t er snu "~ ~} ..,i°'-~, J.-iiaaivha et~~n~ District Supervisq~TS IO-2-80 dmended 1/1f83 •Ste tmtrvensws "" Rewr~~ Si"~ -P 2 ©~V (C ~ ~ ~~ m ~ ~ ~ ~ ~ ~A ~ ~ ~ ~ ~-- ~ 13 ~ a a a •a ~~ ~ ~x~~ ~ ~~ ~~ ~ N N .r~~,M p~ ~ .r ?~~.~ • O.~ ~ A a ~~ ~~ ~ ~~ ~rt~ ~~~~ M ~'~"~ ~ ~ ~ ~1~~~'~ n ~s ~~~ ~ -~ ? ~ ~~~~ N ~.~ r / ' ~ ' ~ .~1 a" , ' p .~ ~ 4 ~ ' I' Y 1. 111 ~ / 1 1 ' 1 / , ~ 1 /~ / ~ , ~ q 1 ~~ 111 1 1 r; 1 . ~ ~-•) / V`M ~~t,l, , 1'.11'1'1 f 1 1 I H " ,- \.../ ~ ¢ , . , Ir. . 1 ? ~ 1 ,/ 1,,,1,1.1 ~ 11 j1 f ~ 1+1 ti ~, ,~~ ;., ,.1'11 `I ~ ~ /~ 1,; 1'1 i l ,1, , l ~ ( , J JIF ~.1 ~ '- ~ / w ~ ~ . 11 1 1 1 p~' 141 » 1 71 1 I l i.l l L' S 1 1... -~ .+ f 1. 1 : 1,,1._-~,~ /' 1 1 ~ ' . , ~ ~ ,, • --~ ~ .., ~~ ,~ ,, 1 U. 11 , : .• ; •`~• , / A 1~• /OM/ 1 1 ,' 1 k /~* (''T-/: ~, ., ~ ~ .• 1 11 ~~ ./ 1 1 ~ 1 11111 j .; ~ T-a'~ l 1 1 ! I r ~ Ir;... ~sr y , ~ WI ~ ~ ~ . _ 1 ~~,~_ . _ ----- ~ ..~ 1 1 1'q . 1.t 1 1 i 1 • ~/' 1 ~ ./ 1 » 1,1111 "..^ ~ r J ~ .1 .1'1.1 1 1 1 ~ r 1 1 / 1 ~1 / 1 1 ~ 1 / 1 ~ ~. / ' ! t 1 ~ ~~ ' 0 -~ 200 4oD 600 800 ~CHRlSTMAS TREE ~ _~ ~ t' t3 3/8" CONDUCTOR at 80` CEMENTED TO _ ~ ! SURFACE WITH 230 SACKS OF CLASS G. i 1000 ARCTIC PACKED 9 5/8"x 7" ANNULUS THROUGH FO. at 1180` ~;- r 1200 7" F.O~s at IISfl' & 1300` t I I 14 00 E 600 OF CEMENT THROUGH F0. nt 1300. 9 5/8" at 1514`, RAN 35 JOINTS OF 53.5 Ib., B.T.C., 8-95 CASING. CEMENTED TO SURFACE WITH 1500 SACKS OF PERMAFROST CEMENT of f4.8 to 14.9 PPG. 1800 PERFORATIONS at 2054'-2064' --~ 6 2110 - 2151 at 4 SHOTS PER FOOT 8 2" HOLE TO T. D. et 2278' PLUGGED BACK TO 2205. 2 7 8° TUBING WITH MULE SHOE at 2155 70 JOINTS OF 6.5 ib., N-80, EUE,SRD TUBING, PLUS 25~ OF MULE SHOE 7" at 2198`, RAN 58 JOINTS OF 38 Ib.,6.T.C., S~95 CASING. CEMENTED 1st STAGE WITH 90 SACKS OF CLASS'G` WITH 2 % CFR-2 AT 15.2 PPG. SOUTN BARROW No. 15 2640 FEL and 990` FNL Sec. 23, T.22N., R.t7W. , U.M. HUSKY OIL N. P. R C1pe~ations tVAT/ONAL PETROLE(JM RESERVE in ALASKA WELL COMPLETION SCHEMATIC 1 1 0 •i •• INTRODUCT{ON After the 1976 drilling season, casing requirements were reviewed and design of casing strings standardized. Every effort was made to minimize weight and grade changes for simplicity, cost effectiveness, and to reduce chances of error during handling and running operations. Casing sizes were selected to accommodate designs for wells from 2,000' to 20,000'. Steel grade selection was the controlling factor on design with tow hardness (Rockwell C24-28) steel being selected for Arctic application and possible H2S environment. Casing sizes and design crsteria required by Husky are listed be{ow: MINIMUM PRESSURE YIELD STRENGTH REQU l REMENT (PSI) (PSI} SIZE(1} WEIGHT M1N. MAX. COLLAPSE BURST CONNECTION 20" 133#/ft. 55,000 8Q,Q00 1,500 3,050 STC 13-3/8"(2) 72#/ft. 95,000 110,000 3,450 5,350 BTC 9-5/8"(3) 53.5#/ft. 95,000 110,000 8,850 7,900 BTC 9-3/4"(3) 53.2#/ft. 95,000 110,000 9,750 8,540 BTC 7" 38#/ft. 95,000 110,000 12,600. 9,200 BTC (1} OD tolerance _to be within API requirements unless adjustment absolutely necessary to meet l D requirements . (2) Special drift to 12.25". (3) Special drift to 8.50". The following are additional requirements primarily to assure that the .steel exhibits the metalturgical properties for Arctic applications and resistance to hydrogen embrittlement. 1. All pipe that is 13-3/8" OD and smaller to be quenched and tempered. 2. Run Charpy "V" notch tests on two random samples per 50 tons per heat. Minimum acceptance of 15 ft.-Ib.@-50°F. Furnish test reports with oE-der. 3. Perform all testing normally required for AP! approved pipe. 4. Furnish test reports for ladle analysis, quantitative analysis, and all check tests as per API requirements. In addition, the lot{owing handling requirements were made: 1. Collars must be of same stee{ grade as pipe body. 2. Apply an API modified thread compound on mill-installed collar before bucking on . 28 • r r 3. Inspect at mill using Tuboscope's Amatog IV or equivalent on 9-3/4" and smaller, and at feast magnetic particle on 13-3/8" and 20". All pipe to have special and area inspection together with full length API ' drifting. (Nate special drifting requirements. ) 4. Apply Arctic grade grease on all connections before installing thread protectors . 5. InstatE closed-end type thread protectors. Plastic plugs can be used to secure wrench openings in protectors. 6. Buck up thread protectors with impact wrench. Both mil! and third party inspection personnel should observe the installation of thread protectors . 7. Palletize or containerize the tubulars, if possible, prior to shipment from mill. Do not haul pipe like cordwood in gondola railroad cars. 8. All pipe to be Range 3. 9. No "V" notching or metal stenciling on pipe body or collars. ' Casing programmed far South Barrow Well No. 15 was as follows: 13-3/$" conductor at t1i0'; 9-5/8" casing at ±1504'; 7" casing at ±2100'; 2-7/$" production tubing if needed to complete the well. Casing actually run was 13-3/8" at 80`; 9-518" at 1514'; and 7" at 2198', The 2-7/8" production tubing was hung at 2155' just below the production perforations in the 7" , casing. The 7" x 9-518" annulus was Arctic Packed through the 7" FO at 1180' back to surface. r 29 , East Barrow #IS We~1 Bore Scf~ematic Based on information from AOGCC W'etI Histc~rv Wefl: Eas# Barrow # 15 13-3/8" 72# Casing Cmtd at 80' in 17-1/2" hole w/ 230 sx G (cmt to Surf} 7" X 9-5/8" Annulus Arctic Packed from 1180' to surface 9-5/8" 53.5# Casing cmtd at 1514' in 12-1 /4" w/ 1500 sx Prmfrst (cmt to Surf} Perforations 4 SPF Hyperjet IC Csg Gun 2054-2064' 2110-2151' 2-7/8" Tubing hung at 2155' No Packer 7" 38# S-95 Casing cmtd at 2198' in 8-1 /2" hole w/ 140 sx G cmt ( 80 sx CI "G" w/ 2% CaC12 & 50 Sx downsqueezed ) ~ ~ ~ PBTQ 2170' ,~ ~, `.~ i 3 ~'`~ f C~ 8-1 /2" hole TD is 2278' Barrow Gas Fields ~~'eli impro~`er?ments Study Feb 20Q7 Appendix d Page 39 of 47 C ?cc zco 3C0 4GC SCC 6GC 7G0 3C0 9CC ~cco ~.eo tzcc 1300 14CG sscc '6CG 1760 lace ,5co zccG z,oc zz<1 z3cc z=:~ Well: East Barrow No. 15 13-3/8" 72# Casing Cmtd at 8G' in 17-V2" hole vu! 230 sx G (cement to surface} 7" X 9-5l8" Annulus Arctic Packed from 1180' to surface 7" F.O.s at 1180' & 1300' Downsqueezed 50 sx (-55 cu.ft.) through FQ at 13GC' to 1700' 9-5t8" 53.5# Casing cmtd at 1514' in 12-1l4" w( 1500 sx Prmfrst (cement to surface} Perforations 4 SPF Hyperjet If Csg Gur. 2 0 54- 2 06 4 `. 2110 `-2151 ' 2-7i8" Tubing hung at 2155 with 1/4" control line and 1 G centrizrs 7" 38# 5-95 Casing emtd at 2108' in 8-1 /2" hale w,' 14G sx G cmt ( 9G sx CI "G" w! 2°% CaCl2 ~ 50 Sx do~Arnsgueezed } PBTD 2205' &1i2" hole TD is 2273' ATTACHMENT 6A. Well Construction Details I-(]P'13 ~-T ~ ~ - • SUBMIT IN P~ .TE• STATE OF ALASKA ee oH[er tn- strcrtions on __.. _ OIL AND GAS CONSERVATION COMiNITI'Ef reverse sitter WALL CCIMRLETiaN ,CSR RECC)MPL~TiON EiEPC}RT AND LOG ta. ?YP oil: aAs R'ELL BELL :. D8Y L..~ t)[heC ~ . --__ h. TYPE OFff~~CiiOMPLETIO (N~~ _. _. \Ew tJ ore.R[t L-J E`EP~ ^ DACx ^ a avR. ^ Other U'F;LL ` ... -Z \~HE_IiP UP4RATUR.-:,)- ~ - - '. r _ -- Husky-_Oil NPR, Oge~atzczns:,...~zh~_: _....,_---. a ,.. , 3. aDDaefly- at< -DFERAraR _ - _ 3201 C Str-yet, Suite 640, Anchorage, Alaska. 4. t,ocAr[ov or tcELL (K;.port location clearly and in accordanse with arty Stott requirements}• t t 23-200138 - - - _ d[i V R"tILTY A••(D ~SE.RIIkL. NO.-._."' AL,I.02TE:e. OK,'CHt $t: NA.~QE L OR );.E.1SE Nr>r4tE Koval Petr(~leuza Res.erv~e ~ wEL.L No. - 50. Barrow No~`:"T3"~ :~`~'" At surface 950 FWL be 500 FST., SeC 14, T22N, R18W i~.. tP•o-t-l~oa~t xoL.E - -- il. os tv EC .i r E st top Prod. in terosl reported Deiow SeG I4, T22N, R18W dt total depth to PERMTT NO: N/A _, . .. _t3,,.UAT.E .°[i DDED _ 14. DATE. T.D: REA.CFZLrD 15:. DATE COMP SLISP OR ABAND.- tB, ELEVATIONS (DF, RKB, RT,-GR, ETC)• I .ELEV. CASiliGHEAD ~ - } 12/17/76 312/77 ,-~ ~_: : u~p,_ 111,7/77_= = :•~ Grd =- 22• -Fad 26' KB-- 40;.f:j , ~ =:::26' ~; - 18. TOTAL DEPTH, 1,ID &TVD 9. PLUG, SAC ILID . IF MULTIPLE COM PL., - 22, t\TERVALS -DRILLED. 8Y SOW .,LiNY• ROTARY 2UDL$ ~ - CABLE TOOCB , 2534,' rID 2474'. MD .. All C(' -~: ~ : -2`L. PRODUCIYG INTERVAL(S), OF THISCOH•iPLETION-FI'OP, BOTTO:K, NAJ~IS fMDANLS TVD)` ~ - -' ~- (2~ tV~3~D{ O`iA - )) SURVEY MADE _ , .i. Yes 24 TYPE ELECTRIC A:'tiD OTHIIt LOGS Rt1N~. - - ~ - ~ - DIL/$HC Sonic/FDC-CNL-GR/HRD ' ~ - ~ CASISAG RECORD (Report aii sttuigs set fn wetU~-.~, ~ ~ .... .~ .:.. .- _... C-4S.t"i7G SIZE W_ EIGEiT~ LB/FT. GRAL)E DEP1 Ft SET f~ID) ~ I{OI,F( SIZE CE~?'~.VT'YG RELO.~ .. A_\;OCNP PULI,SD ~ . IO 41` - I4- 3 .4 Cm to f . 7)t 32 N-80 2514 8 ` 2 _ Cm S f _ Cla ss tt )) ~ 24. LINER RECORD -~ - ._ - - ... .. - - 27, ~ ~ ~ ~ TUBING RE;O D - SLZD TOP «ID7 -- 'BOTT0;,4-(MD) S.'#CF£S CEU~T• SCi..EI=.Y (i4iB3 SIZE 17P~"CIs< S£T (ti.~D) t,PACiiEIt SET (ivT'J) '28. PERFORATIO\S OPF~ TO PROD (inutval, s'iza and number). ?], ~- ~ ACID,--SLIOT. Fi.4V'i Lis, CE3.IE.t~Pt' SQU~Z^c,. ETC. ..Selected Intervals have been- Perforated n ir,~rr~rviL. (atDr A~L•~crrr ANIJ _• use .:with 4 SPF, Hyperjet II. • - , L- t. ,, .:° 20. PRODUCTION - - ~. 41Ft a~i;t ~~<;<: - - -DATE FIRST P20DUCTION PRODli CTtON-WiE'IHOD (Ftowin e, gas-IBS i, pcimD)ng~size and type of Dtdtnpl ~. - t-1"iL ~. _ $.1Produ - ~ DATL OP TLSr. HUiTRS TESTED ~ f.~LO_SES12E ~~~ FP.OD'N FOR ~ pIy-B.°,L,.- G.~S--I:CF. -Wf.'T€IL-3EI.:' GAS-OIL R:1TL0 - TEa'F 1'r"~tSOD ~~~ - FLOW, TJBIDI.G ~ -ASL\G fRESSIJItE CALCUI,ATF~ OLL-BBI. - GAS-i:ICF: ~ WATER-BBL. ~ ~. QIL. GRAVITY•APt (CORR.) PRESS. - 2!-FIOUIL RAZE - ~~~ I. nisaosrrenK ar r.AS [RaLd. uatd tof ueL. rented.tiC_) TE91' t4-FTYE3 3FDBT ` $?, L[9T UY ATTACB}fBtiT$' .~ ~~ Noae. This re ort.is CONFIDENTIAL and is filed for info t•on.o 3 . I herehp (:('rttfp ChaC'the areg n~ and a ac 'e to o"tmatloti" la comp ece hn correc as a er[n ne rout a a~a a e recor a ' D~illing~Enginsr.er Jan 28,. 1977 SIGNELY TITLE DATE ---- '(Sec fr4strurti-ors end Spaces for Add+tior+ol Data on Reverse Side) Farm 9-330 (keV' 6~' UNITED STATES svl;Mrr IN DUPLICATE• DEPARTMENT OF THE INTERIOR (Seeotherln- sfrucGona on reverse side} GEOLOGICAL SURVEY ~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. TYPE OF WELL: ofL GA8 q'F.LI. ^ WELL D$Y Other '~ b. TYPE OF COMPLETION: rraG nlsF Form approved. Budget Bnresu No. 42-R365.6. j, LEASE DESIGNATION AND SE$IAL NO, None 8. N INUFAN, ALLOTTEE OH TRTBB NAME N/A d. UNIT ACREEAfENT NAMD N/A NEwT Q ~~ Rrt ^ ENi r ^ RACK ^ r.PSVR. ^ Other S. FARM OR LEASE NAMD 2. NAME OB OPERATOR NavalPetroleumReserveNo.4 ~" Husky Oil NPR Operations Inc. 9. WELL xo. 3. ADDRE83 OF OPBRATOR So. Barrow Well No. 13 3201 C Street, Suite 600, AnchoraP ~e, AK 99503 la. BIELD AND Pool, oR WILDCAT requirement~)' 4. LOCATION OF WELL (RGport Location edeardy and in accordance with ang $tate South Barrow Gas Field ... ~ At surface 8d7 ~ FWL ~ 552' FSL, Sec p 14, T22N, R18W 11. SEC., T., R., M., OR DLOCK ANP SURVEY OR AREA At top prod. Interval reported betow i-• At total depth Sec 14. T22N. R18W 14. PERMIT NO. DATE 1SSCED 1Z. COUNTY OR I3. BTATE PARISH ( N/A ~ North Slope Alaska 1rJ. DATE SPUDDED 1S. DATE T.D. REACHED 17. DATE COMFL. (Readp t0 prod.) jg. ELEV ATIONB (DF, RKB, RT, GR, ETC.)• 1S. ELEV. CA3INOHEAD 12/17/76 I 1/2/77 ( Suspended 1/17/77 ( Grd: 22; Pad:. 26- KB: 40 26' ZO. TOTAL DEPTH, YD A TVD 21. PLUG, MACH T.D., MD d TVD ZZ. IF AIULTIPLE COMPL., $.$. INTERVALS ROTARY ?GOES CABLE TOOLB ~ HOW MANY• DRILLED BY 2534' MD 2474' MD -~ ~ A11 24. PROUIICING [NTERVAL(S), OF THIS COAL FLETIUN-TOP, BOTTOM, NAAfE (MD AND TVD)• rr 26. TYPE Ei.ECTRIC AND OTHER LOGE RUN DIL/BHC Sonic/FDC-CNL-GI YV' SURV EY~MADE -.^y 27. Wa3 WELL CORED i,.. 2R. CASING RECORD (Report aid atrsnga set in weld) CAS1N0 SIZE WE[O HT, LR./BT. DEPTH SET (MD) HOLE SIZE CEMENTING RECORD AMOUNT PULLED 10 3/4" 51 1157' 14 3/4" Cmt to Surf w/760 sx PFII 7" 32 2514' 8 1/2" Cmt to Surf w/805 sx _ PFII; tail in w/80 sx Class "G" w/2% CAC _ ZS. LINER RECORD 30. TUBING RECURD SF2E TOP (MD} BOTTOM (MD) BACKS CEMENT• SCREEN (MD) SIZE DEPTH SET (MD} PACKER SET (MD) 31. PERBORATION RECORD (lnservai, afse ana ntimoer~ 32. ACID, 3IIOT, FRACTURE, CEMENT SQIIEEZE, ETC. ,,,, Selected intervals have been perforated DEPTH INTERVAL (MD} AMOUNT AND KEND DF MATERIAL USED with 4SPF, Hyperjet II. _ - ~ 33.• PRODUCTION - DATE FIRST PRODUCTION I PRODUCTION METHOD (Flowing, Daa d{Jt, pasping-siae and type of pump) I WELL BTATUB (Prodaotng Or l{I shpt-in) - DATE OF TEST ~ HOUR9 TESTED ~ CHOKE 812E f TREOBT'N. F~ ~ OIL-BRL. ~ GAS-ATCF. I tN ATER-BBL. ~ GAS-0[L RATIO FLOW. TUBTNO PRESS. CASING rRE39CIIE CALCULATED I{ OTL-RAE. GAS-MCF. WATER--RBL. OIL GRAVITY-dPI (CORB.) +e.., ~ Z4-RO(:R RATE t _ _ -~-> 34. DISP03TTTON OF OA9 (SOdd, need Jor fined, Uerited, etC.) ( TEST WITNESSED BY °M 38. LTRT OF dTTACH AtENTB None. _ 36. I hereby certify that the foregoing and attached information Se complete and correct ae determined from all avaiinble records ... SIGNED John M. McCarthy TITLE Drilling Engineer DATE January 28, 1977 *(Se¢ Instructions and Spaces for Additional Data on Reverse Side} „~, 4 2 `-- inrr" 9-331 Jta l91• UI`!1 T ED ST:tTc3 A~~~ di:?ART'rtcNT OF T'ri= [DtT~RiOR GEOLOGiC~L SiJRyEY SUPiDRY (yOTICES rV~ID rZcPOr'~T5 Oy V~tcLLs i~fervai-~Uu Feen+ 9~331~ ~ ••cM ,ueV~il to ~ «w er Ww[ bat's La s diM~ew+t I. well ^ vgreil ® other `° 2 NA:AE OF OPERATOR 3. ADDRESS OF OPERATOR 9. vte'LL NO. So. Ba3zow No. I3 10. FlELD OR WILDCAT NArWE South Barrow Gas Field II.. ScC., T„ R., ?A.. Oe~ BL.K. ANO SURVEY OR °P' R, LOCATION OF WELL (REPORT LOCATION CLEARLY. See spew 1T ~~ below.) 14 T22R ffi.841 AT SURFACE: 907r FWL b552~ FSL 22. COUNTY ORPARISIi 23. STATE AT TOP PROD. INTERVAL- Ro. Slope Boron , Alaska ~... AT TOTAL DEPTH: 14. RPI NO. 26. CHEt.K APPROPRIATE BOX TO INDK:ATE NATURE OF NOTICE, ,. ' ~Q008 REPORT, OR OTHER OATA L'f. ELEVATIONS (SHOW DF_ K08, AND Y1D) REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: Grotmd ~ 22 ~ • Pad _ 26' • Tait - ~ 44' TEST WATER SHUTOFF ^ l..! FRACTURE TREAT ^ SHOOT OR ACtDiZB Q REPAIR VYELL ^ (trOT~ IlipaR raant:- al InrdtlpN de~Yar or zaws .~. Pt1Ll OR ALTER CASING ,^ Q daweroa one 4-3m3 MULTIPLE COMPLETE Q Q vliANQE ZONES Q ^ ABANDONS Q ^ (other) Pzoaress rettort. 27. DESCRIBE PROPOSED OR CObIPLEI'ED OPERATIONS (Clearly stela all perti>tsert details, and give pertinent dates, indadin; estimated date of snrtir+g any proposed work. if-well is directionalip drlited, ;ieo- subsurface toptioas arM messund and true vartftai depths for ail marlues and nines pertinarLt to this work.) 12/17/76: Spudded well at 10:00 p,ta. 12/23/76: Drilled 14 3/4" hole to II66. Rea DII., B8C/SoaicrGRJCAL. .y~ Rea 10 3/4" 60.70# P~1I0 casiag~to 1257. Cemented :o surface J~ v/760 sa PsrmafFOat II. Full cem~t rettsras to surface RecErven ,,,,, 12/25/76: Ripple up stack. Tested casing and stack to 3SOt)#. OEPU7Y MINERALS MANAGER 12/26/761 Drilled 8' 1/2" hole.. aasNOaE wElo oPERAnoMs 12/27/76: Core #1, 2159-2189, 1002 recovery. 12/29/76: Coss ii2, 2189-2219, 97x recovery. .i.~~11 II I9$3 12/30/76: Core ,53, 2288-2318, 100x recovery. "'~ 12/31/76: Core #4, 2318-2348, IOO:L TeCOVery, MINERALS MANAGEMENT SERVICE tit W. <TM AVE., SURE ZA 1/1/77: Core ~f5, 2410-2425, IOOx recovery. ANCHORAGE. ALASKA 94;01 1/1/77: Drilled 8!~" hole to 2438'. Ran DIL, BHC/Sonic/Glt/CAL and FDC/CRL/CAL. (See cwatinuatioa attachedi "~ Subsurfaw Safety Vatvx Menn. srLd Type Set ~ ~,~_ Ft, 28. ! hereby mortify t the regoing is trot arLd correct slerleo( • ~L Drillia8 MSr o;,~ / _6 - 7 b - V/,7~,/~ ~ i apaq~rx_f~WI arN w StsN o!~lil~* v-sd- ) /J p //Q A?PROVlD 9Y ~~ ~' /-~t,.G~~-T}~,g_ `~~~Ji~ ~~L pA~ (/ ~~7! d CONQLTIOMS Qf APMIOYAI~ IP AMY: '°~""_ 77--"~~~ .,~, This amends original signed 1/6/76. Amended 1/14!83 •S,alnshVetlern on R.vee,e Side 7 . `~ Perm AA?row0. $'lE..^.Y. BYSfiY K0. +2~?.:S{3 S. LEi.SE t% fF INDIAN, ALLOFI`EE OP. TR18E NA:ac 7. UNIT AGREEMENT NA.LIE 3. FARM OR LEASE itAl6e r~ Item 17 continued: ~~ 1/2/77: Drilled 8~° hole to 2522`. Core #6, 2522-2534`, 25X recovery. ~' 1/3/77: Ran DII., BHC/Sonic, FDC/CNL, Mpmeter from TD to 2534. Took 24 sidewall cores, recovered 17. 1/4/77: Ran 7" casing H 80 32~ B-3, C-I, 8BD to 2514. Cemented w/8O5 sx Permafrost II, tailed in w/80 sa Class G 2X CaC12 PuII cement '~"~ returns to surface. This report 38 (~NFIDENTSAL and is filed for information purposes only. .~. IIECEIVCo DEPt1TV MINERALS MANAGEt ,~„ ONSHORE EIELD OiERA71ONS .!fi~N I ~ ?983 MINERALS MANAGEMENT $ERVIGQ r ~l t tv. <iH AVE., SUITE 4A ANCHGRAC,E, ALASKA 99.`.01 rr ~+ w .... • ' "'' - a_, 3 3t m ~ F. 23 N. _~r -i ~ --i ~ T~ ~'? ~ ITT. 22 N. f ! ! I 1 I I I ( t f 4 I 2 1 2 1 F 6 1 S I I I 1 I I 1 ( i { 1 ~-------~------~-------t------- ------L-------I I I I i I I ! I ~ t I I t 1 s 4 a I rr t !z r I s I t I I I I 1 I i t I-------~------ 1 ------1------ ------a--------~ ~ I j r4 f ra ~ I 1 I ! I ~ I 1 F I i6 1 !3 l it ( 14-41111t ra I rT I 1 i (~ `SOUTH BARROW No. f3 1 ( 1 I ~/ LAL = 7 i° I S~ l 3.84" I I ( I eoT'---.t CCQ$~""~~--- [_pNG.=156°37~40.4t" l-------r-------~ ------«------- ------~--------~ X= 661,513 I ` Y=6,310,250 I E ~ l 21 ' 22 ~ 2D i 24 t9 I 20 I I I I ! i 1 ~------~-------~-------r------ ------t-------~ i I 1 1 1 1 1 I ~ ~ i 1 1 ` 2• 4 2T ( 26 ( 20 30 1 - 29~ 1 1 t ! I - I t t I 1------•~-- -----1-------1--- -----~------~-------~ SCAIEj i" = I PILE CERTIFICATE OF SURVE70R 1 hareby certify that 1 am properly registered and •'•.• i.~r '{,"~~ licensed to practice Land surveying in the State of Alaska and ~ •=~'.• ='.~ that thls plat represents a location survey made by me or 'y ~ ,~ _ `" ' ..~~_ ' under my supervision, and that all dimensions and other "y ~ ~-, .? '' /.i -••`-~ • ,•°" details ore correct. (f /{/~/./ ~J~{~ Y .' ... Qate SURVEYOR 15 1 9PERR Y~S UN NEIL SUR VEYING COMPANY.,_:....__~__..__... _._._. _._. .... PAGE 1 _ • ANCHORAGE. ALASKA HUSKY U1L NPR+4 OPERAT IONS DAZE OF SUR VEY JANUA RY 14 1977 SOUTH HARROW 13 COMPUTATION DATE 9URW EL GYR U BCOPIC MU LT ISHUi SURVEI( SuuTH BARNOw GA9 FIELD _ ~ ~ ~ JANUARY l7 1973 _ ~ ~~~ _ __ _ _ ~"~JpN NUHliEK 9U3~Iblgq ALASKA KELLY BUSH ING ELEV. a 40.00 fT, TRUE 9Utl~SEA COU RSE COURSE DO GLEG TOTAL. MEASURED VERTICAL VERTICAL INCLINA TIO N DIRECTIO N .,9EY EHITY __RECTANGULAR „GUDRDINATE ~ 9, . VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DE G/100 NORTH%BUUfH EAST/wE3 1 SECTION 0 ,, ,00 +40.00 . .__ 0, 9 . ..8 ..0...4 F _ _ . _..~~ _~_..__._. 00 V •44.. ~~ _ _ _.. _ _.. •Q0. .. 100 :100.00 60.00 0 29 9 5S, 8 E ,48 ,24 9 ,35 E •,33 200 199,99 159,99 0 35 8 q0, 5 E •17 •87 S 1,02 E +,96 300 i .299,98 259.98 i 20 _ _ S 4,96 E rgz. __.._.^:z~p2_S~,_ ~._ _1~aS E •1.Z9 • 400 ~ 399,94 3S9,94 ! 40 8 0,37 N ,'#6 5,03 8 1.54 E +1,2! 500 499.89 459.89 2 3 S 8,66 w ,47 8.26.8 1,26 E +,72 600 '; ~ ;599,81 SS9,81 2 24 S .2537 W . ,~79 . __„__._, l.l!_98_S ,, ~_ ,Ob E •72 '~' ?00 .699.65 659,65 ... , 3 , 5q _ 8 45,11 . N . l.f~ jb,#q 8 ~ #,28 w 4,33 800 799,28 759,28 5 4S S 52;25 N 1.94 21,8! 8 9,65 W 11.04 900 098,53 858.53 8 15 _ 9 64,bq 3 W .. 2;91 $ 3 27 95 S `""'#- b7 8 ~~~ 20,09 ~~- 36 13 N w 21.86 38 27 1000 997.03 957,03 11 3N S 2 72, w ,S , . . ~ 1100 . f094,4S lOS4.45 14 29 S 77.81 w 3,17 39,75 8 57.91 w 60.31 tv 1200 ~ 1191.31 1151.31 t4 20 9 79,67 w ,44 446! 9 . . . _ _ ~ . 82.31 . - w 85.03 ~"~ 1300 1288.21... 1248.21 14 l5 9 80.51 w _. . _. ~2q _ ~ _ . . __6d ~b~ _ 1bb:b3 it fo9.Se 1400 1385.19 1345,19 I4 .0 9 81.49 w .3q 52.66 8 130,74 w 133,88 iSp0 1482.26 1442.26 l3 49 9 83.75 N ,57 55,75 S 154.51 w 151,84 1600 1579.48 1539.88 ~13 15 8 87.21 W _. _.. 44 _ ____-57.61_5_.._-.. __-.171.84 w 181.25 1100 1676.92 1636,92 l2 44 9 89.50 w ,73 58,26 9 200.35 w 203.71 1800 177q:4b 173q,46 12 q4 N 85,89 N 1,02 57 S _ 57, 222,36 ~-~ w 225.63 1900 1871,91 ~ ld31,91 13 10 N 82,26 w ._ ,42 _ _ _ __ 2A4,bq ' ~S,~b 8 ^"~ w 241,71 2000 1969,25 !929.25 t3 20 N 79,62 N ,85 51.43 9 267,23 w 270.01 2100 2066,61 2026,61 13 5 N 7567 w ,72 46.36 S ~~ 289.50 - W 291,90 2204 21b4,Oq 2124,04 12 5S N 74, 8 w '-~,34 ~ ~ ~40,b4 5 311.22 N 313.19 2300 2261.62 2221.62 12 20 N 71.76 w ,77 34,08 9 332.11 w 333,62 2400 2359.47 2319.47 11 29 N 73.78 W W ,95 S _ 27.96 9 '~'4~~ ~ 3 351.81 _ 365 $11 w W 352,88 ~ 366 65 • 2475 2433.02 2#93,02 11 5 N 73,20 , S , 2 . , HORIZONTAL DISPLACEMENT ~ 366,65 F EET AT 8OUT H~ Bb pEG, 16 MIN. WE51 AT MD = 2475 THE CAL CULATION PRUG EDUNE9 ARE BASED UN THE USE OF THREE DIMEN SIQNAL RADIUS OF GUHYATUR E METHOD, I . ~ ~ ! ~ , ., . P a I" ., . ~ ~ . ,. F iii `_ _`" E~ _ .. .,a. 9PERRY-SUN WELL SURVEYING COMPANY PAGE 2 ANCHUHAGE~ ALASKA "' HUSKY OIl NPR-4 OPERATIONS DATE OF BURVEY JANUARY !q 1477 S~1UTH BAItROw 13 COMPUTATION DATE 9URWEL GYROSCOPIC MULTISHOT SURYEY SUUTH BANHOW VAS F1ELp JANUARY 17 i477 _ _ Jed"NUM~EIt SU3~ibiga ALASKA KELLY BUSHING ELEV. s 40.00 FT, ALASKA _ ..... _ ._. ._...~( rCQ ~uSiiIFIG"7:LEV.~.~_._NG,0.0.F`1~. ._ INTERPOLATED VALUES FUR EVEN 1000 FEET OF NEA$UREO~'DEfITF~ ~ -__...._...._... - " ' ~ ' " TRUE 9U8-SEA TOTAL MEASUNEU VERTICAL VERTICA RECTANGULAR COORDINATES"~ _ _ __ .._. _. IiD+~Yp _..~ Y~R~I~AL' ~ ~ ~~"~~~ . DEPTH DEPTH pEPiH NORTN/SUUTH EAST/WEST DIFFERENCE CQRRECTION ...... .. _....._ ._...~~_ _. 0 ,00 -80,00 1000 997,p3 957.03 3q, 07 S 3b, 13 W 2,97 2.97 2000 19b9.25 1929.25 Sl,g3 S 267,23 W 30.75 27 ,78 2g7S 2433.02 2393,02 23,79 S 3b5,eA N -~ _ ' ~ 41-,49; _.___. i~.•~3._ __._ THE CALCULATION PROCEDURES ARE BA9EU ON THE U8E OF THREE D IMEN9IQNAL RADIUS OF CURVATURE METHOD, • ..« ... WELL BORE SCHEMATIC 0 500 1000 1800 2000 2300 3000 PERFORATIONS I/6177 /NTERVAL SPF 2224 - 34 4 2315 - 30 4 2330 - 45 4 2358 - 68 4 REPERFORATIONS t/14/77 2224.5 - 34.5 4 2315.3 - 45.5 4 2386.5 -76.5 4 23@3 - 87 4 43 20" AT T4` 20", f33# , K-55 CSG. CMT. TO SURFACE W/ 150 SACKS PERMAFROST. t2/f@/7E -0-3/4" AT 1157' !O-3/4°, 5f # J-55 CSG. CM T. 717 SURFACE W/780 SACKS PERMAFROST f2 /22 / T6 -7/8" TUBING A7 2394' !-T/8", 6.3 # , N-80 TUBING. f/IS/T7 '. B.O. 2514 ` K8 ` " AT 2514` ", 32 #, N-8'O CSG. ;MT. TO SURFACE W/ 805 SACKS 'ERMAFROST. TAIL IN W/@O SACKS 'LASS G° W/ 2 % CoC1=. D. 2534` K8 SOUTH BARROW NO. t3 BO T' FWL. ANO 552 ' FSL. SECTfON /4, T22N, Rl9W , UM. Pq0 LEVEL 26`EST KB 40 ` EST. HUSKY OIL AI P. R. OPERATIONS NAVAL PETROLEUM RESERVE N0.4 • .....- CASING ~. Programmed casing for South Barrow We{1 No. 13 was 20" conductor at ±40', 10-3l4" at 1200', 7" at 2500', and 2-7/8" production tubing if ,,,~ required. Casing actua{ly run was 20" conductor set at 74', 10-3/4" at 1157', and 7" at 2514'. The 2-7/8" production tubing was run to 2394' and hung in the 7" casing when the well was completed. 33 STATE OF ALASKA ALAS . LAND GAS CONSERVATION COME ION REPORT F SUNDRY WELL OP ATIONS 1. Operations performed: Operation shutdown ^ Stimulate ^ Plugging ^ Perforate ^ Pull tubing ^ , Alter Casing ^ Other ^ 2. Name of Operator ~ 5. Datum elevation (DF or KB} North Slo e Borou h CH = 261 KB = ~ Feet 3. Address 6. Unit or Property name 3201 "C" Street, Suite 602 Anchora e Alaska 99503 S uth Bar w 4. Location of well at surface 7. Well number 807' FWL & 552' FSL, Sec 14, T22N, R18W U. M. Alaska SB #13 At top of productive interval 8. Approval number See Attached Sperry-Sun At effective depth Directional Survey Report 9. API number 50- 023-20008 At total depth 10. Pool 443' FWL & 492' FSL, Sec. 14 T22N R18W U. M. Alaska South Barrow 11. Present well condition summary Total depth: measured 2534' feet Plugs (measured) true vertical 2491' feet Effective depth: measured feet Junk (measured} N/A -true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structura- Conductor 60' 20" 150 sxs. Perm. 741 74' Surface 1153' 10-3/4" 760 sxs. Perm. 1157' 1150' Intermediate Production 2514' 7" 805 sxs. Perm. 2514` 2471' Liner 80 sxs.. "G" Perforation depth: measured 2224' - 22351 @ 8 SPF, 2315' - 2346' @ 8 SPF, 2356 ` - 2358' @ 4 SPF, 2358' - 2368' @ 8 SPF, 2368 - 2376 @ 4 SPF, 2383' - 2387' @ 4 SPF., true vertical 2184-2195, 2275-2306, 2316-2318, 2318-2328, 2343-2347 (Interval SPF as indicated above} Tubing (size, grade and measured depth} 2-7/8", 6;#, N-80, 2384' tally, set @ 2394' rID RE~~~ Packers and SSSV (type and measured depth} No packers or SSSV employed . s ~~;. 12. Stimulation or cement squeeze summary See Attached Report. ~, Intervals treated (measured} 2224 - 2387 feet MD BKB Barrow Sandstone ° ~ ~,c~~[age Treatment description including volumes used and final pressure See attached report by Halliburton 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation No prior production history Subsequent to operation - 0 - 350 - 0 - 525 - 14. Attachments Daily Report of Well Operations CBS Copies of i_ags and Surveys Run i~j/'~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Date / Form 10-404 f~12-1-$5 " ~/ Submit~rfi Dt~5licate ~1 L t.Itf U ti 1 u l~f JC ft Y 11r Ctl o,v,f,ow i.v5 to tyG1C5 ~.v.. u. .+~.v.x: ~RtNG SERVICE ~ATING REPORT .,,.,.resew 495679 ~ACTU T,CNtT NO. wY ~Ht/ R+a - -- -- WELL DATA South Barrow sec. Twp. ang. county North Slone star. Alaska ~atlon fvame TYW vi. rmatlon thickness From To ewf~we U 'ai Prod: Oil Rpd. Water Bpd.Gat_prtctd. a«ee ant Prod; Ott Rpd. Water Bpd. Garr_MCtd. Tv/,Ne L iatton Tool J{' Mandrof Slzs Extsnstont in. 01eN NOLe meter Type Sat At 1e e-owwT,ewf om bole Temp. RBP• /twlawwT,owf -= Or Flange Pbtd -Rw-owwTtoNa MATERIALS JOB DATA ,t. Fiutd Versa Gel Density 7.75 LbJGaf SAtJf spi. Flak! Nitrogen Density Lb./Gal SAP) .Type 51zs LD. Type ~~~4(l size ~~~4(1 Lb. 1 f14 aactive Tracer Carrier tJnlts-MCI rfauant Type SII"1-7 Gai. 9 •1000 Gat. ctant Typs Gal. • x1000 Gal. ~ - Loss Type Lb. 75 •_~/1000 Gat. Itfng Agent WC;-~ ~ samrt_b. 15(1 ® ~ /1000 Gat, ng Agent Gal.-Lb. ! /1000 Gai. ~ kfr Type Gal: Lb. • /3000 GaE. ker7ypa Gat.•Lb • v1000Gat. osslinker Gaf.-Lb ® _~ 1000 Gal. Iltzer Gal: Lb.__ • X1000 Gal. ~ erType ~CT'"3 2t7~t.-Lb 9 •~.l1000Gat. fferTyps K-34 ta3t..Lb 9 •~/1O04Gsi. tertacide Gal.-Lb,-.-.-• !1000 Gat. Foamer Gal: Lb •__~ 1000 Gal. Control Gal: Lb • x1000 Gat. vertex Gal.•Lb ! /1000 Gat. tlon Reducer Gat: Lb •_;1000 Gai. `psc Balls Qty. Size S.G. her a -..53 Cr1 '~ ACID DATA - ;,;,. ~,~ TYPe None x+ Gal:Bbl. _ - . Type % Gat.-Bbl. ~~ ;5 _ aetantType Gat. •__/1000 Gai.- - - ~ :~~~ a~~ ~rfactant TYDe ~ Gat. • __/1000 Gal. Agent Type GBt. • X1000 Gai. ~ _ Control Type Gat.-LD. " • X3000 Gaf. xroston inhibitor Gat.-Lb. • v1000 Gai. t irrntl at i nr~ - C i Dt-A/,TMewT roslon lnhtbitor __ Gat: Lb • /1000 Gai.,- ~~ Fy-ar. ~i fih '! (~4 sk ~fl l4~arx3 _, sefcwtlTrow ow Joe F king lnhtb[tor Gal Lb •._!1000 Gat. __ _ . -- - - Sequester _ Ga! Lb • X2000 Gat. ^ ~ ~ ~ ~` ~- - Tfa.twNw. cws,Ne ^ Awwuwf Nwu: Tveme ^ _ ~~ - - tlCttOn Reducer GiI -Lb 13000 Gal. Joe ooNw T - a PRESSURES tN PSt _ SUMMARY - VOLUMES _ _ , dating Dtsplacament lOSa =akdown 1200 Maximum 1400 age g00 Fracture Gradknt 5 Mln. ~ 050 10 Mtn. ~-15 Mtn. HYDRAUt.tC HORSEPOWER 147 sexed Available Used AVERAGE RATE !N BPM ling 5 otspt.29.00 SCfr~rerolt 5 stonier presentative Y S/R. Chdtxrlan __ es ested weNrtT f,fe F/10Y TO YAR,MVM 1ft wLtewwet.e 38 ~7 ~ 1 2514 ~ 2394 fNOT///T. CALLee OYT ON LoCATIOw JOe fTARTiO JOe COM-t.eTte eAa 3-15-8 A*~ 3-15-87 eA*t 3-20-$7 eATe 3-20-87 .~... 0800 T,we 1300 ~*~^ 1810 TrMe 1959 rERSONNEL AND SERVICE t1NITS - wAMt t UNIT NO. e[ TT1t t iOCAT10N _ R. Dickerman B7994 F En B. Carr 45859 51296 Z J. Jacks C0329. 3507 L_ Lnthactan B5694 2033- ~ 2535 t 5 Prefiush: Bbt.~t. 25 _ TYae 7~ CC Load ~ Bkdn: Bbi.~Caal. Pad: Scf-Bbt.~3at. Troatment:}@;FK~a1.. 3Q0(~ DisptsBbf.-Gat.,,.,?9~4~(1 Gas assist 29.400 Tans-set • 700 sef./Bbt. Foam Quattty 60 % Total Votums Foam 5600 Bb4-Gai. Total votumez Bbt.-Gat. 7502 t=tuts-Foam_ _ _ _ - REMARKS Halliburton s/BOb Carr Operator rDi" Y W w 0 1 v .,rte.. r.r.. ... v.. ..~... .~~.. Ni _ iJ LiAiA JV ~L~1 L[ Kwhi ., ~. -.~~u: ~~'8 lt~G CYiTOMtR North Slope Borough 1 of 1 -, ~Mi MO. poi Tr-i FOaRI FYdC oATS 3-20-87 CORM till bt NART RATt YOLYMti ' } -VM-t -wrsiuwa {-q' R i NO. TIMt ~R-Mt. iil' OAL T C TV iINO GAi1N0 IAL OtfGRI-TION OP O-tR ATION AND MATi 1810 1859. Pill 2" Line with Calciun Chloride water 1901 Test csg. valve to 1000 psi _• 1903 Close 2" to tare 1905 Test 2" to tore to 3004 si. 1908 Bleed Pressure back to 600 si 1910 500 650 Open csg. valve & 2" to tore 1910 I 1.15 500 750 Start pad with Calcium chloride water 1913 3 6.9 550 380 Pad 1915 2~ 11.8 560- 330 Pad 1920 2~ 570 360 Pad 1925 3-5 25,2 540 520 Pad 1935 40.9 1500 1250 I,S.I.P. 1943 1.5 2 1000 700 Start 2.5# Sand 1945 3 1000 750 2.5# 1948 5 1200 1150 4.5# 1949 5'~ 1200 1150 4,5# 1950 6 - --- 1250 1200 8,5# - 1951 6 1250 1200 8.5# 1952 5 38 -- 1250 1200 Go to flush 5 bbls Gel - -_ 1952- 1150 1150 Displace with nitrogen 2500 scf/min 1500 psi 1953 1150 1200 3500 scf/min 1500 1954 - - 1150 1250 3500 scf/min 2000 - 1955 1200 1250 3500 scf/min 2000 _ 1956 - ~~;. -1200 - 1250 3500 scf/min z0oa 1958 1200 1300 3500 scf/min 2000 ]959. _ _ -1200 1300 Nitrogen displaced -total N2 displaced 29400; 5t ~~ ~i ~~ ~~ ~' ~'~ ,` s I ,: 'J ~~ ,~ • A pressure buildup test was conducted for North Slope Borough Co., Well SB-13, Alaska, on 8/27/87. The fallowing are the results from the buildup analysis: Permeability thickness 71.9 and ft. Effective .permeability to gas 4.447 and Reported thickness 163 ft. Estimated reservoir pressure 631 psi Fracture half length xf 52 ft. The well was. not shutin long enough for semi-Iog analysis. AlI the calculations were based on type curve matchings technique only. Reservoir pressure was estimated from the buildup type curve. Physical properties of gas used in the calculations were from correlations. NL Sperry-SuNNL industries, Inc. • S®uth ~a~-r~w #13 ~~`ell Bore Schematic Bayed on information from AOGCC ~~i'ell History Well: South Barrow # 13 All depths are from KB (40' Elevation} 20" 133# Casing Cmtd at 74' in 26 "hole w/ 150 sx (cmt to Surf} 10-3/4" 51# Casing cmtd at 1157' in 14-3/4" w/ 750 sx (cmt to Surf} 2-71`8" Tubing hung at 2394' No Packer PBTD 2514' 7" 32# Casing cmtd at 2514' w/ 805 sx Permafrost cmt with 80 sx CI "G" tail wi 2% CaCl2 (Cmt to Surf} Well TD is 2534' Barrr~ti4 Gu Fields ~4'eli improvements Studi Fein ?00' Appendix t P~~`~e 23 of 4 9 too 26C aoo aco soo sco goo eao Sao looo ltoo tzeo 1300 1 A00 1500 ?600 7700 t800 1900 2000 z?oa zzGG 2sro 24GU Well: South Barrow No ~.~ Before P&A 20" 75# cmtd at 74' in 24" hole w/ 150 sx Permafrost Gmt (cement to surface) 2-7/8" E All depths are from KB (40' Elevation) 2-7i8" 7" 7` 9-5/8" 2-7/$" X ° 7" X 9-5/t 10-3/4" 51# J-55 cmtd at 115T in 14-3/4" w1760 sx Prmfrst cmt (cement to surface) 7" 32# N-60 cmtd at 2514' in 8-1(2" hole ~,vi805 sx prmfrst Lead and 80 sx Ct G tail (cement to surface} 2-7/8" Tubing hung to 2394' Perforatians Hyperjet (i Csg Gun //;-h/ ~~~+~ ~ ~ / ~ ~ 2224'-2235', 2315'-46', 2350 -76', 2383'-8T 8 spf j l ~ ~+ / Foam frac with 104 sx of ZO140 sand / ~ ~~~~ 8-tit" hole TD is 2534' ~; WELL HEAD DRAW/NG SOlJTH BARROW No. /3 GRAY LUBRICATOR ADAPTER 2 t2" 3000 MSP W/ 2 T/8" O. D. EUE 8 RD. LIFT THREAD GRAY GATE VALVE, ~~ 29/16" 3000 MSP, GRAY TEE, 21/2 3000 FLANGED ENDS MSP X 2 i/2" 3000 MSP ~ n ~~ GRAY TUBING 80NNET, 6" 3000 MSP X 2 I/2" 3000 fiRAY GATE VALVE, 21/16" MSP, WITH 4 - i/4" CONTROL 3000 MSP, FLANGED ENDS " LINE INTEGRAL NEEDLE WITH GRAYSAFE HYDRAULIC VALYES OPERATOR INSTALLED 6" 3000 MSP ' GRAY TUBING HEAd, i2" 2000 t~SP X 6" 3000 MSP X 2-2`FLANGED OUTLETS O GRAY"GATE VALVE, 2 Vt6 3000 MSP, FLANGED ENDS 12" 2000 MSP GRAY CASING HEAD, 13 3/8°~ t2~~ 2000 MSP S.WL X t2" 2000 MSP X 2-2" L.P, OUTLETS f3 3/8" X 10 3/4" ADAPTER --- BUSHING 10 3/4" CASING T" CASING 2 T!8" TUBING ATTACHMENT 7. Wellhead Details 44 GATE VALVE, 2 1l16" M3P L.P. ENDS ' SOUTH BARROW No. /3 807` FWL 81 552` FSL SEC. 14, T22N., R.18W.,U.M. PAD LEVEL 26~ EsS. SOUTH B~iRROW GAS FIELD ',HUSKY O!L N.P.R. Operations /!ra ~~ 1 1 1 1 ~:- L~ L I= W~~.x~w scx~a~ze ATTACHMENT 7A. 39 Wellhead Details ~ ~ • ~- IDENTIFICATION OF WELLHEAD SCHEMATIC PARTS 1. HEAD, CASING, LOWERMOST, TYPE 'S-3', 9-5l8" FEMALE SLIP-ON BTM. x 10" API 3000# FLANGE TOP, W/TWO 2" API L. P. S.O. , 10" BOWL, API -75° SPECS 2. PLUG, BULL, SOLID, 2" API L. P. MALE THREAD, API -75° SPECS 3. NIPPLE, PIPE, 2" API L. P. MALE THREAD BOTH ENDS XXH, 6" LONG, APR -75° SPECS 4. VALVE, GATE MCEVOY MODEL 'C', FIG. i20, Z" APf L. P. FEMALE THREAD ENDS, FULL PORT, RM-13 5. HANGER, CASING, TYPE 'SB-3', NON-AUTOMATIC, 10" BOWL x 7" O.D. CASING, API -75° SPECS 6. GASKET, FLANGE, API #RX-53, 3i6 S.S. 7. SET, STUDS & NUTS, F/10" API 3000#, API -75° SPECS 8. HEAD, TUBING, TYPE 'SL-1', 10" API 3000# FLANGE BTM. x 8" API 3000# FLANGE TOP, W/TWO 2"API 3000# S.S.O., W/VRT, APf -75° SERVICE 9. PACKOFF, CASING, TYPE '-1', 10" FLANGE x T" O.D. CASING, API -75° SPECS 10. GASKET, FLANGE, API #RX-24, 316 S.S. 11. VALVE, GATE, MCEVOY MODEL 'C', FIG. 125, 2" API 3000# FLANGED ENDS, FULL PORT, RM-13 12. SET, STUDS ~ NUTS, F/2" API 3000# FLANGE, API -75° SPECS 13. VALVE, GATE, MCEVOY MODEL 'C', FIG. 125, 2" APi 3000# FLANGED ENDS, FULL PORT, REVERSE ACTING LESS 80NNET >; STEM ASSY., RM-13 " 14. FIG. 125, RM-13, ACUTATOR, VALVE, BAKER, HYDRAULIC, F/2 VALVE COMPLETE W/BONNET ASSEMBLY 5 MANUAL OVERRIDE 15. FLANGE, COMPANION, THREADED, 2" APf 3000# x 2" API L. P. FEMALE THREAD, APf -75° SPECS 16. PLUG, BULL, TAPPED, 2" APl L. P. MALE THREAD x 1!2" NPT ' FEMALE, API -75° SPECS 17. VALVE, NEEDLE, ANGLE PATTERN, 1/2" NPT MALE tNLET x FEMALE OUTLET, API -75° SPECS ~~ ~ ~ ~ ~ 1$. GAUGE, PRESSURE, 0-3000#, i/2" NPT MALE THREAD INLET, AP! -75° SPECS 19. HANGER, TUBING, TYPE 'SlA-3', 8" BOWL x ONE STRING 2-7/8" EUE TUBING x FOUR STEP COUPLINGS F/1/4" DHBV CONTROL LINES, API -75° SPECS., COMPLETE WlWRENCH FOR PST COUPLINGS 20. NIPPLE, PACKOFF, TYPE 'PST', 2-7/8" EUE MALE x Z-1/2" NOM., 21 API -75° SPECS., WlWRENCHWG SLOTS GASKET API #RX-49 FLANGE 316 S S . , , . . , 22. ADAPTER, TUBING HEAD, DOUBLE STUDDED, TYPE 'PST', 8" API 3000# BTM. x 2-1/Z" APt 3000# TOP, W/2-i/2" PST POCKET >; FOUR 3/4" NOM. PST POCKETS F/DHBV LINES, W/FOUR 1/2" NPT FEMALE TAPS ON FLANGE O.Q. 90° APART FOR CONTROL LINES, COMPLETE W/FOUR 1/2" NPT NEEDLE VALVES, API -75° SPECS 23. GASKET, FLANGE, API #RX-27, 316 S.S. 24. VALVE, GATE, MCEVOY MODEL 'G', FIG. 125, 2-1/2" API 3000# FLANGED ENDS; FULL PORT, RM-13 25. TEE, STUDDED, 3000# W.O.G., 2-1/2" x 2-1/2" x 2-1/2" API 30~# W/VR7 IN OUTLET, API -75° SPECS 26. SET, STUDS ~ NUTS, F/2-1/2" API 3000# FLANGE, API -7S° SPECS 27. TOP ASSEMBLY, TREE, 2-1/2" API 3000# FLANGE BTM. x CAP TAPPED 1/2" NPT, W/2-7/8" EUE LIFT THREADS, API -75° SPECS 28. VALVE, NEEDLE, GLOBE PATTERN, 1I2" NPT MALE THREAD fNLET x FEMALE OUTLET, API -75° SPECS 29. GAUGE, PRESSURE, 0-3000#, 1/2" NPT MALE INLET, API -75° SPECS , 30. FLANGE, COMPANION, THREADED, 2-1/2" API 3000# x 2" AP! L. P. FEMALE THREAD, APl -75° SPECS ' 31. PLUG, BULL, TAPPED, 2" APf L. P. MALE THREAD x 1I2" NPT , FEMLE, API -75° SPECS 32. VALVE, NEEDLE, ANGLE PATTERN, 1/2" NPT MALE fNLET x FEMALE OUTLET, API -75° SPECS 33. BACK PRESSURE VALVE, CiW, TYPE 'H', 2-1/2" NOM. 34. TESTER, B.O.P., 10" TYPE 'S' OR 'SL` BOWL, 4-1/2" IF TOOL JOINT TOP 35. TESTER, B.O.P., 8" TYPE 'S' OR 'SL' BOWL, 4-1/2" IF TOOL JOINT TOP 41 1 LJ • • 36. PROTECTOR, BOWL, F/10" TYPE 'S' BOWL 37. TOOL RUNNING & PULLING, F/10" BOWL PROTECTOR 4-1/2" IF TOOL JOINT TOP 38. PROTECTOR, BOWL, F/8" TYPE 'SL' BOWL 39. TOOL, RUNNING E PULLING Ff8", BOWL PROTECTOR, 4-1/2" !F TOOL JOINT TOP 40. PLUG, VALVE, REMOVAL, TYPE 'A', 1-1/2" L. P. Ti-lREAD, F/2" OUTLETS ~z • ATTACHMENT 8. Tubing and Casing Details . ate'-sat Q - --_- - - - _ _ G - - - },, j ',• U1'~D STATES s~'~ ~ D`~ "_" aodsaee°e°°,~ 0. ix:-Rass.s. _ tnerls• DEPARTMENT OF THE tl~lTERfOR ,(ntt~nr «~ LEaA! DCBICRATIOR .YD [IESraL Iw. s revere .~, _ - s - GEOLOG fCAL SURVEY _ - _ N/A - - - - WELL ~OMPIETfON OR R~COMPLETtON REPORT -AND LOG * ~ ° It(DLL2r. ALLO?TES os Tats.`,1AMa j N/A = = -- - 2a. T E W L oIL cwa- --- . _ ast,L ^ IrsuL ® vet ^ Other 7. gt(tT;ACUCMSxT RAI[Z! _ - h. TYPE OF COMPLETION: - ~.. T N /A = - xsw woes orsr- rl.ac Dtrr. WELL ® OVt6 ^ LS ^ 6ACS ^ GSSVIL^ Other ~ ~ ~ $. rAax. os'L.EAas aaxs atioaa z. xAMe or ossa.roa ~ t ~' petroleum Reserve'.~II AK . USGS through Husky Oil NPR Operations, Inc. ~ - - ° BELL x_°= - _ _ - 3. ADDatss Dr-OPLRATOB - ---- --- - -- -------- . So. Barrow We12 No.=• I5 2525 C Street , Suite 400, Anchorage, AR 99503 = ~ lo =nstDFasD soon or_wtsoc.T 4. LoeArlox o. IrtLL (Rrporr tDaa:Ise v~rty aRd in accordance (oitA any sea a reQairerneets>• So. BatroGl Gas. Ffeld At surface 2640' FEE; 990' FNL 21. asr.:'z. 6-. M., oe sLOCIt axDSattvet - ~' n ~ ~ At top prod. tntervat reported be4tr € _ f S+ - , At total depth Same (straight hole) ~ 23;-- T22N= _RllW,' UM Sec 24. rsaYlT xo. DArs tssasa 12.-Conan os - 1S. sTAxs= .. . - - - - _ _ ---- : - - N/A = __ . -~-- _- - 1- =.N/A North ".Slope orotigh, AR 25. DATE 6PO DDCD 28. DATt T.D. a6:aCRED 2i. DATE COY PL (ready t0 prod.) 18, ELLVATION8 (Dr, sKS, aT,•CS, CTC.)~ I9. ELBV _CaaT.lOasAD 8/23/80 ~ 9/i/80 ~ 9/10/80 ~ GL-7; Pad-12'; KB-30' :'_ ~ ~ 12 `' _ ' '= _~ YD. TOrwL Dora, Yn a rv Yl. rLma, sack r.D., Ma a TvD 22, tr xcLrlrt.e coxrL., 23. tKrsaVAL6 BOTSaT. TOOLS - =CAres- TOOt.B 2278' TVD & MD ZI70' HOW MAxr• D6lLLLD ET ~ ~ ~ ,= ~ - N/A -•- `' -~. f ~ Rotary' `~ ;: ~ _ "L4. PRODCCI:(a I:(IERY A4(S j. Or TSIS ODHPLST[Oa-rOP, DOTTO Y, ~A~(Y (IID AFD TYDj~~ - - _ f.7. w~a uur~iw.. •,. _ - ,. _- iaZYET; MADE - J - .< - _ - - 2454`-2064' and 2110'-21ST' 1~ & TVD, Upper Barrow Sands - , - _- ~. -_ = - ' -- - ~`'" 28. TYPE ELECTRIC AxD 078E6 LOGS Zito - - .. 27. WAE WELL COBLD {:. DLL/MSFL/GR, FDC/CNL/GR/CAL, BHC/GR, DIP, MLL - = - Yes '~ _ `~-' 23. CASING RECORD (Report aU ttringe iet fn (Derr} -. - - - . CAS[SO a1LL wLIO RT. LB./Trl. DEPTR EET (YD) ROLE 6ILE Cta(ExTISa REC06D•~ A?(OatIT PULLED 13 3/8" 72~, 5-95 80' ICB 17 1/2" " 230 ~Sx C1 G to Surface: None - 9 5/8" 53.5 S-95 1514' KB 12 1/41' 1500 Sx Permafrost Rtrns None-.~ 7" 38~ S-95 2298' KB 8 1/2" 90 Sx G1 G w/2X CcI~ ~- None-~ 50 Sx Downsaueeze 2d-Stag None __' 29. LIItTBB RECORD 30. TCBINO RECORD ". - -- - Bt2L TOP (MD) T10TPOY (YD) SACta CEY LYT• 9CREIx (YD) S(ZII DEPTa 8ET (YD) PACHat iET (MD} 2 7/8" 2155'= RB NlA. ` i - -- --~ 3i. ezaroaATlox aecoaD (Inttrva3, aatR aswd n,unber) gZ ACID, SHOT, FRACTURE, CEMENT SQQEEZE. ETC.. - 2054' -2064' ; 2110' -2151 ~ Dora t~aeveL (MD} AYOI-xr AxD etxD or' x.TSBtat assD - w/4" 'Hyperjet II Casing Guti' . -__ _ .. _ - - _ - . . ~;~l~SVN~~ JUL 2 3 2008 - - ~ - :. = ' 33.• PRODUCTION __ - p,-rz treat rtooaCTlo~c PsoDOCrtax MLrROD (Ftoloi+(p, pea ttJt, pvrnpinp-ei:a and type of pvn(p) - wsct arart:s (Prvd+(e[nq,or _. _-.-. - _ 9/ 17(80-- - - __ _ ~ Gas -- __- _- _ ~ - - = ~ - ekat-tn) _ - Sh - . _- . - ut ~In DArz or zest aocss rasrsD csoss 61zs PROD'R. rob Otlr-664 ~ WASLB-BBL; CA6-HCF. CAE-0IL tAT[O 9/17-18/80 36 it ~ 1/8-5/I6 raT resloD ( © .. 1 ( -~ ` -250 MCFD ( 1 ~ - .. ~ = 0" -=: N/A -' ~• - _ rww. Tas[It0 rasaa. CASi~a P6L88Ca6 CALCa WTLD OIL-B6L GA8-MC7. wATEa-66L. O[L aL~VITT-a!t (COBB.} 2!-aoaa urz "'~~' ~ 0 tt t f { 1.0. MMGFD I 0 - ~ `: ~ ~ ' " - ~ Q := ~ , ~ _. ~ . 34. Dlstrostnos or oss (Sold, wa Jor jBel, vented, cto.} _ tsar wtr~essaD sz =- .-- Flared ~ - ~ H. ~ M. Peterson: ~= - 35. Lur or ATrACHMtYTa - _ .e - .. We .. _ ~ _ __-_-- 38. F hereDT t1t that the for of - d attached lnformatlon L complete and correct.. as determined from alt avatiaDie records ~ stcrrro - ~~ Chief of Operations, ONPRA _ -DS~ Fj'c '(Sec Instructions and $pocu lot Additional Data on Reverse Side) ~CHRtSTMAS TREE . ` '~ • O j ~ ~ ~_ ~ '' 13 3/8" CONDUCTOR a1 80` CEMENTED TO ~! ! SURFACE WITH 230 SACKS OF CLASS G 200 400-1 i+{ 1 1 t 1 1 1 6001 600 --~ ~ }:: 1000 ARCTIC PACKED 9 5/8"x 7° . ANNULUS THROUGH F.O. of 1180 1200 7" F.O~s at 1180` A 1300` t400~ DOWN SQUEEZED 50 SACKS OF CEMENT THROUGH F.O. of 1300. 600 9 5/8° at t5t4`, RAN 35 J01 NTS OF 53.5 Ib., BTC., S-95 CASING. CEMENTED TO SURFACE WITH 1500 SACKS OF PERMAFROST CEMENT at f4.8 to 14.9 PPG. t800 20 PERFORATIONS at 2054-2064` & 2110 - 2151 at 4 SHOTS PER FOOT 2200 8 V2" HOLE TO T. 0. at 2278 PLUGGED BACK TO 2205`. 2 7/8" TUBING WITH MULE SHOE of 2155_ 70 JOINTS OF 6.5 Ib., N-80, EUE,8R0 TUBING; PLUS 25~ OF MULE SHOE 7° at 2198`, RAN 58 JOINTS OF 38 (b.,BT.C., S-95 CASING. CEMENTED 1st STAGE WITH 90 SACKS OF CLASS ~G` WITH 2 % CFR-2 AT 15.2 PPG. SQUTH BARROW No. F 5 2640 FEL eznd 990` FNL Sec. 23, T.22N., R.t7W. , U.M. HUSKY 4CL N. P. R Ope~otions A/AT/ONAL PE7ROLEl1M RESERVE in A t ASKA WELL COMPLETION I SCHEMATIC j ~~ ~~ i tNTRODUCTtON After the 1976 drilling season, casing requirements were reviewed and design of casing strings standardized. Every effort was made to minimize weight and grade changes for simplicity, cost effectiveness, and to reduce chances of error during handling and running operations. Casing sizes were selected to accommodate designs far we[Is from 2,000` to Z0, 000'. Steel grade selection was the controlling factor on design with low hardness (Rockwell C24-2$) steel being selected for Arctic application and possible H2S environment. Casing sizes and design criteria required by Husky are listed below: YIELD STRENGTH (PSI) SIZE(1) WEIGHT MlN. MAX. MINIMUM PRESSURE REQUIREMENT (PSI) COLLAPSE BURST CONNECTION 20" 133#/ft . 55, 000 80, 000 1, 500 3, 050 STC 13-3/8"(2) 72#/ft. 95,000 110,000 3,450 5,350 BTC 9-5/8"(3) 53.5#/ft. 95,000 110,000 8,850 7,900 BTC 9-3/4"(3) 59.2#/ft. 95,000 110,000 9,750 8,540 BTC 7" 38#/ft. 95,000 11Q,000 12,600 9,200 BTC (1) OD tolerance to be within API requirements unless adjustment absolutely necessary to meet ID requirements. (2} Special drift to 12.25". (3) Special drift to 8.50". The following are additional requirements primari{y to assure that the .steel exhibits the metallurgical properties for Arctic applications and resistance to hydrogen embrittlement. 1. All pipe that is 13-3/8" OD and smaller to be quenched and tempered. 2. Run Charpy "V" notch tests on two random samples per 50 tons per heat. Minimum acceptance of T5 ft. -Ib.@-50°F. Furnish test reports with order. 3. Perform all testing normally required far API approved pipe. 4. Furnish test reports for ladle analysis, quantitative analysis, and all check tests as per APt requirements. in addition, the fallowing handling requirements were made: 1. Col{ars must be of same steel grade as pipe body. 2. Apply an API modified thread compound on mill-installed collar before bucking on . 28 • • ~ 3. Inspect at mill using Tuboscope's Amalog IV or equivalent on 9-3/4" and smaller, and at least magnetic particle on 13-3/8" and 20". AlI pipe to have special and area inspection together with full length API ' drifting. (Note special drifting requirements. ) 4. Apply Arctic grade grease on all connections before installing thread protectors . 5. Install closed-end type thread protectors. Plastic plugs can be used to secure wrench openings in protectors. 6. Buck up thread protectors with impact wrench. Both mill and third party inspection personnel should observe the installation of thread protectors . 7. Palletize or containerize the tubulars, if possible, prior to shipment from mill. do not haul pipe like cordwood in gondola railroad cars. 8. All pipe to be Range 3. 9. No "V" notching or metal stenciling on pipe body or collars. , Casing programmed for South Barrow Well No. 15 was as follows: 13-3/8" conductor at ±110'; 9-5/8" casing at ±1500'; 7" casing at ±2100'; 2-7/8" production tubing if needed to complete the well. Casing actually run was 13-3/8" at 80'; 9-5/8" at 1514'; and 7" at 2198'. The 2-7/8" production tubing was hung at 2155' just below the production perforations in the 7" ' casing. The 7" x 9-5/8" annulus was Arctic Packed through the 7" FO at 1180' back to surface. i 29 ' 1 East Barro~i #l~ «ell Bare Schematic u~~~.1 =;n it 4~,rmati a Fr,,ir~ `_UCs~~C `~-~'~il [ iiaorv Well: East Barr©w # 15 13-3r8" 72~ Casing Cmtd at 80' ~n 17-1i2" hole w! 230 sx v (cmt ±o Surfj 7" X 9-5i8" Annulus Arctic Facked from 1180' to surface 9-5%8" 53.5# Casing cmtd at 1514' in 12-1%4" wi 1500 sx Prmfrst (cmt to Surf) Perforations 4 SPF Hyperjet II Csg Gun 2054-2064' 2110-2151' 2-7f 8'" Tubing hung at 2155' No Packer 7" 38# S-95 Casing cmtd at 2198' in 8-1 /2" hole w/ 140 sx G cmt ( 80 sx CI "G" w! 2% CaCl2 & 50 Sx downsqueezed } PBTD 2170` '~ ~ '` 8-1 ~'2" hole TD is 2278' C:cli l ~ \~.i~ FICfC~ Z'.t_ ~~:r icy. .:i~1C:'l.c ~. Ll Clv _t 1~ ;~ fT 1 ,_ h :cc L , '~G acr- ~c~ „c ~cc cc !sae !>Gr ,~cC Well: East Barrow No. 15 ~~.,rv ? 3-3 3" 7%~ ,,asirg ~r?'td at 30' in 17-1i2" r~cle ,vr i3C sA C (cerrent to sur`ace 7" X 3-Si3" .a nu(us arctic rackad frcm 11aC` is surra~° 7" F.O s at 1180' & 1360' Ccwrtsqueezed 50 sx (-55 cu.ft.) tr<rouyF FO at 130G' to t7`;Q' 9-5r8" 53.S+iasirg cmtd at 114' it 12-1f4" ~r~=' 1~iC s:c Pr,~trst (cement tc su~`ace F2r1;:raticr'~S 4 S~F Hyperj2i'i ~;j ijU(' 2L~4-i~64, 2 i'C'-21 J1, ~-~ ~' T~Gi'-y .;f~.4 3 ! 1 ~ vv;C.^ 1 ~~ ..~C. J! ,.... a,d 1 ~:- c ?r5 %_, Zr~"."r ..,-~'~ .~a~i:~':~ -C~: c i ~':'?~ ~-f '_ ,Q!B bN .4~ a J ...... ATTACHMENT 8A. Tubing and Casing Details F or~c r--7 SUBMIT IN D TE' STATE OF ALASKA eP other In- 5[rl:C[I(tni On 5 API OIL AND GAS CONSERYATION . COMM1TTEf reYBCSC s~sie~ _ _. S0- WELL COMPLET~aN QR RECOMPL~TtON REPQRT AND ~DG la. TYPL, e c ... U[t, uns- ~ - ~ ~ ~ - \\'F,LL \[''F.LL ~L D8Y ~ OthPr . _. . b. TYPE OF COMPLETIOt~c ` SEW ~ wOGF ~ DEEP- ^ PLCG ^ MPP. \\'t:LL ._t O\'r.R !_} E~ DACR GESY R. OtI7Pr -- -~. SAHE_VY VPCRATUn a:. _ .. Husky.Qil NPR.: Operatons:,...Znc~ __-_- ...:.::, ... . ,. - ..3. AD DRGUS- OP ~ORERAtOa. .. ...... . .. .. _. _-. .. .. __ ,.. ~ ~ ~ .., ... 3201 C 3tr-'et, Suite 600, Anchorage, Alaska. 4. r,OCAt(OS OP \c ELL (K port location etearLy and in aceordansa ecith ¢ny State reQuirementr)' ~t svrlace 950' FWL & 500' FSL, SeC 14, T22N, R18W A[ top Drod. interval reported below At -total deD~ rim. oR Yx(F3;•; NA.~Y Naval Petrgleum Reserve ~~ 9. WE1..L LYO. ~ - - So. Barrow~0": `I3"`"-" .:-" OHJECTNEJ~ • • ..............._ Sec 14, T22N, RI8W N/A _.I3.,.LAir, C.~L'DDF.D - l~k. D.1TE,T.D. RF 1.CF1ED is.. DATE CdivtP SUSP OR A3.L~tD. L6. E2.EVATIONS (DF, Ri{S, RT, GR, ?';TC)• i".. ELEV. CASFP'G HEAD 12/-17/76 , 1/2177 Susp~ 1/17f77,. ._ Grd - 22• Pad 26• KB - 4Q 26' , ._ . . - ..Fs,. ~. ; , >.; Id. TOTAL DEF~^. FF, SLD & TVD 9. PLUG, RACI{ aID & IF hLL'LTFPLE CO:vIPL.. - yl. FSSERYIL3 ~DRtLLED. aY 2534' MD 2474'. MD. HOW ai.arFY• R02ARY TOOL; ~ CAMLE TOOLS All CL. t'ICUUU LIJIV li`ii'LltYAL(S), VF TLiFS COitiIPLE.'TION-°I'OF, BOTI'O:K. NA.'a[S {IYtD AND TYD)• ~. wxs. nrR.zccno~(wI. slnsvE-~ arADE 24. TYPE ELEC''"i,.IC AtiD OTHIIL LOGS RUN - ~ ~ - ~ - DZL/BHC Sonic/FDC-GNL--GR/HRD -_ ]~. - - - ~ CASIiiG RECORD (Reoort~ siF stiinas set in wclU _ _ ~ -. ~. '~ .:.. ..'. ' :. ~.' -. - ~ ~ -. ,. ~ - ' CASIilq SIZi WEIGHT. LB/FC. GRADE DEPTH SET f.1rC31 HOF,E SIZE - CE:.SLtTIYG R.ECOf:D ~.. - A_~:OU.1('I' PISLi.ED ' 10 4" - 14 3 4 Cmt to € I 7" 32 N-80 2514 8 1,2 Cmt ao S f Cla ss rr rt W 2° zD. LIIVE.Z Fz£ccFiD z'r. ilisuvG R.E:.O?.D SIZD TOP (3IDT •ROTTOYC -(iMD) SACF{s' C~ltlv"T' SC'sIF.€.`J .(D: D.1 SIZE ~ I3EP'Cli SET (ti.:DT [-PACF{IZ{ SET (iYtD) 2$. PERE'ORATIO\S OPT TO FROD[I (Interval, size and number) q. ~~ ~ ACID, SiIOT, F:.A."'L.a?, CE3LE,`7T SR6s'='Z^•,, ~. E'i'C. _ ~ _ Selected Intervals have been Perforated DITc+'i'It IhTE1tVAb (KD) AhF•JUYf fh*D _ USA with 4 SPF, Ayperjet II. ' " '-° . l_ t- " -' :u. PROnucrlos _ . _.. if,( o;r-f r~ ::: , D R.Tt' FIRST ?20DUCTLO\ PRODGC*t0^F 0.1EIKOD (Flowi:~e, g.as~l:£c, Pumping-seize and LY De of DumP~t ~ ~ P: GL '$~,~tndLC:.b oste 0Y TeS^. KU L'RS T=STED CIiO'{E SIZE PP.OD';l FOR OFI~-ESL G.LS--.~'CCF. Wd.TEEir-3EL~ G.4S-OIL R:<TLO ~ - TFa'l HiStOD ~~~} - FLO~Y. TJBiVG ASi\G PRESSURE CALCULATED OLL-88I,. GAS-.3CF. WATER-BI3L. ~ - OLL GRAVITY-APi (CORR.) P&E3S. 2!-AOLTIt RATE ~~ St. ntCPIIQITtnV AP [_aQ i.l r.ltF. ulPrt /pT nPI-CPnted ef!! 1 SCOT l4 iTV E3 31n by g?, L[92 OY A2TAC8\[6ST3 ~ ~~ - ~~ - None. This report is CONFIDENTIAL and is filed for information anl~ 33. I hrrebp cerrL'S-that/yth~r toreg n^ and a a/cue tnlormation la comyrte sn~i-correctea ~r~ermin~~m~ 1~a~n~e recor•Ti SII;VEU ~ / .G~ T TITLE D~ZlI1nE Engln~er DATE Jan 28 ,. 1977 -- '(See (nst-uctiaF,: arld Spoc:: for ,Atdd~rionei Data on Revenx Side} ~"-' a WELL BORE SCNEMAT/C 0 300 1000 1000 2000 2900 3000 PERFORATIONS t/6/77 INTERVAL SPF 2224 - 34 4 2315 - 30 4 2330 - 45 4 2308-88 4 REPERFORATIONS (/14/77 2224.5 - 34.5 4 23!3.3 - 4S.S 4 2356.5 - 76.5 4 2383 - BT 4 20" Ar Ta' 20", 133# K-55 CSG. CMT. TO SURFACE W/ i50 SACKS PERMAFROST. t2/f6/7E IO-3/4" AT f 157' t0-3/4", 5f ~f J-55 CSG. CMT. TO SURFACE W/T60 SACKS PERMAFROST !2 /22 /T6 -T/B" TUBING AT 2394' -T/B", 6.5 ii, N-BO TU81NG. I/t5/T? B. D. 2314 ` K8 " AT 23t4` ", 32 iM, N-BO CSG. MT. 70 SURFACE W/805 SACKS ERMAFROST. TAIL fN W/80 SACKS LASS 'G" W/ 2% CoCf=. 0 2534' KB SOUTH BARROW N0. f3 BOT' FWL. ANO 552 FSL SECT/OK /4, T22N, R/BW UM. PAO LEVEL 26`EST A E 40 ` EST. HUSKY OIL RlP.R OPERATIONS NAVAL PETROLEUM RESERVE NO. 4 43 CQS I NG V Programmed casing for South Barrow Weft No. 13 was 20" conductor at ±40', 10-3/4" at 1200', 7" at 2500', and 2-7/8" production tubing if „~, required. Casing actually run was 20" conductor set at 74', 10-3/4" at 1157', and 7" at 2514'. The 2-7/8" production tubing was run to 2394' and hung in the 7" casing when the well was completed. 33 STATE OF ALASKA ALAS AND GAS CONSERVATION COMt N REPORT F SUNDRY WELL OP ATIONS 1. Operations performed: Operation shutdown ^ Stimulate ^ Plugging ^ Perforate ^ Pull tubing ^ , Alter Casing ^ Other ^ 2. Name of Operator 5. Datum elevation (DF or KB) North Slo e Borou h CH = 26' KB = 4 ' Feet 3. Address 6. Unit or Property name 3201 "C" Street, Suite 602 Anchora e Alaska 99503 South Bar w 4. Location of well at surface 7. Well number 807' FWL & 552' FSL, Sec 14, T22N, R18W U. M. Alaska SB #13 At top of productive interval 6. Approval number See Attached Sperry-Sun At effective depth Directional Survey Report 9. APl number 50- 023-2o0as At total depth 10. Pool 443' FWL & 492' FSL, Sec. I4 T22N R18W U. M. Alaska South Barrow 11. Present well condition summary Total depth: measured 2534' feet Plugs (measured} true vertical 2491' feet Effective depth: measured feet Junk (measured) N/A true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 60' 20" 150 sxs. Perm. 74' 74' Surface 1153' 10-3/4" 760 sxs. Perm. 1157' 1150' Intermediate Production 2514' 7" $05 sxs. Perm. 2514` 2471` Liner 80 sxs.. "G" Perforation depth: measured 2224' - 2235' @ 8 SPF, 2315' - 2346' @ 8 SPF, 2356 ` - 2358' @ 4 SPF, 2358' - 2368' @ 8 SPF, 2368 - 2376 @ 4 SPF, 2383' - 2387' @ 4 SPF. true vertical 2184-2195, 2275-2306, 2316-2318, 2318-2328, 2343-2347 (Interval SPF as indicated above) Tubing (size, grade and measured depth) 2-7/8", 6a#, N-80, 2384' tally, set @ 2394' h1D ~~LE.. Packers and SSSV (type and measured depth} No packers or SSSV employed. 1.,r~ ~ '_ 12. Stimulation or cement squeeze summary See Attached Report. ~. . _. ~ a5 ~;.~.~~. t,;~tT~~iSS ; Intervals treated (measured) 2224 - 2387 feet MD BKB ( Barrow Sandstone • ~ ~ ;4~,e~-,;rage Treatment description including volumes used and final pressure See attached report by Halliburton, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation No prior production history Subsequent to operation - 0 - 350 - 0 - 525 - 14. AEtachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~- t5. (hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Date / ~Q Form 10-404 f~/12-t-85 " ~ Submitrif~ D~¢Iicate ~ s S~auth Sarr~a~~ #13 ti4'ell Bare Schematic Ba~~d :n inormatit~n trim, .~~1000 ~4;t{ Fl:;t:,r~ i!'J~I1; S~cath ~~rr®vv # 13 ail re.;ths are from KE 40' Eie~~atiorl ,20" ?3.s*= Casi^g Cm'd a± 74' it 26 "hole ~N! ?~~ sx (,omt to Svrfj 10-314°' S1# Casing cmt~ at 1?57' in 14-3/4" vv/ 750 sx (crnt Co Surf) 2-718" Tubing hung ai 2394' No Packer PBTD 2514' 7" 32# Casing cmt~ at 2514' ~u% 805 sx Permafrost cmC Nrith 80 sx CI "G' tail wi 2°ro CaCl2 (Cmt to Sur) UJelf TD is 2534' L].~.. ~ E_i l~ i ~ '!li `.~ .;C ~.t. :iu~.._~ 1~; 1 ~- ~~)F, 3i ,/C: .t:..Y ~~L_ _! ~,. i Well: South Barrow N® ~.~ ~~:~; zec xc sGu x;C scr. ~~ acv yc~: r~W ~zcr, +~cc Baca iscc ice »oc ,ire <c:;c z•sc --'%c i°x.: i ar, 20" 75z ~.mtd at 74' in 24" hcle wl I o0 sx permafrost ~rnt (cement to surface! 2-?18" E Ail ~eGt s are from KB (40' Eievaticn; 2-7r3" ?„ ?' 9-Si8" 2 7'8" X ?" X 9-~/~ ZO-314" 51~ J-5~ crrtd at 1157 in 14-3i 4" w~76G sx Prmfrst cmt (cement to surface) 7" 32M N-60 cmfd at 25 t 4' in 8-L~2' hole ,N-805 sx prmfrst read and 3C sx GI G tail (cement to surface` 2-7r3' Tub+ng hung to 2394' /~ PerF~~aEiCnS NlYerj2r (~ ~.sCj v!.n ~J~'k-'~~~1 ~ Lv l ~ C_ 2_2-~ 2235'. 23 5"-46 2 c`-75', 2333' 3'' 3 spt t t ~ f~ ~/ r F~2i't fr~~ ;vrth t04 ,x ~r 2~i4G Sated ~~ ,`'~`~ ~' ATTACHMENT 9. Water Analyses ~ • L1i iL:...i .. y aL.a.L ~. t ' - - , • •. ~ ' G~OCi-:=CAL ANALYS IS O~ ti~lH.~~2 Pro-391 . . • OATC OC REPORT :2.~C12 Z.;, 1; 7Z - •ELL NO. J? A_Z]. ;1'~ ~ - 3 : DtTE Of SANPLtND 1'+SC~'l ~~ 197Z p ~ J COU•1NT :.[ Z F~: 44r PL CD fY .~.. C. C•: .^.21t' i1ELD .70- ~:.T=qIS J33 'l~Q • LA 90R~Tp RY NO. .~•.7-72 •+-L•7 [ 20NE ~ . • AN 4LYST .°351d~ SAUPLE SOARC[ R401 CA15 PLATS -[R Nf itlpn RCACTiMG VILAC R_[ACT IMC VALA[ rllU C.Aws r[t Lt Tt• toul v-ttrtf •t• re LLIOR •[attr[ • SDOIUr k• 6155.7 207.76 47.115 cAt.ctuY, c. 207.0 2^.33 1.53 ' YACn[stvY Yt L3.3 3.56 0.63 ; BARIUM • R.._ • X1;.6 ~ 0.50 0.09 _, _ sTaonrtw . sT. - • •• SUt PN ATE SDA O.O ~ - t3. `JO t 17.00 ~ • • cNLOatDt ci 9!i30.5 2Ga.00 1:7:11t . • ' .CAR 60NAT[ CO] 0.0 ~• ~ • '. y•~ . Rt CAReOMATE - NCOS 9~:.~ , r 1::.3$ •• P.SO MYDRpXt DE ON • • S1tTCA S10z - , .. IRON. ALUMINA R=O~ y • TOTAL ~S•56 5 - r7~]L ~ 100 .. GROAT CNfYI CAC CNARACTC~ - YI SCCLL ANCOUS - ALKALIS -RtYAR7 SALINITY RORON. 15.3. --K iARTNS - SCCDNOARY SALiNiTT MYDROD[N SULFIDC AbSt'..at •~ STAONO ACtOS -RtAtARY ALKALINITY [OUIYAILNT SALT IZBOO• p-M •'• [tCAlt ACt03 3LCONOAAT AIKAIlNITT RESIST1Yt1'Y 1 T1eT 0.~I1p.,Y, ••• • CA/LARTNS - CMLORIMITT r ~n I`71rT• • . -rtt CNLDRIbE SALINITY S-ECiilt CRAYtTT L0027 - SVL/MATE SALINITY CARtlONATE /CNlOR1 DC _ PN 7.65 . REYARXS Xa•f. Tl CX CLL CRA-N ~•N~•de•S- , • { ~ >41taC T1R• vKut •• ' • This sa.-~la contzined 2.G~ alcohol - • by volta]e (tested. by distilla~on) . • • • ~ •' .. •' • ' .. .. i • • . • tro • ' X ncof . a ' 1C. L 3:~p*ss:-3 tt (U.S..t.~ etc Fi111s~ ---~ .. . • I-C Lzboxnta~ •. • • • ,.. ,' • uc Re.a [vi• •.r~.csRr..Tte. e• tetles tR re•..t et• eATte• ....,.. L e.t... ...aP• o_ r-_ ~_....:a etnt„T~L.r, n='n • ~ • _ _ t ~~~ s ~ ~ 1 ~.., C~'£'~iIC~I, & G£DLflGIC:~L L.~aflR.4 ~'d ~IE,S flr r1LASi~A, I'YC. ''.C. 9CX 4-i27S Tc~E~4CNc (90-1-279-:Ot4 A NCHORAG'c IVDUSTRtAL C~:VTcR Ancnorge'Ataska Oa508 274.3304 Sfi33 B Street ~lA?r.iZ ANALYSIS P..~Pa ~2 i crssAto Huskv a~'_ Ca*~z^.v O~obe:: 8, 1380 - - nAr 5053-3 ~a xa ?=l'SI.L ~O u-~ 32:.~cw ~. i 5 LaCATi."t?/ pT~T ~ ?~`rR~ FORYATIOZi eaulvTZ r~rsxvAt ~"_^ Ne. 4 (2188-22731 Szmale Cr~^.icer iaskZ A F>ta~ Stir . S~cal.s t az~ri?T: ! caxGLVE2axa- Sas71e t~k~~ 9-i2-80 by Fit BrQCtcwav C:t~ena ~<~!I mr+il2 Azivoa ~ Cr I se33nm - - - _ 780a 339 . Q9 snits - - - - - 2 0.04 ~,,...;~.,~ _ n~ 1.10 X13. - - - - - - , dE~ '3 •' ° car5ens csLeaa 14004 39~.~0 0 - ~~~ 6A ~ 59 a_ _ - - - - - 1490 24.x4 Ls - - - - - - - d~oad! - - - - - aol Cae4ess _ 419.2 $ Toni Aa~ee a - _ - - d ~ 9 _ ~ a foal di.net..a seda4 msls _ 24120 8plo~c r...am ~ et•9.: :laC2 +q~ai.aq naJl - - - - 23779 oera.w - - - - 0.29 o~sa.a.s aba.~i p~ - - - - - - - - 7 . t ra..,.v....~ _ _ 0. ~ $ et~rrwea W.iTT~ .lltlI.°5I3 PAS T R.;I ~~ `.lamoi~ acove ^r+~eTt~bld ilisQ rt uais Ha CI SO 2~F CI a Ca HCOa S G HCO= ~s SO. 5 3Rg SO. Fa CO Fa CO a S a ~x...ti. ~ ,..~ n+r ~.a.r. w. x v u1 L ~cS: lte/za3casoe v. acr tt.yta sors*+~ .~......• p.r a~ •y` ~++ ~Lat~M OrriA ! H~w'+r .ri+sr • s + ~.rs -~ t f ~ i ~ .;=~~. ~L'L'~~I~AL &; ~LOLaG1~:~L L~ R~ir~_-~ a ~3i~ILS (lI' AL~SIi~i, I~~'. P.Q. BCX 4S2'o TEt-cPHC^IE t967~-27?-.614 Ai~CiiORAGE tiVDUSTRIAt CE^dTER Rnc:~or¢ge; Aiaska ??569 274-3304 500"33 B Street 1 i".~ e~1~It~LYSIS ~.:p~i~ i 09S3AT04 L?':.°itv Q~1 C~^,.z^`/ DAT° G~'.~;'~' 8, 1980 Lai NO 5053-2 e"ri SI.I. 3G ~~t~ ~''T~" ~. 1 ~ L.^.CATIOH FTSI.D ~~ FQR~iATIOti CauxTT rrTSavaz` IST No. 4 (2:.33-227S1 $TATS A135k3 8Alt?LS PRAY 1/2 wiv t."i^s ?rve.-se Gift °-Yi°TZ ~t COIiCLZIEI8Dt3~ Sa^~14 T~tCEri Se*7'f'?^.~?~ 12. 1980 ~JV t~'~II ~3'"JCC'+~v. '~~ ~ awq/1 Anioas ~ new f _ - - 8907 - 387.45 e~b _ - _ _ _ ~ 0.02 ~a~i+.o _ . ~ 1.02 GSLaid. - - - ~ aa00 --- x06.08 Calaam - - - - 550 27.45 ~ym.a _ 0 0 *•-Q,.em _ _ 80 5.53 3i~bee+u _ _ 1000 16.40 hs.a - - - - _ - - ei~dxnafc. - - - - - - Toot Casa . 422.50 ~~ Asioe s - - 422.50 tort aS~siwd mda, ms/1 2x4 75 8yedr7c r.reon~. @ aa•A.: aiiaC:.q>~ai.a; ~~ - - - - - - 2 ~ 300 a~„~ - - - - 0.31 owo.mu.ss Oti•.e,.d y3 _ _ . _ _ _ 7.0 ~~ ,_..., 0.29 o;,i„e„wf Wa3'~t .i?-tAL~ 523 P~ITTiR2+i 5es3~ 6sas~2o a'oovt dwez-.ceC 3t3Q ~r i1ffit x: G bt; ~(• Cl 50 Ha FICOa 5 G 504 5 ?dg COa 5 Ft Ct F3C0, SO. CO, (]4 wY.~ 4 aw±s L+~r Y..i.ir 7il Z ~.i Si) i02'L: yi!=~Ymeo D~ Yet Sd.~/t= YSyr~ ~~ 7+ Ls l.is s~iw+i Md'+Jr...q A....~ t 7fwdr+w airLSS b~ ~ N-2 Water Samples For NSB Gas Fields Well Date TDS Sample Description E Barrow 14 2/14/1977 111,662 DST#1 Top of Test Tool E Barrow 15 9!12/1980 24,475 DST #4 (2188-2278'} 112 way through revers 9/13/1980 24,120 DST #4 (2188-2278'} Sample Chamber E Barrow 17 4/21/1978 21,569 Production Test #1 Sample #1 4(21/1978 21,640 Production Test #1 Sample #2 4/21!1978 21,589 Production Test #1 Sample #3 4/21/1978 21,577 Production Test #1 Sample #4 E Barrow 19 5/17/1978 114,809 DST#1 E Barrow 20 5!20/1980 74,073 DST#1 Sag River Top of Toois 5/20/1980 157,059 DST#1 Sag River Pit Sample 5!20/1980 62,913 Production Test #1 Barrow Sands Flareline S 5/20/1980 62,931 Production Test #1 Barrow Sands Flareline S Walakpa 1 1/22/1980 14,800 DST#1 (2066-2120} Top of DCIP Valve 2/8/1980 15,400 DST #2 (2073-2088) Sample Chamber 1 1 1 1 1 1 1 1 1 1 1 1 A 1 1 i 1 1 1 ~~ N A T I O N A L PETROLEUM RESERVE I N A L A S K A ATTACHMENT 10. FIT for Well EB 15 HISTORY OF DRILLING OPERATIONS SOUTH BARROW WELL NO. 15 ~~ .; ;_ ~- _ £,_ ~~, ;; ~; ~ ~>` ~ :' ~~~'~ HUSKY OIL NPR OPERATIONS, INC. Prepared by: Drifting Department Edited by: S. L. Hewitt and Gordan W. Legg For the U. S. GEOLOGICAL SURVEY Office of the National Petroleum Reserve in Alaska Department of the Interior SEPTEMBER 1982 ~ I` M t SOUTH BARROW WELL NO. 15 INTRODUCTION South Barrow Well No. 15 is located in the East Barrow Gas Field, Alaska (Figure 1) . The well is 2,640 feet from the east line and 990 feet from the north line of protracted Section 23, Township 22 North, Range 17 West, Umiat Meridian (Latitude: 71°14'58.68" North; Longitude: 156°20'42.13" West) . The Alaska State Plane Coordinates are: X = 694,843.94 and Y = 6,309,541.29, Zone 6. E{evatians are ?' ground level and 30' Kelly Bushing. Painting, cleaning and rigging up began on August 15, 1980 and was completed on August 23, 1980. The well was spudded August 23, 1980. South Barrow Well No. 15 is a step-out well 1/2 mite northwest of the South Barrow Welt No. 19. The hole was drilled to a total depth of 2,278 feet. The primary zone of interest was the Barrow Sandstone. Zones 2054' to 2064' and 2110' to 2151' were found to contain hydrocarbons. At the conclusion of the drilling and evaluating operations, the well was completed as a gas producer. The wellhead was secured, and the rig was released on September 18, 1980. Husky Oil NPR Operations, Inc. supervised and directed the drilling and support operations as prime contractor far the Department of the Interior. Brinkerhoff Signal, Inc. was the drilling .contractor, and Brinkerhoff Rig 31, a National T-20, was used to drill the wetl. BE-~vFO~ T SE P 1 V ~ G ~ IrAIIFIgN®NT GM ~p-A SE4 l'~•- t • Y~ 30UTH BARRO W Well No. 15 kpq-A 4 T FIGURE 1 -WELL LOCATION MAP -SOUTH BARROW WELL NO. 15 ~ I` M DRILLING SUMMARY Cleaning, painting and rigging up of Brinkerhoff Signal, Inc., Rig No. 31, began on August 15, 1980. Rigging up was completed on August 23, 1980 and the hole was spudded at 12:30 p.m. The rig .had previously been on South Barrow No. 20, a short distance away. A 13-3/8" conductor was set at 80' and cemented to surface with 230 sacks of Permafrost cement. A 12-1/4" .hole was drilled to 1510'. Fresh water was used as a drilling fluid to 1350' where it was displaced with a gel mud system to clean the hole. Core No. 1 was cut from 800-825' with 9 feet recovered, and Core No. 2 was cut from 1329' to 1389' with 59 feet recovered. A DIL/GR/SP, BHC-SoniclGR/TTI and HDT-Dipmeter were run from 1510' back into the 13-3i 8" shoe at $0' . An additions! 5 feet of 12-1/4" hole was drilled and 9-5/8" casing was run ~, (36 joints, 53.5#, S-95) . The casing was landed at 1514' and cemented ~.~p 'l back to the surface with 1,500 sacks of 14.9 ppg Permafrost cement. The ~~ ~. ~ mud was displaced with 10.1 to 10.3 ppg calcium-chloride mud which was ~ ~ then used to the total depth of the well. The shoe and 10 feet of formation were drilled and the formation was tested to a 0.61 psi per foot ~` equivalent gradient with no break down. An 8-1/2" -hole was drilled to 2278'. The following cores were cut: Core No. 3, 1838' to 1881', 42.8 feet recovered; Core No. 4, 2096' to 2136', 36.2 feet recovered; Core No. 5, 2165' to 2187', 19.9 feet recovered. Three open-hole drill-stem tests were run as follows on the way down: Drill Stem Test No. 1 (2080-2136'): Misrun; packers failed after approximately 3 minutes of initial open. Drill Stem Test No. 2 (2095-2136') Misrun; packers failed after 20 minutes of initial open. Drill Stem Test No. 3 (2105-2136`) no cushion: 1st FP (63 minutes): fHP 1,175 psi; opened through 1/8" choke with immediate strong blow, GTS in 4 minutes, stablized SFP of 830 psi, iFP 248.5-945.5 (from final Halliburton report, gauge No. 62 at 2128'); shut in for 124 minutes, ISIP 970 psi. Znd FP (125 minutes}: Opened through 24/64" choke with maximum SFP of 290 psi; changed to 20/64" choke, pressure declined from 245 psi to 200 psi at end of FP; calculated final flow rate 500 MCFPD; FFP 294-265 psi; shut in for 240 minutes; FSIP 964 psi; FHP 1,167 psi. ~ _ h t~ ~ 8/29/$0 TD: 1510`; MW: 9.6; Vis: 45. Milled on drill collar 0' slips; pulled out of hole. Ran in hole with bit and junk basket. Drilled on junk. Pulled out of hole; no recovery. Reran mill; milled on junk. Pulled out of hole. Ran magnet; recovered miscellaneous parts of slips. Ran in hole with bit and junk sub. 8/30!80 TD: 1515'. Finished milling an junk. PuCled out of ' ' 5 hole; picked up bit. Ran in hole and circulated and conditioned for casing. Pulled out of hole. Ran 36 joints of 9-5/8", 53.5#, S-95 casing; landed at 1514'. Circulated and cemented with 20 barrels water and 1,500 sacks Permafrost cement at 14.9 ppg, 6 B PM, 450 to 650 pounds. Full returns to surface at 14.7 ppg. Cement in place August 29, 1980, at 8:45 p.m. Waited on cement. 8/31/80 ' TD: 1515'; MW: 9.6; Vis: 41. Finished waiting on 0 cement. Cleaned pits and mixed CaC1 mud. 2 .. 9/1/80 TD: 1527'; MW: 10; Vis: 58. Cut off 13-3/$" head; ~.-' ` 12' instal{ed 9-5/8" head. Nippied up blowout preventers and flow line. Tested blowout preventer and manifold to 3,000 pounds. Tripped in hole with bit. Cleaned ~ flow line. Tested casing to 1,500 pounds. Drilled out float and shoe; tested formation to 0.61 psi/ft. Drilled ahead. ' 9/2/80 TD: 1538 ; MW: 10.0; Vis: 38. Drilled ahead; 11' drilled on junk. Pulled out of hole at 1538'; ran magnet. Pulled out of hole; good recovery. Ran in hole with bit; junk on bottom. Pulled out of hole. Reran magnet with small amount of recovery. Ran in hole with bit; drilled on junk. 9/3/80 TD: 1570'; MW: 10; Vis: 38. Drilled on junk. 32' Steel-line measured out; made strap correction. Ran in hole with magnet. Made six magnet runs between bit runs. Ran in hole with bit. Drilled ahead. 9!4/80 TD: 1838'; MW: 10; Vis: 45. Drilled ahead to 268' 1713'; pulled out of hole for bit. Drilled from 1713' to 1812'; circulated samples. Drilled to 1838'; dropped survey. Pulled out of hale, steel-line measuring. Picked up core barrel; began trip in. 9/5/80 TD: 1955'; MW: 10.1; Vis: 45. Finished washing to 117' bottom with core barrel. Cut Core No. 3, 1838` to t 18$1'. Pulled out of hole; recovered 42.8 feet of core. Ran in hole with bit; reamed core hole. Drilled ahead. 17 0 South Barrow # 13 Production Curve From AOGCC Production Database S RARR®ilV VNell N®. 13 Producing Days • ATTACHMENT 11. Well Production Histories 40 _-. _ _ _ I , i 20 I ' i ~ ~ ~ o I I i i i t ~ ~ ! I I Jan-80 ~~ Jan-82 Jan-84 ~ Jan-86 Jan-88 ~ Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 ~ Jan-04 Jan-06 e Cum Gas Prod (MMMcf 10 - - - ------ ---- --- ---- ----- Cum Water Prod (Mbbl) I - 1 1 i ~ I ~ I _II-_ Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 100.000 10.000 1.000 0.100 0.010 Jan-80 Jan-82 Jan-84 Jan-86 filar,-88 Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-O6 Barrow Gas Fields Nell Improvements Study Feb 200? Appendix 1 Pale 2? of-~7 -Gas Rate (CD) (MMcf/d) -Water Rate (GD) (bbl/d) • East Barro~~ #l5 Production Cur`~e ATTACHMENT 11A. From AOGCC Production Database Well Production Histories E BARROW Well No. 15 -Producing Days 40 i i I l l l i l l, i i i ~ I I I 20 i i j i i j I i I I i t 0 Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 e Cum Gas Prod (MMMcf 10 - - - _...__...Cum Water Prod (Mbbl) _ - - a._, .. ;. 1 ~ jl lI ~ lit IIII 01 ~ ~ Jan-80 Jan-82 Jan-84 Jan-86 Jan-88 Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-O6 100 10 1 0.1 0.01 Jan-80 Jan-82 Jan-&1 Jan-86 Jan-88 Jan-90 Jan-92 Jan-94 Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 Barrow Gas Fields Fell Improvements Study Feb 2007 Appendix l Page ;8 of 47 -a-Gas Rate (CD) (MMcf/d) -Water Rate (CD) (bbl/d)
