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DIO 033
DISPOSAL INJECTION ORDER 33 Sterling Formation North Cook Inlet Unit Well B-01A 1. July 14, 2008 CPAI’s application for disposal of Class II oilfield waste by underground injection 2. July 17, 2008 and July 20, 2008 Notice of hearing, affidavits of publication, and mailings 3. August 26, 2008 Sign-in sheet 4. September 8, 2008 CPAI’s amended application 5. -------------------- Emails 6. August 6, 2009 CPAI’s baseline temperature log 7. -------------------- Annual reports 8. June 4, 2024 Hilcorp DIO cancelation request (DIO 33 Cancellation) ORDERS • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West '7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF ConocoPhillips Alaska Inc. for disposal of Class II oil field wastes by underground injection in the Sterling Formation in the North Cook Inlet Unit Well B-OlA, Section 6, T11N, R9W, S.M. Disposal Injection Order No. 33 Sterling Formation North Cook Inlet Unit Well B-OlA November 5, 2008 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 6th day of November, 2008. BY DIRECTION OF THE COMMISSION J J. Co mb S cial Assistant to the Commission • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF ConocoPhillips Alaska Inc. for disposal of Class II oil field wastes by underground injection in the Sterling Formation in the North Cook Inlet Unit Well B-OlA, Section 6, T11N, R9W, S.M. IT APPEARING THAT: Disposal Injection Order No. 33 Sterling Formation North Cook Inlet Unit Well B-OlA November 5, 2008 By correspondence received by the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) July 14, 2008, ConocoPhillips Alaska Inc. (CPAI) requested that the Commission issue an order authorizing underground disposal of Class II oil field waste fluids into the Sterling Formation through the North Cook Inlet Unit (NCIU) B-OlA wellbore. The NCIU B-OlA well is located on the Tyonek Platform offshore Cook Inlet, Alaska. 2. The Commission requested additional information on July 15, 2008. CPAI clarified several points by electronic mail on July 15, 2008 and met with the Commission on July 21, 2008 to give an overview of the project and discuss specifics relating to the well. 3. Notice of opportunity for a public hearing was published in the ANCHORAGE DAILY NEws on July 17, 2008, in the PENINSULA CLARION on July 20, 2008, on the State of Alaska Online Notices on July 17, 2008, and on the AOGCC website on July 17, 2008 in accordance with 20 AAC 25.540. 4. The Commission did not receive any public comments, protests or a request for a public hearing. 5. A public hearing was held August 26, 2008 and recessed until September 17, 2008. The record was left open at CPAI's request to allow additional time to provide Commission- requested information. Disposal Injection Order 33 NCIU B-01 A November 5, 2008 Page 2 of 9 6. Additional clarification and information in support of the application was received from CPAI on September 11, 2008. The Commission closed the hearing record on September 17, 2008, without reconvening the hearing based on a review of the information provided by CPAI. 7. Information submitted by CPAI and public well history records are the basis for this order. FINDINGS: 1. Location of Adjacent Wells (20 AAC 25.252(c)(1)) NCIU B-OlA is an existing gas development well located 1249 feet from the north line and 980 feet from the west line of Section 6, Township 11N, Range 9W, Seward Meridian. The surface location is on the CPAI-operated Tyonek Platform in 110 feet of water approximately 5 miles due east of Tyonek, Alaska and 40 miles west-southwest of Anchorage, Alaska. Five wells penetrate the disposal zone within a `/4-mile radius of NCIU B-OlA. 2. Notification of Operators/Surface Owners (20 AAC 25.252~C)(2) and 20 AAC 25.252(c)(3)) CPAI is the only operator within a `/a-mile radius of the proposed disposal well. The sole surface owner within a `/4-mile radius of NCIU B-OlA is the State of Alaska. 3. Geological Information on Disposal and Confining Zones (20 AAC 25.252(c)(4)) The proposed disposal injection interval in NCIU B-OlA lies within the Sterling Formation, and it consists of a series of coarse-grained sand beds interspersed with relatively thin layers of carbonaceous mudstone. This interval, which lies between 3295 feet true vertical depth (TVD) and 3387 feet TVD, was previously perforated and used in NCIU B-OlA to dispose approximately 135,000 barrels of slurried Class II drilling waste during 1997-98. This same interval is also currently used for disposal injection in offset well NCIU A-12. Upper confinement is provided by a stacked sequence of siltstones, mudstones, and coals interbedded with scattered sands. This sequence extends from approximately 3110 feet TVD to 3295 feet TVD, and it contains an aggregate thickness of about 125 true vertical feet of mudstone. Lower confinement is provided by a sequence of interlaminated mudstone, claystone, coal and siltstone interbedded with occasional sand intervals. This sequence extends from 3387 feet TVD to 3549 feet TVD, and it contains an aggregate thickness of at least 55 true vertical feet of mudstone. 4. Evaluation of Confining Zones (20 AAC 25.252(c)(9)) CPAI states the effectiveness of the confining and arresting intervals -both upper and lower - is demonstrated by the past injection in the proposed disposal zone in NCIU A-12 and B- OIA. Structure maps and cross sections provided with the application indicate the confining zones are laterally continuous. Disposal Injection Order 33 NCIU B-OlA November 5, 2008 Page 3 of 9 5. Standard Laboratory Water Analysis of the Formation (20 AAC 25.252(c)(10))'; Aquifer Exemption (20 AAC 25.252(c~ 11)) Aquifer Exemption Order (AEO) 4 dated September 29, 1998, exempts those portions of aquifers within the NCIU that are common to and correlate with the interval below 2900 feet TVD1 in NCIU A-12. Wireline analytical techniques compliant with EPA recommended methods coupled with laboratory analysis of water samples in wells offsetting NCN B-OlA were used to characterize formation water salinities. The Commission concluded in AEO 4 that freshwater aquifers underlying NCIU do not serve as a source of drinking water. Further, the Commission concluded that freshwater exists at a depth. and location that makes its recovery for drinking purposes economically impractical. The closest drinking water well to the NCIU is onshore approximately 8 miles to the northwest, in the Beluga River Unit. 6. Well Logs (20 AAC 25.252(c)(5)) Log data from NCIU B-OlA and offsetting wells are on file with the Commission. CPAI provided a type log section of NCIU B-OlA and a cross section through NCIU wells A-11, A-12, B-OlA and B-02 identifying the confining and disposal zones. 7. Demonstration of Mechanical Integrity and Disposal Zone Isolation (20 AAC 25.252(c)(6)) NCIU B-01 A is an existing gas development well directionally drilled south to a depth of 12988 feet TVD. The well was drilled originally as an oil exploration well and subsequently plugged back and sidetracked to aSterling-Beluga Formation gas producing objective. The well is constructed with 30-inch structural pipe set at 407 feet TVD, 20-inch conductor casing set at 2571 feet TVD, 13-3/8-inch surface casing set at 3514 feet TVD, 9-5/8-inch intermediate casing set at 8840 feet TVD, and 5-inch production liner set from 8598 feet to 12896 feet TVD. Well B-OlA is completed with a single 5-1/2-inch production tubing string and produces gas through Sterling and Beluga perforations between 3307 feet and 5943 feet. The annulus space between surface casing and conductor casing is cemented from shoe depth to the surface; well records indicate cement was circulated to surface and a passing positive pressure test was performed. Well construction for NCIU B-OlA incorporates a cuttings injection system consisting of two 2-3/8-inch injection strings (i. e., annulus injection tubings) strapped to the surface casing and cemented to surface. These annulus injection tubings were installed to a depth of 3437 feet TVD. The cuttings injection system was designed to inject oil-based muds and cuttings within a confined interval in the upper Sterling Formation. Inability to run perforating equipment into the annulus injection tubings resulted in installing the intermediate casing in stages -the lower section run as a liner and cemented to the liner top packer at 3268 feet TVD. Prior to running the remainder of the intermediate casing (upper section), the intermediate casing and annulus injection tubings were perforated from 3280 feet to 3314 1 2900 feet TVD is 2900 feet MD as referenced in AEO 4. Disposal Injection Order 33 NCIU B-OIA November 5, 2008 Page 4 of 9 feet TVD, providing access to the Sterling disposal zone. The upper section of the intermediate casing was run into the well, connected to the lower section and tested. The remainder of the well was constructed as planned. A Cement Bond Log run during well construction over the surface casing interval provides inconclusive results regarding the quality of the cement in the surface casing annulus. CPAI states this is due to the existence of the two annulus injection tubings. Interpreted results from CPAI indicate a cement top in the surface casing annulus at 2530 feet TVD. The Commission authorized the injection of approximately 135,000 barrels of drilling waste down the annulus injection tubings during 1997-98 in conjunction with development drilling activities on the Tyonek Platform. Injection occurred without incident. 8. Disposal Fluid Type, Composition, Source, Volume and Compatibility with Disposal Zone (20 AAC 25.252(c)(7)) NCIU B-OlA will be the second waste disposal well for non-hazardous Class II oil field wastes generated on the Tyonek Platform. Waste disposal injection will consist of the same fluids currently being injected into A-12, including drilling mud, drill cuttings, reserve pit fluids, rig wash fluids, formation material, completion fluids, produced water, stimulation fluids and other fluids eligible for injection into a Class II disposal well. The total estimated volume of Class II wastes to be injected into B-OlA for disposal over the life of the project is 1,200,000 barrels. Disposal injection is expected to be made in small batches and at rates similar to NCIU A-12 (i. e., approximately 1000 barrels every other day). CPAI states that performance data and extensive operational experience involving similar waste materials, the same formation and depths, and similar volumes and rates in NCIU A-12 provide an adequate analogy for the proposed NCIU B-OlA disposal injection. Fracture modeling submitted with the application for DIO 17 (NCIU A-12) used well B-01 A as the basis for simulating fracture propagation. A third party fracture model was used to update the DIO 17 results by simulating 3 cases: - 150,000 barrels of 7.4 pounds of solids to each gallon of slurry at 3000 barrels per day (i.e., a volume representing the approved, historical cutting-slurry disposal injection that occurred during 1997-98); - 1,000,000 barrels of produced water at rates of 1 barrel per minute (i. e., modeling the maximum water handling rate capability on the Tyonek Platform); - 60,000 barrels of 7.4 pounds of solids to each gallon of slurry at 2.4 barrels per minute (i. e., modeling the proposed cuttings disposal injection). All fracture model simulations were run with performance assumptions (i. e., rates, volumes, pressures, and continuous injection) that CPAI states exceed the planned injection. Rock properties and wellbore hydraulic data replicate actual conditions. Modeling indicates single wing fracture lengths up to nearly 400 feet horizontally. The total vertical fracture growth (true vertical thickness) is predicted to be 125 feet. Disposal Injection Order 33 N ~ Page 5 of 9 NCIU B-OlA November 5, 2008 9. Estimated Injection Pressures (20 AAC 25.252(c)(8)) CPAI estimates that the maximum surface injection pressure will be 2500 psig. CPAI modeling indicates the average surface injection pressure will be approximately 1030 psi. A step-rate infectivity test was performed in July 2008 with injection rates up to 2 barrels per minute and injection pressures up to 2116 psi. 10. Mechanical Condition of Wells Penetrating the Disposal Zone Within '/4-Mile of NICU B- OLA (20 AAC 25.252(cZ(12~ Five wells2 penetrate the Sterling within a'/4-mile radius of NCIU B-OIA. Within this area of review, the lateral distance from B-OlA to the offsetting penetrations ranges from 440 feet to approximately 1000 feet. Construction information for each well, including cement tops for casing set across the Sterling is summarized in the injection order application. Detailed well construction information is in Commission well files; this information includes cementing records that indicate cement has been circulated to surface in the surface casing annulus for each of the five wells. In addition, CPAI has summarized the results of Cement Bond Logs run for four of the five wells (no bond log was run in NCIU B-03). Recent wellhead pressures (i. e., tubing, inner annulus, and outer annulus pressures) have also been summarized for the five wells penetrating the '/4-mile area of review. ll.Operatin Intent CPAI intends to simultaneously operate NCIU B-OlA as a waste disposal injection well and a gas production well. NCIU A-12 is similarly operated. CONCLUSIONS: 1. The application requirements and conditions for approval of an underground disposal application in 20 AAC 25.252 have been met. 2. Aquifers below 2900 feet TVD are exempt under 20 AAC 25.440 by AEO 4. 3. Proposed injection sands and confining layers are laterally continuous over the field. Stacked confining zones totaling approximately 185 feet true vertical thickness above and approximately 160 feet true vertical thickness below the injection zone will provide confinement of injected wastes. 4. Injection in NCIU A-12 (which is the same sand interval as proposed for B-OlA) and results from historical injection in B-OlA (1997-98) confirm that injected fluids will remain confined to the intended interval. z The five wells are NCIU A-04, A-06, A-07, A-12, and B-03. Disposal Injection Order 33 • NCIU B-OlA November 5, 2008 Page 6 of 9 5. Based on the modeled injection rates, volumes, fluid densities, and pressures, which exceed expected operating conditions, and the historical injection in the proposed disposal zone common to NCIU B-OlA and NCIU A-12, reasonable grounds exist to conclude that waste fluids should be contained within the receiving intervals by the confining lithologies within the Sterling. Cement isolation of the injection zone in the well bore and operating conditions further support the Commission's conclusion about confinement. Modeling worst case conditions (i. e., continuous injection) predicts a zone of influence (waste plume area) for injected materials to occupy a fracture domain extending approximately 400 feet laterally from the well and vertically 125 feet, all within the identified geologic confinement. Batch injection will likely result in a radial-type disposal domain, reducing the predicted lateral and vertical propagation of the fractures that result from the slurry injection. 6. A I/4-mile area of review is appropriate given the fracture modeling results. 7. Disposal injection operations in NCIU B-OlA will be conducted at rates and pressures below those estimated to fracture through the confining zones. Therefore, oil field wastes injected into B-OlA will be confined to the isolated Sterling disposal injection zone. Successful disposal of 135,000 barrels of slurried Class II drilling waste during 1997-98 in the identified zone confirms injected fluids will be confined. Also, astep-rate infectivity test performed in July 2008 confirms injection is into a confined system. 8. Fluid compatibility in the Sterling disposal zone is not an issue. Operating experience and data from disposal injection-(i) involving similar materials and performance parameters (i. e., pressures, rates, and volumes), (ii) including the historical injection of 135,000 barrels of Class II drilling waste, and (iii) involving the same injection zone in nearby NCIU A-12- provide asuitable analogy for underground disposal using annulus injection tubings in NCIU B-01 A. 9. The mechanical integrity of the five offset wells within the 1/4-mile area of review has been demonstrated by cementing records, bond logs (where available) and annuli pressures. 10. Unique well construction involving two small diameter annulus injection tubings and casing perforations mandate procedures other than pressure testing for demonstrating ongoing mechanical integrity of NCIU B-01 A. 11. Supplemental mechanical integrity demonstrations and the surveillance of injection operations-including temperature surveys, monitoring of injection performance (i. e. , pressures and rates), and analysis of the data for indications of anomalous events-are appropriate to ensure that waste fluids remain within the disposal interval. 12. NCIU B-01 A may simultaneously operate as a completed gas production well (producing up the 5-1/2-inch tubing) and a Class II disposal well (injecting down the two 2-3/8-inch annulus injection tubings installed in the surface casing by conductor casing annulus). Disposal Injection Order 33 NCIU B-OIA November 5, 2008 Page 7 of 9 NOW, THEREFORE, IT IS ORDERED THAT disposal injection is authorized into the Sterling Formation within North Cook Inlet Unit B-OlA subject to each of the following requirements: RULE 1: Infection Strata for Disposal The underground disposal of Class II oil field waste fluids is permitted into the Sterling within NCIU B-OlA in the interval between 3295 feet and 3387 feet TVD. The Commission may immediately suspend, revoke, or modify this authorization if injected fluids fail to be confined. Injection shall only occur down the 2-3/8-inch tubings installed in the 13-3/8-inch surface casing by 20-inch conductor casing annulus. RULE 2: Fluids This authorization is limited to Class II oil field waste fluids generated during drilling, production and workover operations. Included are drilling mud, drill cuttings, reserve pit fluids, rig wash fluids, formation material, completion fluids, produced water, stimulation fluids and other fluids eligible for injection into a Class II disposal well. RULE 3: Infection Rate and Pressure Disposal injection is authorized at (a) rates that do not exceed 2.4 barrels per minute and (b) surface pressures that do not exceed 2500 psig. RULE 4: Demonstration of Mechanical Integrity The mechanical integrity of NCIU B-OlA must be demonstrated before injection begins and before returning the well to service following a workover affecting mechanical integrity. A pump-in differential temperature log shall be run in the 5-1/2-inch production tubing every 2 years to evaluate injected fluid isolation. The anniversary date for the temperature log is the effective date of this order. after the date of entry of this order Ongoing mechanical integrity of the well shall be demonstrated by injection performance monitoring of the surface pressure at static conditions in the 2-3/8-inch annulus injection tubings and open 13-3/8-inch by 9-5/8-inch casing annulus with a known fluid. The results of all mechanical integrity demonstrations and CPAI's interpretation of those results shall be provided to the Commission and be readily available on the Tyonek Platform for Commission inspection. RULE 5: Well Integrity Failure and Confinement Whenever any pressure communication between the production tubing and the casing-tubing annulus is identified, or lack of injection zone isolation is indicated by the injection rate, an operating pressure observation, a test, a survey, a log, or any other evidence, the operator shall notify the Commission by the next business day 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 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 Disposal Injection Order 33 NCIU B-OlA November 5, 2008 Page 8 of 9 must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. RULE 6: Surveillance The operator shall run a baseline differential temperature log in the 5-1/2-inch tubing prior to initial injection. A subsequent temperature log must be run one month after injection begins to delineate the receiving zone of the injected fluids. Surface pressures and rates must be monitored continuously during injection. Results of daily wellhead pressure observations in NCIU B-0l A must be documented and available to the Commission upon request. 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. 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: surface pressures (daily average, maximum and minimum); fluid volumes injected (including 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. RULE 7: Notification of Improper Class II Infection The operator must immediately notify the Commission if it learns of any improper Class II injection. Notification requirements of any other state or federal agency remain 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. Disposal Injection Order 33 • NCIU B-OlA November 5, 2008 Page 9 of 9 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. DONE at Anchorage, Alaska, and dated N ember 5, 2008. ~~~_~. a f ~~ Daniel T. Seamount, Jr., Chair %% RECONSIDERATION AND APPEAL NOTICE ssioner 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 grants 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), "[t]he 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 XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 L_J David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 r~ LJ Cindi Walker Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 James Gibbs Kenai National Wildlife Refuge PO Box 1597 Refuge Manager Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin PO Box 60868 PO Box 70131 Fairbanks, AK 99706 Fairbanks, AK 99707 North Slope Borough PO Box 69 Barrow, AK 99723 d ~ i~f~~ • . Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, November 05, 2008 3:56 PM Subject: dio 33 NCIU B-01A Attachments: dio33.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings; 'Willem Vollenbrock'; 'William Van Dyke'; 'Aleutians East Borough'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones ; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'Matt Rader'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mk1n7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter '; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert 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, C (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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments:dio33.pdf; Jody J. Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 11/5/2008 Page 1 of I Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, November 05, 2008 3:56 PM Subject: dio 33 NCIU B-01A Attachments: dio33.pdf BCC:'Aaron Gluzman ; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; Tom Gennings; 'Willem Vollenbrock'; 'William Van Dyke'; 'Aleutians East Borough'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micallef; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones ; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'Matt Rader'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert 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, C (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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA) Attachments:dio33.pdf; Jody J. Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 11 /5/2008 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov DISPOSAL INJECTION ORDER 33 CANCELLATION Mr. Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Suite 1400 Anchorage, AK 99503 Re: Docket Number: DIO-24-003 Request to cancel Disposal Injection Order No. 33 North Cook Inlet Unit (NCIU) B-01A (PTD 1980020) North Cook Inlet Field, Undefined Waste Disposal Pool Dear Mr. Morse: By email dated June 4, 2024, Hilcorp Alaska, LLC (Hilcorp) requested cancellation of the Disposal Injection Order (DIO) 33. In accordance with 20 AAC 25.252(a), the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS Hilcorp’s request to cancel the DIO. On November 5, 2008, the AOGCC issued DIO 33 to ConocoPhillips Alaska Inc. approving Class II underground disposal of oil field wastes in the NCIU B-01A well. The operator of the well was changed from ConocoPhillips Alaska, Inc., to Hilcorp on November 1, 2016. The last reported disposal occurred in April 2023. The well status is Suspended and AOGCC inspected the well in April 2024. Under Sundry Approval 323-164, the open perforations have been cemented in preparation for a potential re-drill. DIO 33 is no longer necessary to the operation of NCIU B-01A and is hereby CANCELLED. DONE at Anchorage, Alaska, and dated June 6, 2024. Brett W. Huber, Sr Jessie L. Chmielowski Gregory C. Wilson Chair, Commissioner Commissioner Commissioner Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.06.06 09:53:42 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.06.06 09:56:05 -08'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.06 14:32:14 -05'00' DIO 33 Cancellation June 6, 2024 Page 2 of 2 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. 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. From:Coldiron, Samantha J (OGC) To:AOGCC_Public_Notices Subject:[AOGCC_Public_Notices] Disposal Injection Order 33 cancellation (Hilcorp) Date:Thursday, June 6, 2024 12:41:52 PM Attachments:dio33 cancellation.pdf Docket Number: DIO-24-003 Request to cancel Disposal Injection Order No. 33 North Cook Inlet Unit (NCIU) B-01A (PTD 1980020) North Cook Inlet Field, Undefined Waste Disposal Pool Samantha Coldiron AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 __________________________________ List Name: AOGCC_Public_Notices@list.state.ak.us You subscribed as: samantha.coldiron@alaska.gov Unsubscribe at: https://list.state.ak.us/mailman/options/aogcc_public_notices/samantha.coldiron%40alaska.go v INDEXES 8 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:Coldiron, Samantha J (OGC) Subject:Fwd: DIO 33 Cancellation Request Date:Tuesday, June 4, 2024 10:07:21 AM Sam, Can you please create a docket for this DIO action. Thanks Chris From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Tuesday, June 4, 2024 10:05:23 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: DIO 33 Cancellation Request Mr. Wallace, Hilcorp no longer needs to maintain DIO 33 for the operation of our North Cook Inlet assets. All open perforations in well NCIU B-01A (PTD# 198-002) have been cemented, and the well has been converted to Suspended status in preparation for potential re-drill in accordance with Sundry 323-164. As such, please consider this as Hilcorp’s formal request to rescind DIO 33. Please reach out to me if you have any questions. Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ti 4 Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8300 Fax: 907-777-8580 June 6, 2022 Mr. Chris Wallace, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2021 Annual Disposal Report for North Cook Inlet B-01A (DIO 33) Dear Mr. Wallace: In accordance with DIO 33 (rule 6), Hilcorp Alaska, LLC hereby submits the annual disposal report for well North Cook Inlet B-01A (PTD # 198-002) for the year 2021. Surveillance Summary B-01A was used for disposal operations for 4 days and a total of 5753 bbls was injected for 2021. Injection performance was consistent with previous injection performance and injection parameters (pressure and rate) were maintained within the limits set forth in DIO 33. A pump-in differential temperature survey was performed on the 5-1/2” production tubing in the NCIU B-01A on 3/16/2021 and the log confirmed well integrity and confinement. The next temperature survey will be conducted in March of 2023. Should you have questions, please contact Chris Kanyer at 777-8377 or Josh Allely at 777-8505. Sincerely, Chris Kanyer Reservoir Engineer 0 500 1000 1500 2000 2500 3000 3500 4000 0 500 1000 1500 2000 2500 01/2021 02/2021 03/2021 04/2021 05/2021 06/2021 07/2021 08/2021 09/2021 10/2021 11/2021 12/2021 NCIU B-001A TBG TBG 2 (2-3/8")IA OA OOA Water Injection Date Tubing Tubing 2 IA OA OOA Water Injection 12/31/2021 101 0 446 30 0 0 12/30/2021 101 0 446 25 0 0 12/29/2021 102 0 446 23 0 0 12/28/2021 101 0 445 20 0 0 12/27/2021 102 0 446 15 0 0 12/26/2021 103 0 446 10 0 0 12/25/2021 103 0 447 0 0 0 12/24/2021 102 0 456 0 0 0 12/23/2021 104 0 447 0 0 0 12/22/2021 104 0 445 0 0 0 12/21/2021 102 0 444 0 0 0 12/20/2021 104 0 444 0 0 0 12/19/2021 104 0 444 0 0 0 12/18/2021 104 0 444 0 0 0 12/17/2021 105 0 444 0 0 0 12/16/2021 104 0 445 0 0 0 12/15/2021 104 0 445 0 0 0 12/14/2021 104 0 445 0 0 0 12/13/2021 103 0 448 0 0 0 12/12/2021 103 0 444 0 0 0 12/11/2021 104 0 444 0 0 0 12/10/2021 107 0 445 0 0 0 12/9/2021 107 0 445 0 0 0 12/8/2021 108 0 444 0 0 0 12/7/2021 111 0 445 0 0 0 12/6/2021 111 0 445 0 0 0 12/5/2021 111 0 445 0 0 0 12/4/2021 111 0 445 0 0 0 Date Range: 01/01/2021 - 12/31/2021 Well: B-01A S Desc: Shut-In Permit to drill: 1980020 Admin Approval: N/A API: 50-883-20093-01-00 12/3/2021 111 0 445 0 0 0 12/2/2021 111 0 445 0 0 0 12/1/2021 113 0 445 0 0 0 11/30/2021 114 0 445 0 0 0 11/29/2021 113 0 445 0 0 0 11/28/2021 112 0 445 0 0 0 11/27/2021 114 0 445 0 0 0 11/26/2021 115 0 445 0 0 0 11/25/2021 116 0 445 0 0 0 11/24/2021 118 0 445 0 0 0 11/23/2021 118 0 444 0 0 0 11/22/2021 118 0 445 0 0 0 11/21/2021 121 0 444 0 0 0 11/20/2021 121 0 444 0 0 0 11/19/2021 123 0 444 0 0 0 11/18/2021 123 0 444 0 0 0 11/17/2021 125 0 444 0 0 0 11/16/2021 130 0 446 0 0 0 11/15/2021 140 0 444 0 0 0 11/14/2021 139 0 444 0 0 0 11/13/2021 137 0 444 0 0 0 11/12/2021 140 0 444 0 0 0 11/11/2021 150 0 444 0 0 0 11/10/2021 148 0 444 0 0 0 11/9/2021 148 0 444 0 0 0 11/8/2021 154 0 444 0 0 0 11/7/2021 159 0 444 0 0 0 11/6/2021 168 0 444 0 0 0 11/5/2021 178 0 444 0 0 0 11/4/2021 145 0 444 0 0 0 11/3/2021 445 0 444 0 0 0 11/2/2021 445 0 444 0 0 0 11/1/2021 445 0 444 0 0 0 10/31/2021 445 0 444 0 0 0 10/30/2021 445 0 444 0 0 0 10/29/2021 445 0 445 0 0 0 10/28/2021 445 0 444 0 0 0 10/27/2021 444 0 444 0 0 0 10/26/2021 443 0 444 0 0 0 10/25/2021 447 0 447 0 0 0 10/24/2021 443 0 443 0 0 0 10/23/2021 443 0 444 0 0 0 10/22/2021 443 0 444 0 0 0 10/21/2021 443 0 444 0 0 0 10/20/2021 443 0 444 0 0 0 10/19/2021 443 0 444 0 0 0 10/18/2021 443 0 443 0 0 0 10/17/2021 443 0 444 0 0 0 10/16/2021 443 0 444 0 0 0 10/15/2021 443 0 444 0 0 0 10/14/2021 443 0 444 0 0 0 10/13/2021 443 0 444 0 0 0 10/12/2021 445 0 445 0 0 0 10/11/2021 445 0 444 0 0 0 10/10/2021 445 0 445 0 0 0 10/9/2021 445 0 444 0 0 0 10/8/2021 445 0 445 0 0 0 10/7/2021 445 0 445 0 0 0 10/6/2021 445 0 445 0 0 0 10/5/2021 444 0 444 0 0 0 10/4/2021 446 0 445 0 0 0 10/3/2021 444 0 444 0 0 0 10/2/2021 444 0 445 0 0 0 10/1/2021 442 0 444 0 0 0 9/30/2021 443 0 445 0 0 0 9/29/2021 443 0 445 0 0 0 9/28/2021 445 0 445 0 0 0 9/27/2021 445 0 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170 0 0 2/13/2021 403 403 170 0 0 2/12/2021 402 402 170 0 0 2/11/2021 402 402 175 0 0 2/10/2021 402 402 170 0 0 2/9/2021 402 402 170 0 0 2/8/2021 402 402 165 0 0 2/7/2021 400 401 165 0 0 2/6/2021 400 401 155 0 0 2/5/2021 400 401 155 0 0 2/4/2021 401 401 150 0 0 2/3/2021 401 401 145 0 0 2/2/2021 402 402 140 0 0 2/1/2021 402 401 130 0 0 1/31/2021 402 401 125 0 0 1/30/2021 403 402 98 0 0 1/29/2021 403 402 100 0 0 1/28/2021 403 402 101 0 0 1/27/2021 402 402 95 0 0 1/26/2021 402 401 82 0 0 1/25/2021 402 401 70 0 0 1/24/2021 401 401 70 0 0 1/23/2021 402 401 70 0 0 1/22/2021 401 401 70 0 0 1/21/2021 401 400 70 0 0 1/20/2021 401 401 65 0 0 1/19/2021 401 400 64 0 0 1/18/2021 401 400 62 0 0 1/17/2021 401 400 58 0 0 1/16/2021 401 401 88 0 0 1/15/2021 401 401 82 0 0 1/14/2021 401 401 85 0 0 1/13/2021 401 401 85 0 0 1/12/2021 401 401 82 0 0 1/11/2021 402 402 80 0 0 1/10/2021 402 402 75 0 0 1/9/2021 402 402 70 0 0 1/8/2021 403 402 65 0 0 1/7/2021 403 402 150 0 0 1/6/2021 403 401 150 0 0 1/5/2021 403 402 160 0 0 1/4/2021 402 402 175 0 0 1/3/2021 402 403 190 0 0 1/2/2021 402 401 84 0 0 1/1/2021 402 401 56 0 0 Hileorp Alaska, LLC June 30, 2020 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8321 Fax: 907-777-8580 RECEIVED Mr. Chris Wallace, Senior Petroleum Engineer JUL O 6 2020 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 AOGCC Anchorage, Alaska 99501 RE: NCIU Class II injection surveillance summary (DIO 17 and 33) Dear Mr. Wallace: Hilcorp Alaska, LLC ("Hilcorp"), as Operator of North Cook Inlet Field (effective November 2016) hereby submits the report required by DIO 17 (rule 4) and DIO 33 (rule 6) establishing the DIO for the Class II Water Disposal wells at NCIU A-12 and B -01A, respectively for the calendar year of 2019. Surveillance Summary A pump -in differential temperature survey was run performed on the 5-1/2" production tubing in the NCIU B-01 A. No fluid was injected into NCIU A-12 within the year 2019. Sincerely, al n Chris Kanyer Reservoir Engineer 200 Pi All 100 so 0 NCIU A-012 01/201902!201313}2019 0€/201905/201906/201907/201908/201909/201910/201911/201912/2019 — Tubing — IA — OA 200 150 100 50 n Well: A-12 S Desc: Shut -In Permit to drill: 1690990 Admin Approval: N/A API: 50-883-20032-00-00 Date Range: 01/01/2019 - 12/31/2019 Date Tubing IA 12/31/2011. 9 70 12/30/201! 9 69 12/29/201! 9 68 12/28/201! 9 68 12/27/2011. 9 68 12/26/2011. 9 68 12/25/201! 9 69 12/24/201! 9 69 12/23/201! 9 69 12/22/201! 9 69 12/21/201! 9 70 12/20/201! 9 71 12/19/201! 9 71 12/18/201! 9 72 12/17/201! 9 72 12/16/201! 9 72 12/15/201! 9 72 12/14/2011. 9 72 12/13/201! 9 72 12/12/201! 9 72 12/11/201! 9 72 12/10/201! 9 71 12/9/2019 9 72 12/8/2019 9 72 12/7/2019 9 71 12/6/2019 9 70 12/5/2019 9 71 12/4/2019 9 72 OA 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 12/3/2019 9 72 12/2/2019 9 80 12/1/2019 9 80 11/30/201! 9 80 11/29/201! 9 80 11/28/2011. 9 80 11/27/201! 9 80 11/26/201! 9 80 11/25/201! 9 80 11/24/201! 10 80 11/23/201! 10 80 11/22/201! 10 80 11/21/201! 10 80 11/20/201! 10 80 11/19/201! 9 73 11/18/201! 9 74 11/17/201! 9 74 11/16/201! 10 74 11/15/201! 10 74 11/14/201! 10 74 11/13/201! 10 75 11/12/201! 10 75 11/11/201! 9 76 11/10/201! 9 76 11/9/2019 9 76 11/8/2019 9 76 11/7/2019 9 76 11/6/2019 9 75 11/5/2019 9 76 11/4/2019 9 80 11/3/2019 9 80 11/2/2019 9 80 11/1/2019 9 80 10/31/201! 9 80 10/30/201! 9 80 10/29/201! 9 77 10/28/201! 9 77 10/27/201! 9 76 10/26/201! 9 77 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 10/25/201! 9 77 10/24/201! 9 77 10/23/201! 9 77 10/22/201! 9 77 10/21/201! 9 77 10/20/201! 9 77 10/19/201! 10 77 10/18/201! 10 77 10/17/201! 10 77 10/16/201! 10 77 10/15/201! 9 76 10/14/201! 9 80 10/13/201! 9 80 10/12/201! 9 80 10/11/201! 9 85 10/10/201! 9 85 10/9/2019 9 85 10/8/2019 9 85 10/7/2019 9 78 10/6/2019 9 78 10/5/2019 9 78 10/4/2019 9 78 10/3/2019 9 78 10/2/2019 9 78 10/1/2019 9 78 9/30/2019 9 78 9/29/2019 9 78 9/28/2019 9 78 9/27/2019 9 78 9/26/2019 9 79 9/25/2019 9 79 9/24/2019 9 80 9/23/2019 9 80 9/22/2019 9 80 9/21/2019 9 80 9/20/2019 9 80 9/19/2019 9 81 9/18/2019 9 81 9/17/2019 9 81 5 5 5 5 5 5 5 6 5 6 6 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 6 6 6 6 6 6 6 6 6 7 9/16/2019 9 82 9/15/2019 9 82 9/14/2019 9 82 9/13/2019 9 82 9/12/2019 9 82 9/11/2019 9 82 9/10/2019 9 82 9/9/2019 9 84 9/8/2019 9 84 9/7/2019 9 85 9/6/2019 9 85 9/5/2019 9 84 9/4/2019 9 85 9/3/2019 9 85 9/2/2019 9 85 9/1/2019 9 84 8/31/2019 9 84 8/30/2019 9 85 8/29/2019 9 85 8/28/2019 9 85 8/27/2019 9 85 8/26/2019 9 85 8/25/2019 9 85 8/24/2019 9 85 8/23/2019 9 85 8/22/2019 9 85 8/21/2019 9 85 8/20/2019 9 85 8/19/2019 9 85 8/18/2019 9 86 8/17/2019 9 87 8/16/2019 9 86 8/15/2019 9 86 8/14/2019 9 86 8/13/2019 9 86 8/12/2019 9 86 8/11/2019 9 86 8/10/2019 9 86 8/9/2019 9 86 6 6 6 6 6 6 6 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 8/8/2019 9 86 8/7/2019 9 86 8/6/2019 9 86 8/5/2019 9 86 8/4/2019 9 86 8/3/2019 9 86 8/2/2019 9 85 8/1/2019 9 85 7/31/2019 9 85 7/30/2019 9 85 7/29/2019 8 80 7/28/2019 8 80 7/27/2019 8 80 7/26/2019 8 80 7/25/2019 8 80 7/24/2019 8 80 7/23/2019 8 80 7/22/2019 8 85 7/21/2019 8 85 7/20/2019 8 85 7/19/2019 8 85 7/18/2019 8 85 7/17/2019 8 85 7/16/2019 8 85 7/15/2019 8 85 7/14/2019 8 85 7/13/2019 8 85 7/12/2019 8 85 7/11/2019 8 85 7/10/2019 8 85 7/9/2019 8 85 7/8/2019 8 85 7/7/2019 8 85 7/6/2019 8 85 7/5/2019 8 85 7/4/2019 8 85 7/3/2019 8 85 7/2/2019 8 85 7/1/2019 7 80 7 6 7 6 6 6 6 6 6 6 6 6 6 7 7 7 7 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 I 6/30/2019 7 80 6/29/2019 7 80 6/28/2019 7 80 6/27/2019 7 80 6/26/2019 7 80 6/25/2019 7 80 6/24/2019 7 85 6/23/2019 7 85 6/22/2019 7 85 6/21/2019 7 85 6/20/2019 7 85 6/19/2019 7 85 6/18/2019 8 85 6/17/2019 7 SO 6/16/2019 7 80 6/15/2019 7 80 6/14/2019 7 80 6/13/2019 7 80 6/12/2019 7 80 6/11/2019 7 80 6/10/2019 7 80 6/9/2019 7 80 6/8/2019 7 80 6/7/2019 7 80 6/6/2019 8 80 6/5/2019 7 79 6/4/2019 6 80 6/3/2019 7 80 6/2/2019 6 80 6/1/2019 6 80 5/31/2019 7 80 5/30/2019 7 80 5/29/2019 7 80 5/28/2019 7 80 5/27/2019 8 80 5/26/2019 8 81 5/25/2019 8 83 5/24/2019 8 83 5/23/2019 8 83 IN 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 5 5 5 5 5 6 5 6 7 6 6 6 6 6 6 5/22/2019 8 83 5/21/2019 8 82 5/20/2019 7 85 5/19/2019 7 85 5/18/2019 7 85 5/17/2019 7 85 5/16/2019 7 85 5/15/2019 7 85 5/14/2019 7 85 5/13/2019 7 80 5/12/2019 7 80 5/11/2019 7 80 5/10/2019 7 80 5/9/2019 7 80 5/8/2019 7 80 5/7/2019 7 80 5/6/2019 7 85 5/5/2019 7 85 5/4/2019 7 85 5/3/2019 7 85 5/2/2019 7 85 5/1/2019 7 85 4/30/2019 7 85 4/29/2019 7 85 4/28/2019 7 85 4/27/2019 7 85 4/26/2019 7 85 4/25/2019 7 85 4/24/2019 7 85 4/23/2019 7 85 4/22/2019 7 80 4/21/2019 7 80 4/20/2019 7 80 4/19/2019 8 80 4/18/2019 8 80 4/17/2019 8 80 4/16/2019 8 80 4/15/2019 8 80 4/14/2019 8 80 6 6 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 6 5 6 6 6 6 4/13/2019 8 80 4/12/2019 8 80 4/11/2019 8 80 4/10/2019 8 80 4/9/2019 8 80 4/8/2019 9 80 4/7/2019 9 80 4/6/2019 9 80 4/5/2019 9 80 4/4/2019 9 80 4/3/2019 9 80 4/2/2019 9 80 4/1/2019 9 80 3/31/2019 9 80 3/30/2019 9 80 3/29/2019 9 80 3/28/2019 9 80 3/27/2019 9 80 3/26/2019 9 80 3/25/2019 10 80 3/24/2019 10 80 3/23/2019 10 80 3/22/2019 10 80 3/21/2019 10 80 3/20/2019 10 80 3/19/2019 10 80 3/18/2019 11 80 3/17/2019 11 80 3/16/2019 11 80 3/15/2019 11 80 3/14/2019 11 80 3/13/2019 11 80 3/12/2019 11 80 3/11/2019 12 79 3/10/2019 12 79 3/9/2019 12 79 3/8/2019 12 79 3/7/2019 12 79 3/6/2019 12 79 6 6 6 6 6 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 3/5/2019 12 79 3/4/2019 12 79 3/3/2019 12 79 3/2/2019 12 79 3/1/2019 12 80 2/28/2019 12 80 2/27/2019 12 80 2/26/2019 12 80 2/25/2019 12 80 2/24/2019 12 80 2/23/2019 12 80 2/22/2019 12 80 2/21/2019 12 80 2/20/2019 12 80 2/19/2019 12 80 2/18/2019 12 79 2/17/2019 11 78 2/16/2019 11 78 2/15/2019 12 79 2/14/2019 12 78 2/13/2019 12 79 2/12/2019 12 80 2/11/2019 12 80 2/10/2019 12 80 2/9/2019 12 80 2/8/2019 12 80 2/7/2019 12 80 2/6/2019 12 80 2/5/2019 12 81 2/4/2019 12 81 2/3/2019 12 80 2/2/2019 12 81 2/1/2019 12 81 1/31/2019 12 82 1/30/2019 12 80 1/29/2019 12 80 1/28/2019 12 80 1/27/2019 12 80 1/26/2019 12 80 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 5 5 5 5 5 1/25/2019 12 80 1/24/2019 12 80 1/23/2019 12 80 1/22/2019 12 80 1/21/2019 12 85 1/20/2019 12 85 1/19/2019 12 85 1/18/2019 12 85 1/17/2019 12 85 1/16/2019 12 85 1/15/2019 12 85 1/14/2019 12 85 1/13/2019 12 85 1/12/2019 12 85 1/11/2019 12 85 1/10/2019 12 85 1/9/2019 12 85 1/8/2019 12 85 1/7/2019 12 85 1/6/2019 12 85 1/5/2019 12 85 1/4/2019 12 85 1/3/2019 12 85 1/2/2019 12 85 1/1/2019 12 85 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 6 6 6 6 1500 1000 500 N NCIU B -oafs 0112019021201SD3, 20 19 04/20 190 5/2 0 1 9 05/2 0 190 7/2 0 19 08/20 19 0 9, 201910/201911/20191212019 —Tubing — iA — OA OOA — Water Injection ... 500 400 300 200 100 Well: B -01A S Desc: Shut -In Permit to drill: 1980020 Admin Approval: N/A API: 50-883-20093-01-00 Date Range: 01/01/2019 - 12/31/2019 Date Tubing IA OA OOA Water Injection 12/31/201! 53 196 0 0 0 12/30/201! 54 195 0 0 0 12/29/201! 54 195 0 0 0 12/28/201! 54 195 0 0 0 12/27/201! 54 196 0 0 0 12/26/201! 54 196 0 0 0 12/25/201! 54 196 0 0 0 12/24/2011. 54 195 0 0 0 12/23/201! 53 196 0 0 0 12/22/201! 52 194 0 0 0 12/21/201! 53 197 0 0 0 12/20/2011. 53 196 0 0 0 12/19/201! 53 196 0 0 0 12/18/201! 53 196 0 0 0 12/17/2011. 53 195 0 0 0 12/16/201! 54 197 0 0 0 12/15/201! 54 197 0 0 0 12/14/201! 54 197 0 0 0 12/13/201! 54 201 0 0 0 12/12/201! 54 192 0 0 0 12/11/201! 54 192 0 0 0 12/10/201! 54 191 0 0 0 12/9/2019 53 192 0 0 0 12/8/2019 52 194 0 0 0 12/7/2019 53 195 0 0 0 12/6/2019 52 192 0 0 0 12/5/2019 53 195 0 0 0 12/4/2019 52 195 0 0 0 12/3/2019 53 196 0 0 0 12/2/2019 52 194 0 0 0 12/1/2019 52 194 0 0 0 11/30/201! 52 193 0 0 0 11/29/201! 52 192 0 0 0 11/28/201! 52 191 0 0 0 11/27/201! 52 193 0 0 0 11/26/2011. 52 193 0 0 0 11/25/201! 52 194 0 0 0 11/24/201! 52 193 0 0 0 11/23/201! 52 192 0 0 0 11/22/201! 52 193 0 0 0 11/21/201! 52 192 0 0 0 11/20/201! 52 193 0 0 0 11/19/201! 54 191 0 0 0 11/18/2011. 54 196 0 0 0 11/17/201! 54 194 0 0 0 11/16/201! 54 193 0 0 0 11/15/201! 54 192 0 0 0 11/14/2011. 54 193 0 0 0 11/13/201! 54 191 0 0 0 11/12/201! 54 191 0 0 0 11/11/201! 52 193 0 0 0 11/10/201! 52 193 0 0 0 11/9/2019 52 192 0 0 0 11/8/2019 52 190 0 0 0 11/7/2019 53 191 0 0 0 11/6/2019 53 191 0 0 0 11/5/2019 53 193 0 0 0 11/4/2019 53 192 0 0 0 11/3/2019 53 192 0 0 0 11/2/2019 53 193 0 0 0 11/1/2019 53 193 0 0 0 10/31/201! 53 192 50 0 135 10/30/201! 53 192 50 0 221 10/29/201! 53 193 0 0 0 10/28/201! 53 192 0 0 224 10/27/201! 53 194 1560 0 273 10/26/201! 52 193 20 0 201 10/25/201! 52 193 20 0 177 10/24/201! 52 192 0 0 0 10/23/201! 52 192 0 0 99 10/22/201! 53 193 1500 0 338 10/21/201! 54 192 1500 0 201 10/20/201! 54 194 1650 0 223 10/19/201! 54 194 1600 0 303 10/18/201! 54 193 1600 0 179 10/17/201! 54 192 750 0 209 10/16/201! 54 193 850 0 171 10/15/201! 54 193 125 0 35 10/14/201! 52 193 250 0 212 10/13/201! 52 193 325 0 182 10/12/201! 52 195 350 0 255 10/11/201! 52 198 1590 0 315 10/10/201! 52 192 1500 0 203 10/9/2019 52 192 100 0 195 10/8/2019 52 192 175 0 259 10/7/2019 53 190 150 0 275 10/6/2019 53 192 420 0 155 10/5/2019 53 192 650 0 265 10/4/2019 53 189 1600 0 345 10/3/2019 53 190 1590 0 138 10/2/2019 53 190 1600 0 111 10/1/2019 53 188 48 0 212 9/30/2019 53 191 50 0 203 9/29/2019 52 190 1575 0 368 9/28/2019 53 191 1300 0 324 9/27/2019 52 191 360 0 153 9/26/2019 53 191 25 0 120 9/25/2019 53 191 100 0 271 9/24/2019 53 190 1560 0 71 9/23/2019 54 191 0 0 0 9/22/2019 54 191 1550 0 543 9/21/2019 54 189 1550 0 247 9/20/2019 54 190 0 0 165 9/19/2019 54 189 1550 0 465 9/18/2019 54 191 0 0 0 9/17/2019 54 191 0 0 0 9/16/2019 53 190 19 0 312 9/15/2019 53 190 1550 0 255 9/14/2019 52 190 1540 0 172 9/13/2019 53 190 200 0 229 9/12/2019 53 190 4 0 400 9/11/2019 53 191 1545 0 182 9/10/2019 53 190 10 0 167 9/9/2019 53 190 1509 0 343 9/8/2019 53 190 25 0 0 9/7/2019 55 190 25 0 117 9/6/2019 53 192 25 0 398 9/5/2019 55 192 1505 0 0 9/4/2019 55 193 25 0 196 9/3/2019 53 191 25 0 0 9/2/2019 53 192 25 0 0 9/1/2019 53 190 350 0 310 8/31/2019 53 191 125 0 263 8/30/2019 53 190 50 0 104 8/29/2019 53 191 250 0 356 8/28/2019 53 191 30 0 234 8/27/2019 385 378 1600 0 482 8/26/2019 445 400 1500 0 257 8/25/2019 445 397 100 0 0 8/24/2019 445 409 100 0 186.67 8/23/2019 445 422 1550 0 0 8/22/2019 440 440 100 0 0 8/21/2019 53 191 100 0 0 8/20/2019 53 190 100 0 0 8/19/2019 53 191 100 0 0 8/18/2019 53 188 100 0 0 8/17/2019 52 189 100 0 0 8/16/2019 52 191 100 0 0 8/15/2019 52 187 100 0 0 8/14/2019 53 188 100 0 0 8/13/2019 52 186 100 0 0 8/12/2019 54 187 100 0 0 8/11/2019 54 189 100 0 0 8/10/2019 54 188 101 0 0 8/9/2019 54 191 100 0 0 8/8/2019 54 191 100 0 0 8/7/2019 54 192 100 0 0 8/6/2019 54 192 100 0 0 8/5/2019 53 191 100 0 0 8/4/2019 54 191 110 0 0 8/3/2019 53 190 105 0 0 8/2/2019 53 189 100 0 0 8/1/2019 53 187 100 0 0 7/31/2019 53 189 100 0 0 7/30/2019 53 189 100 0 0 7/29/2019 54 188 100 0 0 7/28/2019 54 189 100 0 0 7/27/2019 54 187 100 0 0 7/26/2019 54 188 100 0 0 7/25/2019 54 188 100 0 0 7/24/2019 54 188 100 0 0 7/23/2019 54 190 100 0 0 7/22/2019 53 188 100 0 0 7/21/2019 53 189 100 0 0 7/20/2019 53 189 100 0 0 7/19/2019 52 188 100 0 0 7/18/2019 52 189 100 0 0 7/17/2019 52 187 100 0 0 7/16/2019 53 191 100 0 0 7/15/2019 53 189 100 0 0 7/14/2019 53 187 100 0 0 7/13/2019 53 188 100 0 0 7/12/2019 53 187 100 0 0 7/11/2019 53 186 100 0 0 7/10/2019 53 188 100 0 0 7/9/2019 53 188 100 0 0 7/8/2019 52 189 100 0 0 7/7/2019 52 187 100 0 0 7/6/2019 52 190 100 0 0 7/5/2019 52 188 100 0 0 7/4/2019 52 190 100 0 0 7/3/2019 52 188 100 0 0 7/2/2019 52 188 100 0 0 7/1/2019 54 187 100 0 0 6/30/2019 54 187 100 0 6/29/2019 54 188 100 0 6/28/2019 54 188 100 0 6/27/2019 54 186 100 0 6/26/2019 54 188 100 0 6/25/2019 53 188 100 0 6/24/2019 52 188 100 0 6/23/2019 52 189 100 0 6/22/2019 53 187 100 0 6/21/2019 53 188 100 0 6/20/2019 52 187 100 0 6/19/2019 53 191 100 0 6/18/2019 54 191 100 0 6/17/2019 54 188 100 0 6/16/2019 52 189 110 0 6/15/2019 52 187 110 0 6/14/2019 52 185 110 0 6/13/2019 52 184 110 0 6/12/2019 52 183 110 0 6/11/2019 52 187 110 0 6/10/2019 52 187 110 0 6/9/2019 53 186 109 0 6/8/2019 53 186 110 0 6/7/2019 53 186 100 0 6/6/2019 54 187 100 0 6/5/2019 53 186 100 0 6/4/2019 54 186 100 0 6/3/2019 54 188 100 0 6/2/2019 54 189 100 0 6/1/2019 54 188 100 0 5/31/2019 54 186 100 0 5/30/2019 S4 186 100 0 5/29/2019 54 186 100 0 5/28/2019 54 188 100 0 5/27/2019 52 190 104 0 5/26/2019 78 228 104 0 5/25/2019 53 187 100 0 5/24/2019 53 188 100 0 5/23/2019 53 186 100 0 It 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5/22/2019 53 187 100 0 5/21/2019 53 187 100 0 5/20/2019 53 186 100 0 5/19/2019 53 185 100 0 5/18/2019 53 184 100 0 5/17/2019 53 187 100 0 5/16/2019 53 187 100 0 5/15/2019 53 187 100 0 5/14/2019 52 186 100 0 5/13/2019 53 186 100 0 5/12/2019 53 186 100 0 5/11/2019 53 185 100 0 5/10/2019 53 185 100 0 5/9/2019 52 186 100 0 5/8/2019 52 185 100 0 5/7/2019 53 186 100 0 5/6/2019 52 185 100 0 5/5/2019 52 185 100 0 5/4/2019 52 185 100 0 5/3/2019 52 185 100 0 5/2/2019 52 185 100 0 5/1/2019 52 187 100 0 4/30/2019 52 187 100 0 4/29/2019 52 188 100 0 4/28/2019 52 187 100 0 4/27/2019 52 186 100 0 4/26/2019 52 186 100 0 4/25/2019 52 188 100 0 4/24/2019 52 188 100 0 4/23/2019 52 187 100 0 4/22/2019 54 187 100 0 4/21/2019 54 186 100 0 4/20/2019 54 186 100 0 4/19/2019 54 187 100 0 4/18/2019 54 188 100 0 4/17/2019 54 187 100 0 4/16/2019 54 186 100 0 4/15/2019 54 186 99 0 4/14/2019 53 187 100 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4/13/2019 53 187 100 0 4/12/2019 53 185 100 0 4/11/2019 53 187 100 0 4/10/2019 53 184 100 0 4/9/2019 52 186 100 0 4/8/2019 53 184 100 0 4/7/2019 53 186 100 0 4/6/2019 53 184 100 0 4/5/2019 53 184 100 0 4/4/2019 53 184 100 0 4/3/2019 54 186 100 0 4/2/2019 54 185 100 0 4/1/2019 53 184 100 0 3/31/2019 53 186 100 0 3/30/2019 53 186 100 0 3/29/2019 53 186 100 0 3/28/2019 53 185 100 0 3/27/2019 53 185 100 0 3/26/2019 53 185 100 0 3/25/2019 54 187 100 0 3/24/2019 54 187 100 0 3/23/2019 54 185 100 0 3/22/2019 54 186 100 0 3/21/2019 54 186 100 0 3/20/2019 54 187 100 0 3/19/2019 54 186 100 0 3/18/2019 53 186 100 0 3/17/2019 53 186 100 0 3/16/2019 53 185 100 0 3/15/2019 53 187 100 0 3/14/2019 53 186 100 0 3/13/2019 53 186 100 0 3/12/2019 53 187 100 0 3/11/2019 53 185 100 0 3/10/2019 53 186 100 0 3/9/2019 53 184 100 0 3/8/2019 53 184 100 0 3/7/2019 53 186 100 0 3/6/2019 53 186 100 0 [C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3/5/2019 53 187 100 0 3/4/2019 53 186 100 0 3/3/2019 53 186 100 0 3/2/2019 53 187 100 0 3/1/2019 53 185 100 0 2/28/2019 53 186 100 0 2/27/2019 53 185 100 0 2/26/2019 54 186 100 0 2/25/2019 54 186 100 0 2/24/2019 54 193 100 0 2/23/2019 54 193 99 0 2/22/2019 54 192 100 0 2/21/2019 54 193 100 0 2/20/2019 54 190 100 0 2/19/2019 54 191 100 0 2/18/2019 53 191 98 0 2/17/2019 53 191 99 0 2/16/2019 53 192 98 0 2/15/2019 53 191 99 0 2/14/2019 53 193 99 0 2/13/2019 53 192 99 0 2/12/2019 53 192 104 0 2/11/2019 53 192 104 0 2/10/2019 53 193 104 0 2/9/2019 53 192 104 0 2/8/2019 54 192 104 0 2/7/2019 54 193 104 0 2/6/2019 54 194 104 0 2/5/2019 53 194 104 0 2/4/2019 52 192 104 0 2/3/2019 53 193 104 0 2/2/2019 54 195 104 0 2/1/2019 53 192 104 0 1/31/2019 53 193 104 0 1/30/2019 54 195 104 0 1/29/2019 54 195 104 0 1/28/2019 54 194 104 0 1/27/2019 54 194 104 0 1/26/2019 54 195 104 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1/25/2019 54 195 104 0 1/24/2019 54 194 104 0 1/23/2019 54 195 104 0 1/22/2019 54 195 104 0 1/21/2019 53 194 104 0 1/20/2019 52 195 104 0 1/19/2019 53 195 104 0 1/18/2019 52 196 104 0 1/17/2019 53 196 104 0 1/16/2019 53 197 104 0 1/15/2019 53 196 104 0 1/14/2019 53 197 103 0 1/13/2019 53 196 103 0 1/12/2019 53 196 103 0 1/11/2019 53 196 103 0 1/10/2019 53 197 105 0 1/9/2019 53 196 105 0 1/8/2019 53 196 105 0 1/7/2019 53 198 105 0 1/6/2019 53 197 105 0 1/5/2019 53 198 105 0 1/4/2019 53 199 105 0 1/3/2019 53 203 105 0 1/2/2019 52 200 105 0 1/1/2019 53 199 105 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907-777-8321 Fax: 907-777-8580 July 1, 2019 Mr. Chris Wallace, Senior Petroleum Engineer LE D Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue, Suite 100 2019 Anchorage, Alaska 99501 AOGCC RE: NCIU Class II injection surveillance summary (DIO 17 and 33) Dear Mr. Wallace: Hilcorp Alaska, LLC ("Hilcorp"), as Operator of North Cook Inlet Field (effective November 2016) hereby submits the report required by DIO 17 (rule 4) and DIO 33 (rule 6) establishing the DIO for the Class II Water Disposal wells at NCIU A-12 and 13-01A, respectively for the calendar year of 2018. Surveillance Summary No fluid was injected into NCIU A-12 or NCIU 13-01A within the year 2018. Sincerely, fig. Z - Tommy Nenahlo Reservoir Engineer m W, X11 300 200 100 0 NCIU 0-001A 01/2018 02/2018 03/2018 04/2018 05/2018 06/2018 07/2018 08/2018 09/2018 10/2018 11/2018 12/2018 — Tubing — IA — OA OOA — Gas Production 2000 1500 1000 - Well: B -01A S Desc: Shut -In Permit to drill: 1980020 Admin Approval: N/A API: 50-883-20093-01-00 Date Range: 01/01/2018 - 12/31/2018 Date Tubing IA OA OOA Gas Production 12/31/2018 54 200 104 0 969.2541 12/30/2018 54 200 104 0 969.053 12/29/2018 54 202 104 0 969.2139 12/28/2018 54 202 104 0 968.9424 12/27/2018 54 201 104 0 969.3647 12/26/2018 54 202 104 0 965.4032 12/25/2018 54 202 105 0 961.2104 12/24/2018 53 201 105 0 954.5543 12/23/2018 53 204 104 0 934.5959 12/22/2018 53 202 104 0 828.188 12/21/2018 53 205 104 0 816.2632 12/20/2018 53 206 104 0 962.0952 12/19/2018 53 208 104 0 963.1007 12/18/2018 52 209 102 0 962.3164 12/17/2018 52 209 102 0 963.714 12/16/2018 52 210 102 0 964.4078 12/15/2018 52 209 102 0 964.4882 12/14/2018 52 213 102 0 962.598 12/13/2018 52 214 102 0 962.8895 12/12/2018 53 218 105 0 963.5833 12/11/2018 53 220 105 0 963.895 12/10/2018 53 225 105 0 964.2369 12/9/2018 54 230 104 0 962.9599 12/8/2018 53 231 104 0 968.5201 12/7/2018 53 234 104 0 963.6034 12/6/2018 53 235 104 0 965.2021 12/5/2018 52 240 104 0 960.1346 12/4/2018 53 238 104 0 959.2498 12/3/2018 52 239 104 0 883.3677 12/2/2018 52 238 104 0 951.6485 12/l/2018 52 239 104 0 933.6206 11/30/2018 54 240 104 0 661.0201 11/29/2018 54 250 104 0 969.4753 11/28/2018 54 252 104 0 970.7221 11/27/2018 54 255 104 0 973.5374 11/26/2018 54 257 104 0 966.0266 11/25/2018 53 258 104 0 973.7887 11/24/2018 54 259 104 0 978.5144 11/23/2018 53 259 104 0 928.6637 11/22/2018 52 261 104 0 982.0134 11/21/2018 53 270 105 0 981.6012 11/20/2018 53 272 105 0 981.7721 11/19/2018 53 272 104 0 992.43 11/18/2018 52 274 104 0 993.3047 11/17/2018 52 274 104 0 982.8077 11/16/2018 52 277 105 0 991.7262 11/15/2018 52 280 104 0 990.6101 11/14/2018 52 281 105 0 992.8824 11/13/2018 52 296 105 0 992.9528 11/12/2018 52 296 105 0 979.8617 11/11/2018 52 295 105 0 990.6101 11/10/2018 52 295 105 0 989.7655 11/9/2018 52 294 105 0 984.6779 11/8/2018 52 296 105 0 978.7658 11/7/2018 52 298 105 0 961.4417 11/6/2018 52 303 105 0 994.5213 11/5/2018 54 306 104 0 989.5443 11/4/2018 54 308 104 0 1028.757 11/3/2018 53 310 104 0 1020.492 11/2/2018 53 310 104 0 1010.086 11/1/2018 54 311 104 0 1012.861 10/31/2018 54 312 104 0 1015.013 10/30/2018 54 312 104 0 1423.984 10/29/2018 54 313 104 0 1004.727 10/28/2018 54 325 104 0 987.0407 10/27/2018 54 324 104 0 992.3697 10/26/2018 54 322 104 0 1002.263 10/25/2018 54 326 104 0 1007.753 10/24/2018 54 327 104 0 1004.415 10/23/2018 54 335 104 0 1008.296 10/22/2018 54 331 104 0 1007.562 10/21/2018 54 326 104 0 1007.854 10/20/2018 54 330 104 0 996.7334 10/19/2018 54 336 104 0 986.3168 10/18/2018 54 333 104 0 1008.608 10/17/2018 54 331 104 0 1007.633 10/16/2018 54 340 104 0 1005.25 10/15/2018 53 341 105 0 1007.18 10/14/2018 53 346 105 0 1010.026 10/13/2018 53 348 106 0 1019.939 10/12/2018 54 370 106 0 950.0196 10/11/2018 53 372 104 0 987.825 10/10/2018 53 376 104 0 1009.975 10/9/2018 53 376 104 0 1008.95 10/8/2018 54 380 104 0 1007.2 10/7/2018 53 380 104 0 995.3157 10/6/2018 54 384 105 0 1017.697 10/5/2018 54 398 105 0 1452.217 10/4/2018 54 399 105 0 1173.715 10/3/2018 54 397 106 0 1020.543 10/2/2018 54 371 106 0 1020.714 10/1/2018 54 381 104 0 1015.465 9/30/2018 54 379 104 0 1012.69 9/29/2018 54 385 104 0 1000.655 9/28/2018 54 390 104 0 972.4213 9/27/2018 54 392 104 0 843.8933 9/26/2018 54 392 104 0 970.712 9/25/2018 54 411 104 0 1027.943 9/24/2018 54 418 104 0 1029.21 9/23/2018 54 424 104 0 1022.473 9/22/2018 54 424 104 0 1014.068 9/21/2018 54 424 104 0 1012.59 9/20/2018 54 424 104 0 1049.168 9/19/2018 54 424 104 0 1080.016 9/18/2018 54 424 105 0 1045.549 9/17/2018 54 423 106 0 1030.879 9/16/2018 53 426 106 0 1036.519 9/15/2018 53 426 105 0 1041.547 9/14/2018 53 426 106 0 1044.815 9/13/2018 54 430 106 0 1045.88 9/12/2018 53 429 106 0 1039.787 9/11/2018 53 429 105 0 1039.516 9/10/2018 54 430 104 0 1040.903 9/9/2018 53 430 104 0 1041.999 9/8/2018 54 430 104 0 1043.095 9/7/2018 53 432 106 0 1044.503 9/6/2018 53 433 106 0 1044.121 9/5/2018 54 432 106 0 1039.104 9/4/2018 54 431 106 0 1041.889 9/3/2018 54 432 104 0 1077.583 9/2/2018 54 431 104 0 1064.853 9/1/2018 54 434 104 0 1062.31 8/31/2018 54 434 104 0 1064.079 8/30/2018 54 429 104 0 1063.325 8/29/2018 54 414 104 0 970.9332 8/28/2018 54 432 104 0 1064.884 8/27/2018 54 436 104 0 1066.824 8/26/2018 54 436 105 0 1066.955 8/25/2018 54 437 104 0 1067.719 8/24/2018 54 440 104 0 1067.528 8/23/2018 54 439 104 0 1066.16 8/22/2018 54 440 104 0 1070.464 8/21/2018 54 442 104 0 1072.022 8/20/2018 52 443 104 0 1071.238 8/19/2018 52 443 105 0 1068.302 8/18/2018 52 444 105 0 1067.96 8/17/2018 52 447 105 0 1069.67 8/16/2018 52 444 105 0 1071.258 8/15/2018 52 444 105 0 1071.228 8/14/2018 52 446 105 0 1074.637 8/13/2018 54 446 104 0 1072.736 8/12/2018 54 448 104 0 1070.755 8/11/2018 54 449 104 0 1070.323 8/10/2018 54 450 104 0 1070.635 8/9/2018 54 450 104 0 1072.847 8/8/2018 54 449 104 0 1071.198 8/7/2018 53 435 104 0 1066.814 8/6/2018 52 435 104 0 1068.855 8/5/2018 53 436 104 0 1108.5 8/4/2018 53 433 104 0 1095.731 8/3/2018 52 437 104 0 1082.771 8/2/2018 52 439 104 0 1092.262 8/1/2018 53 425 104 0 1096.948 7/31/2018 53 418 104 0 1111.426 7/30/2018 52 402 105 0 1113.166 7/29/2018 52 403 105 0 1113.075 7/28/2018 52 405 105 0 1115.78 7/27/2018 52 406 105 0 1111.738 7/26/2018 52 408 105 0 1099.894 7/25/2018 52 409 105 0 1110.109 7/24/2018 52 409 105 0 1113.488 7/23/2018 52 412 105 0 1113.286 7/22/2018 53 413 105 0 1115.187 7/21/2018 53 415 105 0 1115.679 7/20/2018 52 416 105 0 1115.971 7/19/2018 53 417 105 0 1117.489 7/18/2018 53 418 105 0 1117.831 7/17/2018 52 418 106 0 1160.714 7/16/2018 52 424 106 0 1243.825 7/15/2018 53 419 106 0 1119.852 7/14/2018 53 418 105 0 1122.004 7/13/2018 53 417 105 0 1120.958 7/12/2018 53 426 105 0 1119.068 7/11/2018 53 421 105 0 1119.56 7/10/2018 52 422 105 0 1121.179 7/9/2018 54 424 104 0 1118.987 7/8/2018 54 425 104 0 1104.277 7/7/2018 54 425 104 0 1096.254 7/6/2018 54 427 104 0 1101.965 7/5/2018 54 430 104 0 1092.765 7/4/2018 54 434 104 0 1111.828 7/3/2018 54 434 104 0 1116.594 7/2/2018 54 437 104 0 1179.647 7/1/2018 54 437 104 0 1188.505 6/30/2018 54 452 104 0 1188.254 6/29/2018 54 453 104 0 1185.79 6/28/2018 54 459 104 0 1187.52 6/27/2018 54 464 104 0 1186.534 6/26/2018 54 469 102 0 1187.942 6/25/2018 53 472 106 0 1187.429 6/24/2018 53 471 106 0 1186.574 6/23/2018 53 470 106 0 1186.132 6/22/2018 53 470 102 0 1180.26 6/21/2018 54 487 106 0 1176.52 6/20/2018 52 484 106 0 1178.943 6/19/2018 53 485 106 0 1183.478 6/18/2018 54 482 105 0 1182.955 6/17/2018 53 480 106 0 1181.286 6/16/2018 52 477 106 0 1180.401 6/15/2018 54 481 106 0 1177.274 6/14/2018 53 478 106 0 1177.284 6/13/2018 52 478 105 0 1172.82 6/12/2018 53 478 105 0 1172.458 6/11/2018 53 480 105 0 1173.061 6/10/2018 52 482 105 0 1169.723 6/9/2018 53 483 105 0 1172.237 6/8/2018 53 483 105 0 1181.809 6/7/2018 52 484 105 0 1160.362 6/6/2018 53 491 105 0 1147.472 6/5/2018 53 488 105 0 1140.937 6/4/2018 53 483 105 0 1123.713 6/3/2018 52 485 105 0 1124.819 6/2/2018 52 481 105 0 691.4956 6/1/2018 52 160 105 0 236.5548 5/31/2018 52 495 105 0 1012.037 5/30/2018 52 496 105 0 1165.983 5/29/2018 52 489 105 0 1252.402 5/28/2018 53 489 105 0 1229.739 5/27/2018 52 494 105 0 1167.239 5/26/2018 52 492 105 0 1158.21 5/25/2018 52 485 105 0 1176.681 5/24/2018 52 492 105 0 1146.095 5/23/2018 53 492 105 0 1160.784 5/22/2018 53 498 105 0 1090.261 5/21/2018 53 487 104 0 1168.738 5/20/2018 52 483 104 0 1169.653 5/19/2018 52 483 104 0 1168.134 5/18/2018 53 482 104 0 1168.094 5/17/2018 52 484 104 0 1169.743 5/16/2018 52 481 104 0 1170.648 5/15/2018 54 483 104 0 1180.341 5/14/2018 54 481 104 0 1180.602 5/13/2018 54 482 104 0 1179.687 5/12/2018 54 482 104 0 1152.218 5/11/2018 54 483 104 0 1131.727 5/10/2018 54 483 104 0 1130.088 5/9/2018 54 483 104 0 1147.1 5/8/2018 54 484 104 0 1149.151 5/7/2018 54 488 104 0 1059.072 5/6/2018 54 481 104 0 1161.056 5/5/2018 54 480 104 0 1170.487 5/4/2018 54 480 104 0 1172.428 5/3/2018 54 485 104 0 1179.023 5/2/2018 54 481 103 0 1182.754 5/1/2018 54 480 102 0 1193.784 4/30/2018 53 485 104 0 1111.678 4/29/2018 53 485 104 0 1218.488 4/28/2018 53 487 104 0 1182.1 4/27/2018 52 490 104 0 1132.089 4/26/2018 52 489 104 0 1159.517 4/25/2018 54 494 104 0 1067.277 4/24/2018 52 478 104 0 734.4891 4/23/2018 54 479 104 0 1165.641 4/22/2018 52 477 104 0 1164.344 4/21/2018 52 476 105 0 1164.907 4/20/2018 52 475 105 0 1165.279 4/19/2018 52 476 105 0 1165.51 4/18/2018 55 477 104 0 1164.766 4/17/2018 53 510 104 0 1163.71 4/16/2018 52 505 104 0 1163.881 4/15/2018 52 501 104 0 1163.781 4/14/2018 52 498 104 0 1163.7 4/13/2018 52 495 104 0 1163.439 4/12/2018 52 490 104 0 1161.921 4/11/2018 52 486 104 0 1165.631 4/10/2018 52 483 104 0 1213.923 4/9/2018 55 481 104 0 1215.109 4/8/2018 52 477 104 0 1216.758 4/7/2018 52 476 104 0 1193.693 4/6/2018 55 481 104 0 1206.292 4/5/2018 52 473 104 0 1208.886 4/4/2018 53 476 104 0 1203.979 4/3/2018 54 472 104 0 1195.784 4/2/2018 52 473 104 0 1187.168 4/1/2018 52 470 104 0 1184.755 3/31/2018 52 473 104 0 1741.649 3/30/2018 53 472 104 0 1733.243 3/29/2018 53 469 104 0 1724.979 3/28/2018 52 474 104 0 1731.484 3/27/2018 51 471 104 0 1801.253 3/26/2018 52 472 104 0 1805.245 3/25/2018 53 478 104 0 1682.025 3/24/2018 53 485 104 0 1641.696 3/23/2018 53 482 104 0 1704.809 3/22/2018 53 482 104 0 1357.855 3/21/2018 53 468 104 0 1637.302 3/20/2018 53 483 104 0 1524.439 3/19/2018 54 487 102 0 1488.635 3/18/2018 54 487 102 0 1402.849 3/17/2018 54 490 102 0 1488.444 3/16/2018 54 491 102 0 1559.962 3/15/2018 54 487 102 0 1321.708 3/14/2018 54 480 102 0 1551.325 3/13/2018 52 551 102 0 1442.313 3/12/2018 51 495 102 0 1544.408 3/11/2018 53 481 110 0 1207.277 3/10/2018 53 489 110 0 1463.076 3/9/2018 53 495 110 0 1410.048 3/8/2018 53 492 110 0 1375.802 3/7/2018 53 461 110 0 520.5873 3/6/2018 54 460 110 0 360.6789 3/5/2018 54 487 102 0 1235.329 3/4/2018 54 488 102 0 1238.386 3/3/2018 54 481 102 0 1243.675 3/2/2018 54 489 102 0 1252.06 3/1/2018 54 490 102 0 1304.636 2/28/2018 54 486 102 0 1303.771 2/27/2018 54 484 101 0 1223.626 2/26/2018 58 501 103 0 1264.93 2/25/2018 59 505 104 0 1204.924 2/24/2018 57 506 103 0 995.8485 2/23/2018 59 513 103 0 945.6258 2/22/2018 58 503 103 0 1177.958 2/21/2018 55 499 103 0 1155.787 2/20/2018 55 493 102 0 1158.291 2/19/2018 56 495 102 0 1176.902 2/18/2018 56 498 102 0 1006.185 2/17/2018 56 500 102 0 1191.31 2/16/2018 55 497 102 0 1201.335 2/15/2018 56 498 102 0 1211.269 2/14/2018 56 500 102 0 1196.016 2/13/2018 56 497 102 0 1194.156 2/12/2018 56 496 100 0 1159.025 2/11/2018 56 498 100 0 1173.966 2/10/2018 56 500 100 0 1187.711 2/9/2018 57 502 102 0 1206.07 2/8/2018 57 502 102 0 1222.56 2/7/2018 58 499 102 0 1214.747 2/6/2018 58 501 102 0 1212.545 2/5/2018 58 500 102 0 1235.983 2/4/2018 57 501 102 0 1214.446 2/3/2018 57 499 100 0 1154.49 2/2/2018 56 496 102 0 1195.573 2/1/2018 56 493 102 0 1201.526 1/31/2018 56 494 102 0 1200.862 1/30/2018 56 504 102 0 1541.07 1/29/2018 53 489 102 0 1134.12 1/28/2018 52 490 102 0 1119.641 1/27/2018 51 493 102 0 1119.842 1/26/2018 52 497 102 0 1111.477 1/25/2018 53 494 102 0 1117.097 1/24/2018 54 494 102 0 1103.634 1/23/2018 53 492 102 0 1116.856 1/22/2018 54 492 101 0 1116.926 1/21/2018 54 491 101 0 1116.152 1/20/2018 54 494 101 0 1121.692 1/19/2018 54 498 101 0 1162.192 1/18/2018 54 483 102 0 1031.13 1/17/2018 54 474 100 0 1228.412 1/16/2018 54 486 100 0 1069.277 1/15/2018 54 498 102 0 1072.374 1/14/2018 54 492 102 0 1172.458 1/13/2018 54 492 102 0 1281.59 1/12/2018 54 495 102 0 1243.614 1/11/2018 54 493 102 0 1222.479 1/10/2018 54 496 102 0 1108.913 1/9/2018 54 497 101 0 1247.214 1/8/2018 54 502 101 0 1134.19 1/7/2018 54 504 101 0 1117.208 1/6/2018 54 519 101 0 1077.341 1/5/2018 54 480 101 0 1281.269 1/4/2018 54 480 101 0 1230.654 1/3/2018 54 478 103 0 1105.655 1/2/2018 54 479 101 0 1138.896 1/1/2018 53 480 101 0 1137.97 Hilcorp Alaska, LLC RECEIVE® 3800 Centerpoint Drive Suite 1400 MAR 31 2017 Anchorage, AK 99503 Phone:907-777-8321 A-,0G V V Fax: 907-777-8580 March 27, 2017 Ms. Cathy P. Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: NCIU Class II injection surveillance summary (DIO 17 and 33) Dear Ms. Foerster: Hilcorp Alaska, LLC ("Hilcorp"), as Operator of North Cook Inlet Field (effective November 2016) hereby submits the report required by DIO 17 (rule 4) and DIO SS (rule 6) establishing the DIO for the Class II Water Disposal wells at NCIU A-12 and 13-01A, respectively for the calendar year of 2016. Surveillance Summary No fluid was injected into NCIU A-12 and minimal volumes were injected into NCIU 13- 01 A within the year 2016. A passing mechanical integrity test was performed on the well on 5/10/2015 and is required bi-annually to retain disposal approval status. Reservoir Engineer • • Fisher, Samantha J (DOA) From: Regg, James B (DOA) Sent: Tuesday, July 31, 2012 2:57 PM To: Fisher, Samantha J (DOA); Colombie, Jody J (DOA) Cc: Wallace, Chris D (DOA) Subject: FW: NCI B -01A Annual Surveillance Report (198 -002) DIO 33 Rule 6 Attachments: NCIU B -01A Well Diagram.pdf; B -01A Injection 4 -23 -12 Temp Log.pdf; NCI B -01A Annual Report 2012 6- 28.doc; NCI B -01AD 2012 6 -27 ProductioPressure Data.pdf Follow Up Flag: Follow up Flag Status: Flagged Unclear if they also sent paper copy; please file (DIO 33). Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Dethlefs, Jerry C [mailto: Jerry.C.Dethlefs @conocophilliDs.com] Sent: Saturday, June 30, 2012 3:36 PM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); Buck, Brian R; Dethlefs, Jerry C; Longbrake, Amanda (PDS Technical Services) Subject: NCI B -01A Annual Surveillance Report (198 -002) DIO 33 Rule 6 Jim: Attached please find the Annual Surveillance Report for NCIU B -01 A Class II disposal well as required by DIO 33 Rule 6. This well has not be used for disposal injection for the calendar year, as previously reported with a communication problem, will remain shut -in until packoff repairs can be implemented. Also please note a temperature survey has recently been performed on the well (attached). To perform the temperature survey 300 bbls of water was pumped into the disposal string. Please let me know if you have any questions. Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska Office: 907 - 265 -1464 Cell: 907 - 268 -9188 1 • (Conoco- Phillips 0 Well:IB -01A I Fiellitnek 104 -23 -2012 I Pressure (psia) 300 400 500 600 700 800 900 1000 1100 0 I • I 41111 , 500 - -i 7 I Pressure - Temperature Profile 1. RIH Overlay 2. Before Inj. vs After Inj. 1000 — ` - - - 1500 - - 2000 -- -- - - -- _ 2500 I ` — 0 3000 - \,, 01 3500 e D 4000 r Q C i T 4500= — - --- - -- S we 5000 • . — K 5500 = -- � r \ IC 6000 U no 6500 II= \� -01111/16:. 1l ...."..1"4 7000 7500 40 50 60 70 80 90 100 110 120 Post Pressure - Perfs A Valve 30" 20" 13 3/8" 9 5/8" TBG " Packer — —Pre Psia Post Temperature - - - Pre Temp Report date: 6/30/2012 S N B -01AD Start tring Date ame 7/1/2011 Days 366 End Date 7/1/2012 IA Cook Inlet Production & Pressure Data OA WHP WHT 700 - — - -- - - - 200 — 180 600 — 160 • 500 - — 140 • �^ — 120 400 — — H a — 100 300 — 80 200 — 60 — 40 100 - — 20 0 4 - ►— 0 Jul -11 Aug -11 Sep -11 Oct -11 Nov -11 Dec -11 Jan -12 Feb -12 Mar -12 Apr -12 May -12 Jun -12 • Gas Vol - - -- Water Vol - -Inj Vol 1 -- -1.2 0.9 — 1 o.a v 0.7 - 0.8 22 0.6 - a 0.5 0.6 3 N 0.4 - 0.4 E 0.3 0.2 - 0.2 0.1 0 (-0 Jul -11 Aug -11 Sep -11 Oct -11 Nov -11 Dec -11 Jan -12 Feb -12 Mar -12 Apr -12 May -12 Jun -12 Date SAK . NCI B -01A Attrl Angle Max An le & MD TD ConocoPhillips ® ! Alaska, Inc. Welibore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) c j 508832009301 COOK INLET PROD 38.53 7,939.01 16,720.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: TRDP Last WO: 12/18/2003 10/21/1997 Well Confiq: - NCI B-01A, 4/26/2012 3:03:20 PM - - -- Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 8,807.0 7/31/2011 Rev Reason: GLV C/O ninam 4/26/2012 HANGER, 54 - - Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd CONDUCTOR 30 27.000 54.0 407.0 407.0 120.00 H WELDED I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 20 19.124 54.0 2,579.0 2,510.9 94.00 K - 55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, INTERMEDIATE 13 3/8 12.347 54.0 3,760.0 3,514.8 72.00 N -80 54 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETY VLV, - PRODUCTION 9 5/8 8.535 54.0 10,376.0 53.50 P - 110 INS 410 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd ii. UV LINER 5 4.408 3,588.0 16,720.0 16.25 S135 GAS; LIFT, It Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd DISPOSAL, 54 TUBING Upper 5 1/2 4.950 53.6 3,687.8 3,457.1 15.50 L -80 BTCMOD SURFACE, 54-2,579 Completion Details GAS LIFT, Top Depth 2,675 (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) IPERF, 53.6 53.6 0.35 HANGER FMC TUBING HANGER 5.500 3,000 -3,540 I 409.9 409.9 0.27 SAFETY VLV CAMCO TRM-4E TR SSSV 4.562 GAS LIFT, - 3,667.1 3,440.6 37.73 SEAL ASSY BAKER S -22 PBR Anchor Seal Assembly w/15' seals 4.750 3,602 IIK Mil Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 TUBING Lower 5 1/2 4.950 3,670.5 3,763.6 3,517.6 15.50 L -80 BTCM SEAL ASSY, I JIIL Completion Details 3,667 - \,. : Top Depth PBR, 3,671 (TVD) Top Inc! Nomi... III Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) N 3,670.5 3,443.3 37.70 PBR 190 -60 PBR w/15' SEAL TRAVEL 4.750 IIM NIPPLE, 3,700 3,700.5 3,467.1 37.47 NIPPLE 'X' LANDING NIPPLE 4.562 IIIMI 3,762.4 3,516.7 37.01 SEAL ASSY 190-60 S -22 ANCHOR LATCH SEAL ASSEMBLY (ABOVE SC -1 R 4.750 PACKER) NTERMEDIATE, _ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... I String ... String Top Thrd 54 -3,760 SEAL ASSY, GRAVEL PACK 4 3.500 3,763.7 6,868.0 6,026.8 15.50 1 SLHT 3,762 - Completion Details PACKER, 3,764 - Top Depth KOIV, 3,797 a ?, (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) SLOTS, 3,763.7 3,517.7 37.00 PACKER BAKER SC-1R PACKER 6.000 3,850 -3,869 SLOTS, 3,796.7 3,543.9 36.75 KOIV BAKER KOIV MODEL C 5.000 3,886 -3,893 4,015.7 3,720.7 35.48 RA BLANK RADIOACTIVE MARKER IN COLLAR 4.892 SCREEN, SLOTS, N - � M 4,024.5 3,727.9 35.43 SCREEN 3.600 a,, �� , � 4,367.7 4,009.4 35.01 PACKER BAKER SC-1R PACKER 4.940 SLOTS, - -" 4,275 275 -44,365 365 r ��� 4,370.7 4,011.9 35.03 SCREEN 3.600 PACKER, 4,368 4,608.7 4,205.3 37.31 RA BLANK RADIOACTIVE MARKER IN COLLAR 4.892 SLOTS, !WI . 4,429-4,480 ,371 - � SCREEN, EN, 4,371 4,617.5 4,212.3 37.27 SCREEN 3.600 - -- - ► 4,880.7 4,423.4 35.97 RA BLANK RADIOACTIVE MARKER IN COLLAR 4.892 SCREEN, 4,618 --,,, SLOTS, 4,968.7 4,494.7 35.77 SUMP BAKER SC -2 SUMP PACKER 4.940 .. - -..__ - - -- 4,751 -4,761 • s" PACKER SLOTS, 4,792 -4,803 - ;� A 5,578.7 4,987.8 38.00 NIPPLE BAKER 'X' NIPPLE 3.813 5,613.2 5,014.9 37.67 PACKER BAKER SC -1R PACKER 4.750 SLOTS, 4,922 -4,955 5,646.9 5,041.7 37.35 KOIV 3.500 SUMP 5,648.8 5,043.2 37.33 SCREEN 3.500 PACKER, 4,969 - NIPPLE, 5,579 6,786.8 5,959.5 34.30 SUMP BAKER SC -2 SUMP PACKER 6.000 PACKER PACKER, 5,613 �` 6,836.4 6,000.8 34.66 NIPPLE BAKER 'X' NIPPLE 2.813 KOIV, 5s47 I' 6,867.2 6,026.1 34.52 WLEG BAKER WIRELINE ENTRY GUIDE 2.992 SLOTS, I' -- --- 5,718 -5,742 Other In Hole (Wireline retrievable plugs valves, pumps, fish, etc.) SLOTS, Top Depth , 5,885 - 5,892 SLOTS, (TVD) Top Inc! 5,929 - 5,939 I Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) SLOTS, 54 54.0 0.35 DISPOSAL 2 3/8" DISPOSAL STRING TO 3663' 7/31/1997 5,948 -5,969 SLOTS, 10,010 8,545.6 35.60 PLUG PXN PLUG 9/27/2002 0.000 5,995 -6,032 10,073 8,596.9 35.91 PLUG PXN PLUG 9/27/2002 0.000 SLOTS, 6,078 -6,091 Perforations & Slots SLOTS, Shot 6,118 -6,124 -- s 1 SLOTS, Top (TVD) Btm (TVD) Dens 6,148 - 6,158 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh••• Type Comment SLOTS, 6,169-6,182 182 - 3,000 3,540 2,886.6 3,339.2 9/9/1997 4.0 IPERF CASING GUNS `- `= SCREEN, 5,649 3,850 3,869 3,586.6 3,602.2 2/5/1998 32.0 SLOTS SLOTS, 6,283-6,290 ''''S.. SLOTS, LOTS, „ 3,886 3,893 3,615.8 3,621.4 2/5/1998 32.0 SLOTS _ 6,375 -6,390 •_ SLOTS, 6,610 -6,622 1 i Mandrel Details SLOTS, = Top Depth Top Port 6,762 II (TVD) Inc, OD Valve Latch Size TRO Run SUMP Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... PACKER, 5,787 1 1,558.6 1,552.1 12.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/18/2003 2 2,675.4 2,598.0 26.02 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.04/24/2012 NIPPLE, 6,836 lily 3 3,601.6 3,389.0 38.22 CAMCO MMG 1/2 GAS LIFT DMY RK 0.000 0.0 4/24/2012 WLEG, 6,867 1 SLOTS, ! IL 6,097 -9,107 - � APERF 9,970 -9,972 PLUG, 10,010 PLUG, 10,073 PRODUCTION, 54- 10,376 CEMENT tt PLUG, 9,610 LINER, 3,588 - 16,720 T 1 O (NCI B -01A), 16,720 • SAK • NCI B -01A ConocoPhillips 03 Alaska, Inc. ConocdPteliips KB-Grd (ft) Rig Release Date "' 10/21/1997 Well Conrig: - NCI B -01A, 4/26/2012 3:03:20 PM - -. Schematic - Actual Annotation Last Mod ... End Date Rev Reason: Add Zones, Perfs, Disp String & Notes ninam 8/18/2011 HANGER, 54 Perforations & Slots Shot Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) (MKS) (ftKB) Zone Date (eh... Type Comment 4,185 4,268 3,859.3 3,927.3 C.I. 1, NCI B -01 2/5/1998 32.0 SLOTS IF"- 4,275 4,365 3,933.1 4,007.2 C.I. 2, NCI B -01 2/5/1998 32.0 SLOTS CONDUCTOR, 54-407 4,429 4,480 4,058.8 4,100.9 C.I. 4, NCI B -01 2/5/1998 32.0 SLOTS SAFETY VLV, 4,751 4,761 4,318.8 4,326.9 C.I. 8, NCI B -01 2/5/1998 32.0 SLOTS 410 IS 4,792 4,803 4,351.8 4,360.7 C.I. 8, NCI B -01 2/5/1998 32.0 SLOTS OM GAS LIFT, 4,922 4,955 4,456.9 4,483.6 C.I. 11, NCI B -01 2/5/1998 32.0 SLOTS 1,559 IL DISPOSAL, 54 la 5,718 5,742 5,098.4 5,118.5 BELG -F, NCI 2/5/1998 32.0 SLOTS SURFACE, 6-01 54 -2,579 5,885 5,892 5,233.5 5,239.2 BELG -G, NCI 2/5/1998 32.0 SLOTS GAS LIFT, B-01 2,675 5,929 5,939 5,269.6 5,277.8 BELG -H, NCI 2/5/1998 32.0 SLOTS IPERF, B -01 3,000 -3,540 5,948 5,969 5,285.1 5,302.2 BELG -H, NCI 2/5/1998 32.0 SLOTS B-01 GAS LIFT, 3,602 IW Mk 5,995 6,032 5,323.2 5,353.1 BELG -H, NCI 2/5/1998 32.0 SLOTS B -01 SEAL ASSY, 6,078 6,091 5,389.9 5,400.3 BELG -I, NCI 2/5/1998 32.0 SLOTS 3,667 B -01 PBR, 3,671 6,097 9,107 5,405.1 7,817.4 2/5/1998 32.0 SLOTS MI1 6,118 6,124 5,421.8 5,426.6 BELG -I, NCI 2/5/1998 32.0 SLOTS M B -01 NIPPLE, 3,700 6,148 6,158 5,445.8 5,453.8 BELG -I, NCI 2/5/1998 32.0 SLOTS is Mk B-01 NTERMEDIATE, _ 6,169 6,182 5,462.6 5,472.9 BELG -I, NCI 2/5/1998 32.0 SLOTS 54 -3,760 B -01 SEAL ASSY, -( 3,762 6,283 6,290 5,553.3 5,558.8 BELG -J, NCI 2/5/1998 32.0 SLOTS PACKER, 3,764 _ B-01 KOIV, 3,797 6,375 6,390 5,626.6 5,638.6 BELG -L, NCI 2/5/1998 32.0 SLOTS SLOTS, B -01 3,8504,869 SLOTS, 6 6,622 5,815.4 5,825.1 BELG -M, NCI 2/5/1998 32.0 SLOTS 3,886 -3,893 B -01 6,762 6,767 5,939.0 5,943.2 BELG -O, NCI 2/5/1998 32.0 SLOTS SCREE SLOTS, � v B-01 4,185-4,268 I' SLOTS, . I 9,970 9,972 8,513.6 8,515.2 9/25/2002 4.0 APERF 2' PERF GUN FOR CEMENT SQZ 4,275 -4,365 4" PACKER, 4,368 Notes: General & Safety 1. .., ,:. ,,,, .. SLOTS, ��� End Date Annotation 4,429 -4,480 ��� 7/30 /1997 NOTE: Two 2 -3/8 tubing strings were run w/the 13 -3/8 surface casing. The surface casing was set at SCREEN, 4,371 2/5/1998 NOTE: SIDETRACK 'A' SCREEN, 4,618 --xi V 1 2/7/2011 NOTE: View Scheamtic w/ Alaska Schematic9.0 SLOTS, 4,751 -4,761 • 1 4 8/17/2011 NOTE: 2 3/8 strings perfd w/ 3 WL runs 3530 -3540, 3520 -3530, & 3500 -3520 w/ 4.5 "csg gun @ 4 SPF SLOTS, 4,792 -4,803 I i ' 8/17/2011 NOTE: Establish inj rate @ 8 bpm @ 1000 psi down 13 -3/8" ir 8/17/2011 NOTE: 1.5 bpm down 2 -3/8" @ 1400 psi. down the 13 -3/8" casing from 3500 -3540' SLOTS, 4,922 -4,955 SUMP PACKER, 4,969 • j I NIPPLE, 5,579 i I PACKER, 5,613 KOIV, 5,647 1;sI i SLOTS, I 5,718 -5,742 SLOTS, • 5,885.5,892 SLOTS, 5,929 -5,939 SLOTS, 5,948 -5,969 SLOTS, • 5,995 -6,032 SLOTS, 6,078 -6,091 SLOTS, 6,118 -6,124 SLOTS, 6,148 -6,158 --- - SLOTS, 6,169 -6,182 SCREEN, 5,649 SLOTS, 6,283 -6,290 SLOTS, 6,375-6,390 - SLOTS, - II 6,610 -6,622 SLOTS, 6,762 -6,767 SUMP PACKER, 6,787 111 i NIPPL 6,836 iiii WLEG, 6,867 - SLOTS, 6,097 -9,107 APERF, 9,970 -9,972 PLUG, 10,010 PLUG, 10,073 PRODUCTION, 54- 10,376 CEMENT III PLUG, 9,610 LINER, 3,588-16,720 TD (NCI B -01A), 16,720 • • • ✓ 8/9/2012 ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Annual Class II Disposal Well Surveillance Report NCI B -01A The following surveillance information is provided as required in DIO 33 Rule 6. NCI B -01A (198 -002) was permitted under DIO 33 November 5, 2008 as a Class II disposal well; no solids are injected. The well head pressure in the injection string has remained at zero and there has been no disposal of fluids; 301 bbls were pumped into the well during the temperature log survey on 4/23/12. The daily inner annulus casing pressure ranged from 235 psi to 625 psi with an average of 427 psi. The outer annulus casing pressure ranged from 255 psi to 650 psi. During the last 12 months no Class II fluid has been injected into this well; 301 bbls of water were pumped into the well for well integrity diagnostics during the temperature log survey on 4/23/12. There is no injection rate data on Class II fluids because there has been no injection. Up to 1 bpm was pumped during the temperature survey. There has been insufficient injection into the well to determine fracture geometry, but the temperature survey indicates injection is within the top and bottom confining layers. No anomalous injection results were noted on this well during the year. There has been insufficient injection into the well to determine a zone of influence, but the temperature survey indicates injection is within the top and bottom confining layers. See the attached Surveillance Plot showing injection tubing pressure, injected volumes and inner annulus pressures. Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Thursday, June 30, 2011 6:15 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Dethlefs, Jerry C; NSK Problem Well Supv; NSK Well Integrity Proj Subject: NCI B -01A Annual Surveillance Report (198 -002) DIO 33 Rule 6 Attachments: NCI B- 01AD.pdf Tom, The following surveillance information is provided as required in DIO 33 Rule 6. NCI B- 01A(198 -002) was permitted under DIO 33 November 5, 2008 as a Class II disposal well. It has remained primarily unused, however has had an approximate total of 3000 bbls of Class II fluid injected sporadically over the last 15 months. The well was not used more than two consecutive days during any of the injection periods. See the attached Surveillance Plot showing injection tubing pressure, injected volumes and inner annulus pressures. During each injection periods the injection pressure always less than 2000 psi, injection rates varied between .25 BPM and 1.5 BPM, and no anomalous injection results were noted. When not under injection the well head pressure was zero psi. The IA pressure averages —400 psi with a high of 670 psi and a low of zero psi. Due to the very low injected volumes a zone of influence has not yet been delineated or calculated for this well. This will be completed as soon as there is sufficient injection volume to detect on a temperature trend. Please let me know if you require any additional information. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 7/1/2011 String Name B -01AD Start Date 7/1/2010 Days 365 End Date 7/1/2011 Cook Inlet Production & Pressure Data ^ ^ OA — WHP — WH7 2500 -_- ._- - - - - -- -- - -_ - - -- - -- -- - -) 200 -- 180 2000 - - 160 • -- 140 wo se • 1500 120 LL c - 100 CD 1000 - - 80 -- 60 500 40 -- 20 0 r- 0 Jul -10 Aug -10 Sep -10 Oct -10 Nov -10 Dec -10 Jan -11 Feb-11 Mar -11 Apr -11 May -11 Jun -11 Gas Vol — Water Vol 700 — In) Vol 600 • - 1 a 500 0.8 - 400 • • • - 300 • - 0.8 E 200 -0.4 • too . — 0.2 0 • • 1 ►� -o Jul -10 Aug -10 Sep -10 Oct -10 Nov -10 Dec -10 Jan -11 Feb -11 Mar -11 Apr -11 May -11 Jun -11 Date ~~ u ~ ~ s ~onocoPhillips August 6, 2009 u John C. Braden, PE Cook InletAsset Telephone:(907) 263-4536 Facsimile: (907) 263-3771 john.c.braden@conocophillips.com 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510-360 ~c ~,~ ~~.~ ~ ,' ~~ ~.._ Mr. JimRegg r'~,U,;; ~~ 'f f~~'1`' Alaska Oil and Gas Conservation Commission >Fi 333 W 7~' Ave, Ste 100 '~`%~z'K~ ~ ~ ~* ' ` . . ,"." Anchorage, AK 99501 Re: DIO 33, Rule 6 North Cook Inlet Unit B-OlA Baseline Temperature Log (PTD 198-002) Dear Mr. Regg, Disposal Injection Order 33, Rule 6 specifies that the operator shall run a baseline differential temperature log in the 5-1/2" tubing of NCIU B-OlA (PTD 198-002) prior to initial injection. The baseline temperature log was run in conjunction with the static survey on 5/30/09. The memory log was run at approximately 60 feet per minute with a sample rate of once per second. Attached are plots of the temperature survey from surface to 4,600 ft MD and a temperature and differential temperature survey from 3,000 ft to 4,000 ft MD that covers the disposal zone (3,500 to 3,540 ft MD). The attached log shows no anomalies adjacent to the disposal perforations. Please contact me if you have questions or comments. Sincerely, ~. ~~~ / John C. Braden Cook Inlet Engineering cc: Sharon Allsup-Drake, e-mail Marta Czarnezki, e-mail ~ B-01A Baseline Temperature Log 5/30/09 Temperature, deg F 50.00 55.00 60.00 65.00 70.00 75.00 80.00 85.00 0 100 200 300 400 500 600 ~oo soo 900 1,000 1,100 1,200 1,300 1,400 1,500 1,600 1,700 1,800 1,900 2,000 2,100 2,200 2,300 p 2,400 ~ = 2,500 a m ~ 2,600 2,700 2,800 2,900 3, 000 3,100 3,200 3,300 3,400 3, 500 3,600 3, 700 3, 800 3,9u0 4, 000 4,100 4,200 4, 300 4,400 4, 500 4,600 4, 700 4, 800 4, 900 ~ nnn Temp - RIH ----30" ----20" ~~Disposal Perfs" - - - - - 13-3/8" - - - 9-5/8" 5 1/2" Temperature measurements frequency is approximately one reading per foot. Detail from 3,000 ft MD to 4000 ft MD is shown on the next page with a differential temperature survey. ~'- ~JiS~~F~tc~ ~~~ 3~n~C,C~~Jk ~~h Z~ ~r ~3 ~~ k Zo cas~\.~ a.~~,t~~ ~L- qc~S QlZ~G~-~lC~.a~/ ~z.~Le ~ ~~d.~tC~ ~j J ~ ~~ ~ ~ .5 . ~'' -fiu~~~;~ J ~.J • • • • r Temperature, deg F 50 55 60 65 70 75 80 8 3000 ~ ~ 3050 , ~ ~ ~ ~ 3100 _ , ~ ~ ~ 3150 ~ ~ ~ ~ ~ ~ 3200 ~ ~ ~ 3250 ~ ~ ~ Temp - RIH ~ -•--30" ~ ---'20" 3300 ~~Disposal Perfs" ~ ' ' ' 133/S" ~ - ~9-5/8" ~ 5 1/2" ' 3350 ' ~ ~ Temperature measurements frequency is ~ approzimately one reading'peffoot. ' ~ 3400 ~ ~ ~ ~ ~ ~ 3450 -- ~ ~ ~ ~ ~ ~ ~ Y 3500 ~ a m ~ ~ , ~ ~ 3550 ' ~ ._.... __. .. , ~ ~ 3600 ~ ~ ~ 3650 ~ ~ ~ _ ~ __ __ ~ _ ~ 3700 ~ ~ ~ ~ 3750 ~ 3800 3850 3900 3950 annn B-01A Baseline Temperature Log 5/30/09 Differential Temperature, deg F/100 ft 5 -30 -25 -20 -15 -10 -5 0 5 3000 I I i i -Differential temp 3050 3100 Temperature measurements frequency is approximately one reading per foot. Differential temp is calculated over 5 foot intervals. 3150 ----- --- - 3200 3250 _ .. .. _.. .. . . .. . . 3300 3350 3400 3450 3500 Disposal - Zone - - 3550 - 3600 3650 3700 3750 --- 3800 . ....... .... ..... _ .. _ . . _ _ . . . ..... . 3850 - 3900 -- I 3950 I nnnn . ~ • • NCIU B-O 1 a(PTD 198-002) Schematic Page 1 of 1 ~ • Regg, James B (DOA) From: Braden, John C [John.C.Braden@conocophillips.com] Sent: Tuesday, August 25, 2009 2:57 PM ~~~~~~~~ ~ To: Regg, James B (DOA) ~ ~ ~ ~ Subject: NCIU B-01a (PTD 198-002) Schematic Attachments: B-01A schematic.xls Jim, Thank you for the phone call regarding B-01a. Attached is a schematic, which should help clarify the temperature anomaly seen on the recent log around 3800 ft MD. The top set of producing perforations are 3850' MD. ~ ~ John C. Braden q~~5 p~~,~,uc~ ~z,n~ U 1 ~ Cook Inlet Development ConocoPhillips Alaska, Inc. (907} 263-4536 phone (907) 265-1441 fax john.c.braden@conocophillips.com «B-01A schematic.xls» ~Ci-c~ 1~--C~i ~ ~~ a G~.(,t-~,~_ ~vp~~~ _ ~ UJ DSFZ ~ •~i3,Sc~,~'_ ~S4-t? ~ M.~ ' J .1 ~ C~ -3~s5~` _ 4365' l~~ 8/26/2009 ConoCOPhllllps NCIU WELL B-01A Completion Diagram API#508832009301 Gas Producer S ud Date 7/3111997 RKB-Drill Deck: 24.5' Single Comp. W/ Disposal Shing Sidetrack Dat 21511998 RKB-THF: 54.08 30 SSSV Annulus Fluid: INHIBITED WATER WITH GLYCOL FOR FREEZE PROTECTION RKB-SL : 116.00 ~~~~~ '.~ ~' TOC: 7666' WATER DEPTH: 120' RKB-ML : 236 .'~IOD ~~. :~:~Ta ~ ~!8ottoro :~:VYT . :Greda ~ C~on. ~:~ ~~BaPsf :~:~Coll ~i~:Tensn:~:~ CASING & TUB/NG 3a" a0T 20" 2579' 133tt K-55 3060 1500 2125 13 3l8" 3760' 724 N-80 5760 2670 1661 9 518" 10376' S3.5# P-110 BU77 10900 7930 1710 5" DP 10074' 16650' 19.5# 5-135 17110 15110 712 s t!7" 376~!' L-80 BUTT ov 2s INo 'I'To I'Cen ih I'DesiriPtidi .: ~D 44 . . PRODUCTION TUBING STRING & JEWELRV ~ - ~rie NANGeR -~~ mod 30 410' Camco 5•112" SSSV TRM-4E w/4.562" X 5.500 20" (a? 2579' ~ 29 1559' dumm Camc _ rt ?' ~ ~: ,LM RK Latch 5.500 ~i~ OV ~ ~~~ 28 2675' S/i~' .~Iflc r,,mc ; 1?.~'~- ~ ~•'~'.".; GLM S116" Orifice RK l.atc h 5.500 28 27 3602' dumm Camco 5-112"x1-1~2" MMG GLM RK Latch 5.500 LC. n~= p =1 2" tb . L-ft0. 15.SY P.2. BTC mod ~ <:: ~ Sterli~g Disp. Sands .. ~~.,.,•nls. '.0" OD x 4_fl75" ID i~' "~ 7S)00 :::. : :~: Two 2 318" Inlection SVings ~q ';~Cn~ ~t....° °.=~' .ii~;~r- 5.500 ~;i ~i in 13 318" x 20" Annulus 7'. ,-!i _ i ',-'. :: ~'i ; i-'.'~ 1. ."" 02. BTC mod :~.5~~ cemented in place 22 3764' Baker 5-1/2" x 9•519" SC-iR kr ass 6.000 9.625 /1",i 21 3797' S" x 7" KOIV 5.000 7.000 3~'~' 35~{V 1~~ 2p 5-1/2" 15 5# SLHT 61ank & streens' S 500 DV 19 4368' Baker SC-iL kr ass p7 18 5-VY' 15.5# SLHT blank & screens" 17 4969' Baker SC-1R Sum kr #2 ass tf, 5-1:2" 15 ~~'i L-~'~~ SLHT bl?nk tb t~i 5~„~7' Xover. 5-1-1" SLH7 x a-117_" IBT 14 one t of -7-1fd" 16T `~~~~~1~ 1? 5g7f~' 4-1/2" X nlp le. Z.' 1.;~ prot~,l~ 3.813 45r1U ~~ 1~l of 4-i!2" IBT v.~~C-~~, -t ; cap latch 4.,~~ 11 5613' Baker 4" x 9•5l8" SC-2 kr ass , 4.75" ID 4.75" 10 5647' S" x 3-112" KOIV 3.500 9 4" SLHT screen and blank f,7RF Baker 5-22 ~n,an Ut~h 7 6787' Baker SC-1R sum acker iCook Inlet Sands s eso5 ~-~%z•. ~-vz .o~e~ 6R3C,' 3-1/2" tb _ 3-VZ' X nl le. 2.813" profile 2.813 ~4.50n 13 318" @ 3760 4 6fl3C~• 3-1/Z" ib . 3-V2" X nipple. 2.813" profile 2-P13 3.500 3 f,867' ?-112"'NLEG tbq ta~~ 3~~`'~~ 22 ~i Baker SC-1R packer @ 3764' ~ 5 iong . ~ i.'" F~- ~ ~ears 21 ~~ ~ 1~ ,~_;1 1 ~: : GravelPacked We//Histo r~! :;:~ 3850-3869 February 5, 1998 - Sidetrack ~~ i~ I 20 ~~~~ i:: ~ 3886-3893 Nov. 26, 2001 - Set 3.813" PXN Plug in XN Nipple. ' '~' I I: ~' ~'~ 4185-4268 ::'' 3.125 Fishneck. XN Nipple is 3725" NoGo w13.813" .. 4275-4365 packing bore. ~:~I I;:; :;:;:; ~~~ September 25, 2002 - PERF from 9970' 9972' RKB. 4 spf w/2' PERF gun in prep for P&A 19 ~:~: Baker SC-1L packer assy @ 4368' September 27, 2002 - Cement tubing & casing, cement in ::: ~ ~ ; Gravel Packed annulus @ 9937' (est.): PXN Plug in Nipple @ 10.073' ; 18 4429-4480 Junk & fill on top af PXN plug top @ 10,010' `:~I ~i~l ~.!~ q7gi-q7g7 September29,2002-TagTOC@9610' :~: ~ I I 4~9z-4803 December 18, 2003 Unable to pull dummy @ 3602', set orif @ 2675' ~: ~ : 4922-4955 December 19, 2003 Tag rop of CaC03 w/wt bar @ 5478'=169' above KOIV May 8. 2005 RIH to 8350' RKB-NO Tag, dunng SBHP Survey 17 ~~:': Baker SC-1 R Sump packer @ 4969' 11 :~:~ Baker SC-2 packer @ 5613' 10 4 ~ ~ ~ ~ Gravel Packed ~ ~~~~ ~~.: ~:~:~:~ :~~: 5778-5742 ; :: ~ 9 ~ ; 5885-5892 5929-5939 :~:~I I;:; ~ :;::::~:;; 5948-5969 l I::i i~i~ ~i~~~'~ ~~~ 5995-6032 ~ ~ 6078-6091 i i l I;i: ::~::~~: ?~: 6097-6107 :~:~I I:~: :::::~ ~~~~ 6118-6724 ~ ~~~~ I l: ~~~~~~ ~~~~ 6148-6758 :: , ... 6169-6782 :~:~I I:~: i•: ~ ~:~:~:~ ~:~: 6283-6290 :: ~ . ~~ ~ , : ~ 6375-6390 ~ 6610-6622 `~~~~ ~~~ ' ~~~'~~~ " 6762-6767 7 ~i: Baker SC-1R Sump packer @ 6787' ~ ___ ~ :~:~ 4 1l2" TBG cut @ 8052' MD (11/22/03) :~~i TOC in TBG @ 9610' MD (9I29I02) :~:~ Packer @ 10074' MD 9 5/8" @ 10376' PXN Plu PXN Plug in Nipple @ 10376' MD 5" DP = N. Forlands Perls 16080-76 7 18' TOC in DP (tD 16590' MD Updated : 5113105 By_Dan Bearden ~,- , ~ ~ ~ ~ ~ . _. iir n~ ,f . . . . . . ... . .. JDB ~ ~ ~ • ~5 FW: B-Ola Injectivity Test Job Summary .42egg, James B (DOA} From: Braden, John C [John.C.Braden@conocophillips.com] Sent: Monday, October 06, 2008 11:23 AM ~ t~lbl~.~ To: Regg, James B (DOA) `~~~ ` Subject: FW: B-01 a Injectivity Test Job Summary Attachments: B-1 Injection test 7-25-08 with plots 14aug08.zip Page 1 of 2 • Jim- Thankyou for the call regarding NCItJ B-01 a. Sharon was waiting on a job summary from me #o submit the 10- 404. She will complete it this afternoan. I apologize that it is late. The job summary is below. The previously submitted step rate test included the period where BJ pumps diverted fluid and were clearing lines. I revised the plot to include volumes down the well. I also included a table of pump time and rate (yellow boX) In the "WH Press" tab. Sincerely, John Braden «B-1 Injection test 7-25-08 with plots 14aug08.zip» From: Braden, John C Sent: Monday, October 06, 2008 10:53 AM To: Allsup-Drake, Sharon K Subject: B-Ola Injectivity Test Job Summary Sharon- Below is a job summary for B-01A for the 10-404. An injectivity test was performed on B-01 a 2-3/8" string on 7/26/08: 12:09 Rig up BJ pumps to B-01A 2-3/8" injection string 14:02 Begin pumping fresh water at 0.5 bpm, final WHP 1722 psia 14:31 Increase rate to 1 bpm, final WHP 1828 psia 14:36 Increase rate to 1.5 bpm, final WHP 1951 psia 14:39 Increase rate to 2.0 bpm, final WHP 2116 psia 14:43 Divert to tank 14:44 SD pumps 14:50 Begin recording shut-in pressures 14:58 Rig down BJ 20:41 Finish recording shut-in pressures (see table below): 10/6/2008 FW: B-Ola Infectivity Test Job Summary ~ Page 2 oft Time Time min 2-318" inj t #2-2-318" IA OA Elapsed Time 2-38" Injection Point 2-318"Alt Strin Inner Annulus 2:5o sl 1440 50 340 1550 0.1074 1440 50 340 2:51 0:01 1400 50 340 1440 0.1081 1400 5a 340 2:56 0:06 1300 50 340 1340 0.1116 13~ 50 340 3:06 0:16 1250 50 340 1330 0.1185 1250 50 340 3:26 0:36 1230 50 340 1290 0.1324 1230 50 340 3:56 1:06 1230 50 3A0 1240 0.1533 1237 50 340 4:41 1:51 1230 50 3A0 1200 0.1845 1230 50 340 5:41 2:51 1140 50 3A0 1170 0.2262 1140 50 340 6:41 3:51 1140 50 3A0 1160 0.2678 1140 50 340 8:41 5:51 1120 50 340 1150 0.3512 1120 50 340 10/6/2008 Tyonek B-1 a Step Rate test 7/26/08 Pressure test lines at = 2500psig Acutal test prey Do not exceed 2500psig while pumping into the well Pump Rate~lume to purressure (psig) .5 bpm 15 bbls 1.0 bpm 5 bbls Date/time 1.5 bpm 5 bbls 7/26/2008 12:09 2.0 bpm 10 bbls 7/26/2008 14:02 7/26!2008 14:31 Started pumping 2:02 m ~/2612oo81a:3s 7/26!2008 14:39 Stopped pumping/SI 2:45 m 7/26/200814:43 7/26/200814:44 7/26!2008 14:58 Shut in well and rer•.~rd the f~llowin a pressures 2500 rpsed time bpm Final Pres row 0 0 3 Rig up 112.325 0.5 1722 6746 begin pumping 141.475 1 1828 8495 146.967 1.5 1951 8826 150.217 2 2116 9081 153.617 0 9225 Divert to tank 154.717 0 9290 SD pumps 169.15 0 10157 RD Time Time,min 2-3/8" inj t #2 - 2-3/8" IA OA Elapsed Time 2-3/8" Injection Point 2-3/8" Alt. Strin Inner Annulus Outer Annulus 2:50 SI 1440 50 340 1550 0.1074 1440 50 340 1550 2:51 0:01 1400 50 340 1440 0.1081 1400 50 340 1440 2:56 0:06 1300 50 340 1340 0.1116 1300 50 340 1340 3:06 0:16 1250 50 340 1330 0.1185 1250 50 340 1330 3:26 0:36 1230 50 340 1290 0.1324 1230 50 340 1290 3:56 1:06 1230 50 340 1240 0.1533 1230 50 340 1240 4:41 1:51 1230 50 340 1200 0.1845 1230 50 340 1200 5:41 2:51 1140 50 340 1170 0.2262 1140 50 340 1170 6:41 3:51 1140 50 340 1160 0.2678 1140 50 340 1160 8:41 5:51 1120 50 340 1150 0.3512 1120 50 340 1150 • B-01a Infectivity Test 7/25/08 4500 4000 - ---- ------- --- -- --~~ 2-3/8" Injection Point 1 ', 2-3/8" Alt. String 3500 ---.... - ------- --------~ Inner Annulus I~ BJ pump ', 3000 - Outer Annulus __ _ _ _. R .a 2500- ai f------' _ _ _ _ _ _. d 2000 ____ 2.0 b b bpm _ _ a 1.0 bpm 0.5 bpm 1500 - _. _ ___ ©[(~er ~nn~lu~ 1000 I -__ _ _ _ _ _ _ _ _ __ f -..._.... __ _.. A~.S Puxp I~ 7,'t~ler 1~-nnu,lus 500 -._ _ _ __ __ _ _ - - - __ L~_ __ ___ _. _ _- 0 _ __ __ __ 0:00:00 1:12:00 2:24:00 3:36:00 4:48:00 6:00:00 7:12:00 8:24:00 9:36:00 Elapsed time, HH:MM:ss B-01a Infectivity Test 7/25/08 2500 2000 ~a a 1500 d N N d a a E 1000 a 500 0 r • Pump Rate, bpm 0 2 4 6 8 10 12 Page 1 of 3 Regg, James B (DOA) ,~~ g^~ ~~ From: Braden, John C [John.C.Braden@conocophillips.com] T-- ~~ `~~ Sent: Wednesday, September 17, 2008 12:10 PM To: Regg, James B (DOA) Cc: Aschoff, Mary Mae Subject: RE: CANCELLED -Public Hearing for NCIU B-01A Attachments: Att 7 Full Report -NCIU B-1 Multiwell.pdf Jim- Thank you for your questions. I have attempted to answer them as briefly as possible. • Attachment 7 should have been the last two pages. Attached is a PDF. • Historical injection showed 200,000 total injected. For the modeling, we injected 50,000 bbls of fresh water and then 150,000 bbls of slurry. It is a bit mare than the 134,000 bbfs of slurry reported. The free model results are conservative relative to actual volumes injected. • The frac models run have continuous injection. This is a conservative way of modeling injection. If something will grow out of zone, this would cause it. Actual injection in small batches would initiate many smaller fractures. I wanted to be sure we would not grow out of zone in any situation. • Max 2500 psi was based on DIO 17. Modeled surface treating pressure is closer to 1030 psis as seen in the attached PDF. • Max volume is 3000 BPD based on DIO 17. This was used for the fracture modeling. It would be easier from an operational standpoint if bath A-12 and B-01a had the same limits. • I think the letter is confusing regarding the 7.4 Ibs of solids added. It is 7.4 Ibm of solids added to each gallon of slurry (ppa} and not ppg. The text is poorly worded. • Regarding the request for diesel, it was part of the proposed method to monitor the well. Loading the 2- 3/8" tubing and inner annulus with diesel ensures positive surface pressure. Once the annulus and tubing strings are loaded, the actual volume would be 20 bbfs on a periodic basis. If the Commission feels that annual temperature logs and monitoring changes in infectivity (injection rate and pressure} are sufficient, then diesel is not required. If you need to discuss this in more detail, please contact me. I appreciate your attention to the details and desire to clear up any confusion quickly. Sincerely, John Braden From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 17, 2008 11:23 AM To: Braden, John C Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Subject: RE: CANCELLED -Public Hearing for NCIU B-01A I'm a little confused by the frac model discussion; tried calling you earlier today but no answer and your voice mail would not pick up; left msg with Mary Mae Aschoff. - Info you provided on 9/11108 does not include Attachment 7 (model assumptions and output}; is there something other than the graphic {"B-01A Fracture Results"'} provided in written text? 9/17/2008 Page 2 of 3 - Also on the graphic, it appears the historical cutting injection result was based on 200,000 bbls injected slurry - is that accurate or was it based on actual 135,000 bbls? - It appears that all frac model scenarios are run for single continuous injection; is that also how you operate or is injection done in batches? - What is the average injection pressure {max stated is 2500 psi)? -Avg daily injected volume {max volume injection 3000 bpd)? - Basis for the 7.4 ppg slurry (OBM?} Are you using OBM for drilling? is diesel the make-up fluid for slurry? lam not aware of the Commission ever allowing diesel to cut an injected slurry. This may be an issue. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Braden, John C [mailto:John.C.Braden@conocophillips.com] Sent: Wednesday, September 17, 2008 7:47 AM To: Regg, James B (DOA) Cc: Davies, Stephen F (DOA); Maunder, Thomas E (DOA); Aschoff, Mary Mae Subject: RE: CANCELLED -Public Hearing for NCIU B-OlA Jim- I gat the notice about the hearing. I was reviewing the letters regarding B-01a last night. One request I needed to make during the hearing is that since part of the monitoring plan requires injecting diesel to monitor pressures, it needed to be one of the allowed injected streams. If I can answer any other questions, please let me know, I appreciate the Commission's assistance with our request. Thanks, John Braden From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, September 16, 2008 2:52 PM To: Braden, John C Subject: FW: CANCELLED -Public Hearing for NCIU B-OlA From: Davies, Stephen F (DOA) Sent: Tuesday, September 16, 2008 2:49 PM To: 'jbraden@ppco.com' Subject: CANCELLED -Public Hearing for NCIU B-OlA John, The Public Hearing for NCIU B-01A that is scheduled for tomorrow morning (Sept 17th) has been cancelled. We tried phoning you at 263-4536 to let you know, but that particular phone numberjust rings indefinitely without rolling to voice mail. I tried contacting you through ConocoPhillips' main switchboard, but they just forwarded me to the same phone. Thanks, Steve Davies Sr. Petroleum Geologist 9/17/2008 Page 3 of 3 Alaska Oil and Gas Conservation Commission Telephone: (907) 793-1224 Fax: (907) 276-7542 New Email Address: steve.davies@alaska.gov 9/17/2008 NCIU B-01 a hearing Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Tuesday, August 26, 2008 3:11 PM To: Braden, John C Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Subject: RE: NCIU B-01a hearing Page 1 of 1 As follow-up to this morning's hearing (recessed until Sept 17), here's a list of info we need to complete our review: -discussion/evaluation of injection zone and confining layers; - structure map w/injection zone, arresting zone, confining layer(s) labeled; - clarify volume disposed in B-01A (annular disposal); CPAI says approximately 200,000 bbls during 1997-98, but I can account for only about 135,000 bbls - clarify cement tops as noted in application; - cement bond log for B-01 A, if available; - update fracture model; - report on mechanical condition of wells within 1/4 mile of B-01A penetrating injection zone (cement tops, integrity, annulus pressures; -discussion of A-12 performance to date (mechanical integrity; volume injected to date. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Braden, John C [mailto:John.C.Braden@conocophillips.com] Sent: Monday, August 25, 2008 12:51 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: NCIU B-Ola hearing Jim & Tom- Mary Mae told me you left a message that we are on for tomorrow's hearing regarding B-01 a. I have never been to a hearing. What is the format of the hearing? What information you are expecting? John Braden 8/26/2008 Hearing tomorrow ~ ~ Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Monday, August 25, 2008 4:06 PM To: 'Braden, John C' Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: FW: Hearing tomorrow John -The hearing is rescheduled for the September 17, 2008 at 9:00 am. Sorry-we bounced around a few dates. Jody From: Colombie, Jody J (DOA) Sent: Monday, August 25, 2008 3:55 PM To: Braden, John C Cc: Regg, James B (DOA); Davies, Stephen F (DOA) Subject: RE: Hearing tomorrow John- The Commissioners have granted your request to continue the North Cook Inlet B-01a hearing currently scheduled for tomorrow. The hearing will reconvene on September 16, 2008 at 9:00 am. Jody From: Braden, John C [mailto:John.C.Braden@conocophillips.com] Sent: Monday, August 25, 2008 1:18 PM To: Colombie, Jody J (DOA) Cc: Maunder, Thomas E (DOA); Regg, James B (DOA); Clark, Lindsey L; Aschoff, Mary Mae Subject: Hearing tomorrow Importance: High Jody- Jim Regg left aphone-mail message for Mary Mae Aschoff that the North Cook Inlet B-01a hearing will occur as scheduled. I tried to call you, Tom Maunder and Jim Regg. Our geologist, Rick Levinson, is on vacation until after Labor Day. He should be present to answer any geological questions regarding the B-01a well. I would like to request to delay the hearing until after September 8 to allow Rick Levinson to be present. Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907) 263-4536 phone (907) 265-1441 fax john.c.braden@conocophillips.com 8/25/2008 Page 1 of 2 Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Wednesday, July 16, 2008 2:26 PM To: Colombie, Jody J (DOA) Subject: FW: DIO Request -NCIU B-01A for the NCIU B-01A disposal injection order file; this will become DIO 33 if approved Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Braden, John C [mailto:John.C.Braden@conocophillips.com] Sent: Tuesday, July 15, 2008 5:31 PM To: Regg, James B (DOA) Subject: RE: DIO Request -NCIU B-O1A There are no exploratory wells in the Area of Review, as defined by the 1320' radius around the injection zone of B-01 A. John Braden From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 15, 2008 3:34 PM To: Regg, James B (DOA); Braden, John C Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: DIO Request -NCIU B-OlA Another question. Are there any exploratory or abandoned wellbores in the Area of Review? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Regg, James B (DOA) Sent: Tuesday, July 15, 2008 2:13 PM To: 'john.c.braden@conocophillips.com' Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: DIO Request -NCIU B-01A Tried to call you today about the disposal injection request for NCIU B-01A; must be some phone issues since I was never able to connect to your voice mail. Below is what I wanted to discuss - 1) Your request needs to be processed as a Disposal Injection Order - it appears that is what you are seeking but 7/17/2008 Page 2 of 2 not clear. Please confirm before I prepare public notice of review and hearing. 2) Water depth at platform appears to be 116 ft based on depths reported for A-12 (MD and subsea MD). Please confirm. 3) Location of disposal interrval appears to be Section 6, Township 11 N, Range 9W of Seward Meridian; please confirm. 4) We need the injection interval for B-01A; your application quotes depths for A-12 and shows the lithologic unit correlation (depths are near impossible to read on the correlation). Please provide TVD and MD for approximate injection interval. 5) Application needs a better description of the injection formation and confining layer/layers. 6) Info provided for 20 AAC 25.252(c)(4) references Aquifer Exemption Order 4 as authorizing disposal injection into the Sterling formation; an aquifer exemption does not authorize injection 7) What is the average injection pressure? 8) Fracture model results provided in support of DIO 17 (1998) should be updated with specifics for Well B-01A; you should also account for the 200,000 bbls of slurry injected in 1997-98. 9) Report on mechanical condidtion of wells within the AOR should be more than a statement that the integrity is good; we need evidence of such, including tubing and annuli pressures, cement tops, assessment of the cement jobs performed that isolate the Sterling formation (include bond log data if available), and any other information available that supports the statement. 10) Will B-01A both serve as a disposal injector and gas producer? Items 1 through 4 are needed to finalize the public notice. There may be additional info needs identified as we continue our review. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/17/2008 Page 1 of 2 Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Wednesday, July 16, 2008 2:26 PM To: Colombie, Jody J (DOA) Subject: FW: DIO Request -NCIU B-01A another for the DIO file Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Braden, John C [mailto:John.C.Braden@conocophillips.com] Sent: Tuesday, July 15, 2008 4:01 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Levinson, Rick A; don.andrews@asrcenergy.com; Aschoff, Mary Mae M; Jepsen, J Scott; Clark, Lindsey L Subject: RE: DIO Request -NCIU B-01A Jim- Thankyou for your review of the disposal request. Here are answers to your questions at this time. We will supply more information in the near future. 1. Yes, Tom Maunder and I talked about it. He said it would be a new DIO. 2. The directional shows A-12 KB is 116 ft above sea level. The B-01A directional shows it to be 132 ft above sea level. The water depth is about 100 ft MLLW. 3. Sec. 6 of T 11 N, R 9W is correct. 4. Perforation interval is 3500' to 3540' MD (3307-3339 TVD). The injection interval is approximately 3485 - 3550 MD (3295-3348 TVD). 5. The operator will supply a better description of the injection formation and confining layers. ~ .``~~ 6. You are correct. The aquifer which correlates with the interval below 2900' MD in the NCIU A-12 well in ~ ~~~ ~ Sec 6, T11 N, R9W is exempt under 20ACC25.440. The operator is seeking a Disposal Injection Order for -A~-r~~...~ us^~ the purpose of disposing into the interval listed in item 4. Thank you for clarifying that point. ~~ ~dytG 7. A sundry has been filed to establish current injection pressure and injectivity. Initial injectivity test on 6°'E°' F~ 9113/97 was 0.5 bpm @ 1150 psi, 0.75 bpm @ 1250 psi and 1.5 bpm @ 1400 psi. 8. The operator will repeat the fracture modeling to include the specifics of B-01A and prior injection history. ~- ~,"" 9. A report of the mechanical condition of the wells will be prepared as you suggested below. ~ --. --• ~y; 10. Yes B-01A will serve as a gas producer and disposal injector. ` Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907) 263-4536 phone (907) 265-1441 fax john.c.braden a conocophillips com 7/17/2008 Page 2 of 2 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 15, 2008 2:13 PM To: Braden, John C Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: DIO Request -NCIU B-OlA Tried to call you today about the disposal injection request for NCIU B-01A; must be some phone issues since I was never able to connect to your voice mail. Below is what I wanted to discuss - 1) Your request needs to be processed as a Disposal Injection Order - it appears that is what you are seeking but not clear. Please confirm before I prepare public notice of review and hearing. 2) Water depth at platform appears to be 116 ft based on depths reported for A-12 (MD and subsea MD). Please confirm. 3) Location of disposal interrval appears to be Section 6, Township 11 N, Range 9W of Seward Meridian; please confirm. 4) We need the injection interval for B-01A; your application quotes depths for A-12 and shows the lithologic unit correlation (depths are near impossible to read on the correlation). Please provide TVD and MD for approximate injection interval. 5) Application needs a better description of the injection formation and confining layer/layers. 6) Info provided for 20 AAC 25.252(c)(4) references Aquifer Exemption Order 4 as authorizing disposal injection into the Sterling formation; an aquifer exemption does not authorize injection 7) What is the average injection pressure? 8) Fracture model results provided in support of DIO 17 (1998) should be updated with specifics for Well B-01A; you should also account for the 200,000 bbls of slurry injected in 1997-98. 9) Report on mechanical condidtion of wells within the AOR should be more than a statement that the integrity is good; we need evidence of such, including tubing and annuli pressures, cement tops, assessment of the cement jobs performed that isolate the Sterling formation (include bond log data if available), and any other information available that supports the statement. 10) Will B-01A both serve as a disposal injector and gas producer? Items 1 through 4 are needed to finalize the public notice. There may be additional info needs identified as we continue our review. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/17/2008 Page 1 of 2 Regg, James B (DOA) From: Braden, John C [John.C.Braden@conocophillips.com] Sent: Tuesday, July 15, 2008 4:01 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Levinson, Rick A; don.andrews@asrcenergy.com; Aschoff, Mary Mae M; Jepsen, J Scott; Clark, Lindsey L Subject: RE: DIO Request -NCIU B-01A Jim- Thankyou for your review of the disposal request, Here are answers to your questions at this time. We wiN supply more information in the near future. ~. Yes, Tom Maunder and I talked about it. He said it would be a new DIO. ,/~. The directional shows A-12 KB is 116 ft above sea level. The B-01A directions{ shows it to be 132 ft above sea level. The water depth is about 100 ft MLLW. Sec. 6 of T 11 N, R 9W is correct. Perforation interval is 3500' to 3540' MD (3307-3339 TVD). The injection interval is approximately 3485 - 3550 MD (3295-3348 TVD). 5. The operator will supply a better description of the injection formation and confinin, g layers. i6. You are correct. The aquifer which correlates with the inte larv below 2900' MD in the NCIU A-12 well in ~/ Sec 6, T11 N, R9W is exempt under 20ACC25.440. The operator is seeking a Disposal Injection Order for the purpose of disposing into the interval listed in item 4. Thank you for clarifying that point. 7. A sundry has been filed to establish current injection pressure and infectivity. Initial injec#ivity test on 9113/97 was 0.5 bpm @ 1150 psi, 0.75 bpm @ 1250 psi and 1.5 bpm @ 1400 psi. rj 8. The operator will repeat the fracture modeling to include the specifics of B-01A and prior injection history. 9. A report of the mechanical condition of the wells wil! be prepared as you suggested below. 10. Yes B-01A will serve as a gas producer and disposal injector. Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (907} 263-4536 phone (907} 265-1441 fax iahn c..brad..e..n@conoco~hillps__.eom From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 15, 2008 2:13 PM To: Braden, John C Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: DIO Request -NCIU B-O1A Tried to call you today about the disposal injection request for NCIU B-01 A; must be some phone issues since I was never able to connect to your voice mail. Below is what I wanted to discuss - 1) Your request needs to be processed as a Disposal Injection Order - it appears that is what you are seeking but not clear. Please confirm before I prepare public notice of review and hearing. 2) Water depth at platform appears to be 116 ft based on depths reported for A-12 (MD and subsea MD). Please 7/ 16/2008 Page 2 of 2 confirm. 3) Location of disposal interrval appears to be Section 6, Township 11 N, Range 9W of Seward Meridian; please confirm. 4) We need the injection interval for B-01 A; your application quotes depths for A-12 and shows the lithologic unit correlation (depths are near impossible to read on the correlation). Please provide TVD and MD for approximate injection interval 5) Application needs a better description of the injection formation and confining layer/layers. 6) Info provided for 20 AAC 25.252(c)(4) references Aquifer Exemption Order 4 as authorizing disposal injection into the Sterling formation; an aquifer exemption does not authorize injection 7) What is the average injection pressure? 8) Fracture model results provided in support of DIO 17 (1998) should be updated with specifics for Well B-01 A; you should also account for the 200,000 bbls of slurry injected in 1997-98. 9) Report on mechanical condidtion of wells within the AOR should be more than a statement that the integrity is good; we need evidence of such, including tubing and annuli pressures, cement tops, assessment of the cement jobs performed that isolate the Sterling formation (include bond log data if available), and any other information available that supports the statement. 10) Will B-01A both serve as a disposal injector and gas producer? Items 1 through 4 are needed to finalize the public notice. There may be additional info needs identified as we continue our review. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/16/2008 Page 1 of 2 .M Regg, James B (DOA) __ From: Braden, John C [John.C.Braden@conocophillips.comJ Sent: Tuesday, July 15, 2008 5:31 PM To: Regg, James B (DOA) Subject: RE: DIO Request -NCIU B-01A There are no exploratory wells in the Area of Review, as defined by the 1320' radius around the injection zone of B-01 A. John Braden From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 15, 2008 3:34 PM To: Regg, James B (DOA); Braden, John C Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: DIO Request -NCIU B-O1A Another question. Are there any exploratory or abandoned wellbores in the Area of Review? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Regg, James B (DOA) Sent: Tuesday, July 15, 2008 2:13 PM To: 'john.c.braden@conocophillips.com' Cc: Maunder, Thomas E (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: DIO Request -NCIU B-O1A Tried to call you today about the disposal injection request for NCIU B-01 A; must be some phone issues since 1 was never able to connect to your voice mail. Below is what I wanted to discuss - 1 }Your request needs to be processed as a Disposal Injection Order - it appears that is what you are seeking but not clear. Please confirm before I prepare public notice of review and hearing. 2) Water depth at platform appears to be 116 ft based on depths reported for A-12 (MD and subsea MD}. Please confirm. 3) Location of disposal interrval appears to be Section 6, Township 11 N, Range 9W of Seward Meridian; please confirm. 4) We need the injection interval for B-01A; your application quotes depths for A-12 and shows the lithologic unit correlation (depths are near impossible to read on the correlation). Please provide TVD and MD for approximate injection interval. 5) Application needs a better description of the injection formation and confining layer/layers. 6) Info provided for 20 AAC 25.252(c)(4) references Aquifer Exemption Order 4 as authorizing disposal injection into the Sterling formation; an aquifer exemption does not authorize injection 7) What is the average injection pressure? 8) Fracture model results provided in support of DIO 17 (1998) should be updated with specifics for Well B-01A; you should also account for the 200,000 bbls of slurry injected in 1997-98. 9) Report on mechanical condidtion of wells within the AOR should be more than a statement that the integrity is good; we need evidence of such, including tubing and annuli pressures, cement tops, assessment of the cement 7/16/2008 Page 2 of 2 jobs performed that isolate the Sterling formation (include bond log data if available), and any other information available that supports the statement. 10) Will B-01A both serve as a disposal injector and gas producer? Items 1 through 4 are needed to finalize the public notice. There may be additional info needs identified as we continue our review. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/16/2008 ~ 4 • • ConocoPhillips September 8, 2008 ~i ~~p ~ ~ 2008 A4a~„u C;~i! ~ Gas Cans. C~I~,e i~,sicn Any! ~~.,~~ Tom Maunder and Jim Regg Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 RE: B-Ola Disposal Inejction Dear Tom and Jim John C. Braden, PE Cook Inlet Asset Telephone:(907) 263-4536 Facsimile: (907) 265-1441 Email: jbraden@ppco.com 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510-360 On July 11, 2008 ConocoPhillips Alaska Inc. submitted an application for B-Ola annular tubing strings to be used for Class II disposal into the zone that is currently perforated. The Commission indicated three areas that needed further definition: • discussion/evaluation of injection zone and confining layers; • structure map w/injection zone, arresting zone, confining layer(s) labeled; • clarify volume disposed in B-OlA • clarify cement tops as noted in application; • cement bond log for B-01 A, if available; • update fracture model; • report on mechanical condition of wells within 1/4 mile of B-OlA penetrating injection zone (cement tops, integrity, annulus pressures; • discussion of A-12 performance to date (mechanical integrity; volume injected to date. On the following pages, ConocoPhillips gives addresses these topics. If you have further questions, please contact me as indicated above. Sincerely, John Braden i i September 8, 2008, page2 B-Ola Disposal Injection List of Attachments Attachments: 1. Geologic Structure Map on Top of C.I.1 Surface 2. Geologic Cross-Section 3. Type-log of Sterling Formation 4. Table of Distances Between wells in Injection Zone 5. Recent Annulus Pressures (2004 to present) 6. Cement Bond Log for B-O1 (13-3/8" casing) 7. Fracture Modeling Input and Results 8. A-12 Injection Rate and Pressures September 8, 2008, page3 B-Ola Disposal Injection B-Ola Disposal Zone Geologic Description The North Cook Inlet Unit (NCIU) gas field is a large shallow gas accumulation located approximately 40 miles west-southwest of Anchorage, in northern Cook Inlet, Alaska. The field is.located offshore, and it produces from the Tyonek platform in about 110 feet of water. ConocoPhillips Alaska, Inc. has a 100% interest and operates the field to supply gas to the LNG plant in Nikiski. Gas production began in March, 1969, and over 1.78 TCF have been produced to date. Currently, the field is at a mature state of development. Much of the reservoir is depleted below 50% of original pressure, and the wells have seen water encroachment in a number of the sands. Disposal of produced water is a significant part of current production operations. The volume of produced water is likely to grow in the future as more sands are depleted of gas. The North Cook Inlet gas field produces from two Tertiary-aged formations: the high net-to-gross, Pliocene-aged Sterling Fm (Cook Inlet sands or C.I. sands), and the underlying low net-to-gross Miocene- aged Beluga Fm. The gross reservoir thickness is approximately 3400', and ranges in depth from 3400' to 6925' sstvd. Attachment 1 shows a geological structure map on top C.I. 1 surface, which is in the Sterling Fm. about 230' below the top of gas production. The map is based on 3D seismic interpretation and well ties. The North Cook Inlet structure is a broad compressional north-northeast-trending fault propagation fold with a steeply dipping reverse fault on the east side. This fault splays into a number of normal faults at the northeast edge of the field. The field is approximately 5.5 miles long by 3.5 miles wide. The map shows that wells are clustered near the top of the geological structure, and they extend in a "spider" pattern down through the gross reservoir interval. Small red crosses on the "spider legs" indicate the top of Sterling Fm. production, top of Beluga Fm. production, and base of Beluga Fm. production. The original C.I.1 gas/water contact based on seismic amplitude, and gas-down-to points and water-up-to points is the dashed red line. Over the 39 year history of gas production, water has advanced up structure toward the wells. Some of the C.I. sands, including the C.I. Stray, C.I. A, C. I. B, and C.I. 5 through C.L 7, are watered-out, and they are currently shut-in. The proposed shallow injection zone is indicated by a green dot located east of the crest of the structure along the NCI B-01 well path. The nearest identified faults are over 2.25 miles away from the proposed injection zone. The line of cross section in Attachment 2 is shown in blue on the structure map. The Sterling-Beluga Fm. reservoir is entirely non-marine and consists of dozens of stacked fluvial channel belt and crevasse splay sands that are separated by laterally continuous, relatively impermeable flood basin siltstone, mudstone, and coal. Core interpretation suggests the sediments were deposited asmedium-sized meandering river systems. The dominant reservoir sand bodies are relatively small in size and have discontinuous channel belt form or fan-shaped geometries. However, in the Sterling Fm, the channel belt sands tend to amalgamate to form thick, well-connected packages of sand. Reservoir connectivity relates to net-to-gross, channel belt orientation relative to wells, and presence of thin, but widespread mudstone and coal zones that act as barriers to flow. Generally, the Sterling Fm. sands are well connected laterally, but not vertically.. The Beluga Fm. sands have moderate to poor connectivity both laterally and vertically. 'The proposed zone for water injection is a set of amalgamated sands of the shallow Sterling Fm, approximately 183' tvd above the top of gas production in the C.I. Stray interval. This is the same sand interval that is currently being used as a produced water disposal zone in the NCI A-12 well as shown on the cross section in Attachment 2. Sealing lithology in the confming beds are adequate to contain disposed liquids as has been demonstrated from a 10 year history of produced waterdisposal in the NCI A-12 well. Attachment 3 is a type log plot of the Sterling Fm. portion of the NCI B-01 a well. It shows the proposed shallow injection zone along with the other sands and intervening siltstones, mudstones, and coals that make up the confming beds. On this CDR LWD log, Track 1 shows subsea true vertical depth (sstvd). Track 2 shows Gamma Ray (black solid) and Rate of Penetration (black dashed) log curves. Track 3 is measured depth (md). Track 4 shows phase shift and attenuation resistivity log curves (black solid and black dashed respectively). The proposed injection disposal zone is shaded in blue, and the existing 40' thick perforation interval is indicated in red. Log annotation shows the tops of picked stratigraphic intervals that have produced gas, the proposed disposal injection zone, and surrounding confining beds and arresting zones. Because NCI B-01 was originally drilled in the summer of 1997, the resistivity log curves are fairly high, indicating presence of gas. Currently, the uppermost intervals in the gas production zone, September 8, 2008, page4 B-Ola Disposal Injection the C.I. Stray, C.I. A, and C.I. B, have all watered out, and these intervals have been shut-in across the field. The underlying C.I. 1 and C.L 2 intervals are still produce gas, but at greatly depleted pressure. The proposed shallow injection interval is made up of 2 sands separated by a 3' thick coal and mudstone section. Both the upper and lower proposed sands are each ~50' tvd thick, and are amalgamations of several channel belts sands stacked together. In these sands, effective porosity ranges from 27% to 23%, and horizontal air permeability ranges from 30 and to 1100 md. Drill cuttings taken in this interval are described as gray colored, fine-grain sized sandstone with poorly-sorted, angular sand grains. Some samples indicate that stringers of carbonaceous material and silt-mud material are present. confming beds that occur above and below the sands are made up of interlaminated mudstone, claystone, coal, and siltstone, with occasional thin interbedded sandstone. Several thicker sands are interbedded with the confining beds, and these will act as arresting zones to contain the liquids, should injected water break out of the disposal injection sands. These are shown in the type log in Attachment 3. Between the base of the disposal injection zone and the top of gas production are three confming bed intervals separated by two arresting zones. The lower confming zone is 23' tvd thick and is located immediately above the C.I. Stray -top of gas production. Above that, is a 14' tvd thick arresting zone sand. Above the lowest arresting zone sand is a major zone of confming beds that is 93' tvd thick. The 13 3/g" casing shoe occurs within this major confming zone, and this casing point produces a gap in the logs as well as artificially lowers gamma ray and resistivity values at the casing overlap, as seen in Attachment 3. Above this major zone of confining beds, is an arresting zone sand 28' tvd thick followed by a confining bed zone 22' tvd thick that is adjacent to the lower boundary of the disposal injection zone. Above the disposal injection zone is a section 182' tvd thick, comprised of 3 confming bed zones (46', 37', and 30' tvd thick upward respectively) separated by 2 arresting sands (49' and 20' tvd thick upward respectively). These are well illustrated on Attachment 3. Attachment 2 is a stratigraphic cross section, slightly under a mile in length, oriented approximately north- south, across the middle portion of the North Cook Inlet field. The log format for the NCIU B-0la is the same as that in the type log in Attachment 3. The other wells have the following format: Track 1 shows volume of clay (VCL in green-computed from the neutron and density logs), Spontaneous Potential (SP in red), and Gamma Ray (GR in black) curves. Tracks 2 and 3 are measured depth and subsea true vertical thickness respectively. The plot is datumed on C.I. Stray, which is the top. of gas production. Track 4 shows deep, medium, and shallow resistivity curves (ILD in black, ILM in red, and SFL in blue respectively) and well perforation intervals in red. On these, horizontal lines indicate open perforations, and vertical lines indicate shut-in or closed perforations. Track 5 shows a number of porosity logs: Density (RHOB in red) with low density coals shaded in black, Neutron porosity (NPHI in black), compressional sonic (DT in blue), and computed effective porosity (PHIE in green), which is that portion of total porosity containing sufficiently large pores that fluids can move through. Track 6 shows the tops of picked stratigraphic intervals. T'he stratigraphic top picks are mostly associated with coals that are well correlated. The cross section shows that the sands and confming bed intervals are fairly laterally continuous. That said, the arresting zone sand above the proposed disposal injection interval tends to thin, and become less amalgamated and more interbedded with siltstone and mudstone in the NCI B-Ola well, thereby, enhancing the confinement of injected liquids. Because of the high net-to-gross among the Sterling Fm, the gas production sands, as well as the proposed disposal injection sands, tend to be well connected laterally. However, because of the coals and mudstone zones are also very correlative across the field, the Sterling Fm. sands tend to have continuous barriers that act as confining beds. Structure Man and Geological Cross Section of Disposal Zone and Confining Lavers Within the structural confines, the proposed disposal injection sands are laterally continuous, as are the confining bed intervals. This is illustrated in the structure map, geological cross section, and annotated type log that shows the disposal zone, arresting zones and confining layers in Attachments 1, 2, and 3 respectively. September 8, 2008, pages B-Ola Disposal Injection Clarification of Volume Disposed The most recent sundry (10-404) dated 11/10/98 indicates 134,325 bbls injected. I misread this as 194,325 bbls injected. The correct volume is 134,325 bbls injected. B-Ola Offset Wells Cement Records and Report of Mechanical Integrity The original letter to the Commission, received July 11, 2008, indicated in Attachment 3 of that letter that the following wells were within one quarter mile of the proposed disposal interval: A-03, A-04, A-06, A- 07, A-09, A-12 and B-03. The distance calculations were in error. A corrected table is shown as Attachment 4. The following wells are within one quarter mile of the proposed disposal zone: A-04, A-06, A-07, A-12 and B-03. The well integrity evaluation, below, reviews the wells listed in the original letter. The perforated interval for proposed injection in well B-Ola is 3500 to 3540 ft MD (-3175 SSTVD to -3207 SSTVD). All of the cementing records used for this analysis are on file with the Commission as part of the well files. A plot of recent annulus pressures (2004 -present) is shown in Attachment 5. NCIU A-03 NCIU A-03 was spud on 11/2/68. The 7"casing was set 3/5-6/69 and cemented with 515 sacks of Class "G" cement mixed with 135 bbls prehydrated 10%Diacel "D". The cement was pushed to the top of the stage collar at 5114 ft. Squeeze perfs were added at the following intervals: • 4793-4794 ft (27 sx initial, 65 sx resqueeze), • 4178-4179 ft (46 sx initial, 92 sx resqueeze), • 4100-4101 ft (15 sx initial, 82 sx resqueeze) • 3930-3931 ft (46 sx initial, 91 sx resqueeze) • All perfs tested to 2500 psig. Top of cement based on displacement is approximately 1800 to 3700 ft. The CBL dated 3/5/69 indicates a top of cement at least 3425 ft MD. or -2990 SS. The annular pressure for this well (Attachment 2) shows no abnormal behavior. Following the workover in late 2007, the well was put on gas lift, which accounts for the increased inner annulus pressure. NCIU A-04 NCIU A-04 was spud on 3/19/69. The 7" casing was set 4/11-13/69. The casing was cemented in two stages using a DV collar at 5204 ft. The first stage was 517 sx Class G with 10%Diacel "D" and 2% calcium chloride. 'The second stage was cemented with 735 sx of Class G with 2% CaC12 and 88 bbls FW. Average slurry weight was 15.6 ppg. Top of cement based on displacement is approximately surface to 2200 ft The CBL dated 4/12/69 indicates a top of cement at 2590' MD or -2286 SS T'he annular pressure for this well (Attachment 5) shows no abnormal behavior. Following the workover in early 2008, the well was put on gas lift, which accounts for the increased inner annulus pressure. NCIU A-06 NCIU A-06 was spud on 5/11/69. The 7" casing was set on 5-26-29/69. The casing was cemented in two stages. The first stage contained 402 sx of Class G with 132 bbls prehydrated 8.5%Diacel "D" and 2% gel. The second stage was 705 sx of Class G mixed with 105 bbl of 2% CaC12. Additonally, squeeze perfs were shot at 4299-4300 ft and squeezed with 118 sx Class G with 15 bbls 2% CaC12. Top of cement based on displacement is approximately surface to 644 ft The CBL dated 5/27/69 indicates a top of cement at least 2480 ft MD or -2210 SS. 'The annular pressure for this well (Attachment 5) shows no abnormal behavior. • • September 8, 2008, page6 B-Ola Disposal Injection NCIU A-07 NCIU A-07 was spud on 6/5/69. The 7" casing was set on 6/20/69. The casing was cemented in two stages. First pumped was 525 sx of Class G mixed with 130 bbls prehydrated 10% Dicel "D" and 2% CaC12. This was tailed with 760 sx of Class G with 91 bbls water with 2% CaC12. Squeeze perfs were shot at 4353-4354 ft and squeezed with 130 sx of Class G. Top of cement based on displacement is approximately 1900 to 3970 ft MD The CBL dated 6/22/69 indicates a top of cement at 2510 ft MD or -2239 SS. The annular pressure for this well (Attachment 5) shows no abnormal behavior. NCIU A-09 NCIU A-09 was spud on 8/20/69. The 7" casing was set on 9/11!69. The casing was cemented with 446 sx of Class G mixed with 107 bbls prehydrated 10% Diacel D with 2% CaC12. Top of cement based on displacement is approximately 3320-4879 ft MD The CBL dated 7/28/92 indicates a top of cement at 2590 ft MD or -2258 SS. The annular pressure for this well (Attachment 5) shows no abnormal behavior. NCIU A-12 NCIU A-12 was spud on 10/22-23/69. The 13-3/8" casing was set at 6949 ft 11/6/69. The casing was cemented with 1600 sx Class G followed by 120 sx Class G. Top of cement based on displacement is approximately 3772 to 4831 ft MD. The CBL dated 5/3/70 indicates a top of cement at 1990 ft MD or -1874 SS. The annular pressure for this well (Attachment 5) shows no abnormal behavior. NCIU B-Ola NCIU B-O1 was spud 7/30/97. The 13-3/8" casing was set at 3760 ft on 8/8/97. The casing was cemented with 1234 sx with 3% gel plus 0.25% CFR-3 and 1% CaC12. This was followed with 672 sx plus 2% CaC12. Cement returned to surface. Tested 2000 psi for 30 min Top of cement based on displacement is surface. The CBL dated 9/3/97 has ambiguous results because of two strings of cement. The log calls top of cement at 2590' MD or -2389 SS. The annular pressure for this well (Attachment 5) shows no abnormal behavior. The spike in the outer annulus pressure was caused by the infectivity test on 7/25/08. NCIU B-3 NCIU B-03 was spud 5/4/98. The 13-3/8" casing was set at 4329 ft on 5/11/98. The casing was cemented with 1000 sx lead cement @ 12 ppg. It was tailed with 600 sx @15.8 ppg. The casing was pressure tested to 2000 psig on 5!12!98. Top of cement based on displacement is approximately surface to 1483 ft MD. The CBL is not available over the interval of interest. The annular pressure for this well (Attachment 5) shows no abnormal behavior. Cement Bond los for B-OlA. A cement bond log for B-Ola over the proposed disposal zone is included as Attachment 6. Updated Fracture Model The original fracture modeling for Disposal Injection Order 17 used B-OlA as a basis for simulating fracture propagation using athree-dimensional hydraulic fracturing simulator (MFrac-III). Specific data used in the original modeling can be found in DIO 17 documentation on file at the Commission. The original fracture modeling injected 400 bbls of slurry with a concentration of 7.41bm/gal of solids at a rate i September 8, 2008, page? B-Ola Disposal Injection of 1.5 bpm. According to the latest Sundry of Well Operations (10-404) dated 11/17/98 reporting cuttings reinjected, the cumulative injected was 134,325 barrels of slurry. The revised fracture modeling used the 14.46 ppg EMW leak-off test on 8/16/97 at 3780 ft MD as a basis for the stress pressure in the confming layers and includes the prior injection volume. Input parameters are shown in the diagram below. The treatment schedule pumps the following: • 150,000 bbls of 7.41bm/gal slurry in one stage @ 2.4 bpm (aka "historical cuttings disposal"), • disposal of produced water for approximately two years at a nominal 1.0 bpm (aka PW disposal), which is the current maximum water handling capability of the Tyonek Platform. • 60,000 bbls of 7.4 lbm/gal slurry injection ay 2.4 bpm (aka "future cuttings disposal"). Fracture modeling results indicate the fracture was contained by the confming layers. 'The maximum fracture length was 390 ft from the wellbore during the "historical cuttings disposal" period if all was injected in a single stage at 2.4 bpm. During "PW disposal", the fracture relaxes to 190 ft because of the higher fluid leak-off and lower rate. The fmal "future cuttings disposal" period does not increase the fracture half length because the volume is not sufficient to extend the fracture length beyond the "historical cuttings disposal" period. The model input assumptions and output is given in Attachment 7. A schematic of the fracture results are shown below. B-01a Fracture Results Fracture length (one wing), ft 0 50 100 150 200 250 300 350 400 3200 3250 3300 F~rfs 3306-3339 ND ~' 3350 3400 3450 3500 1. Historical Cuttings Disposal: 200,000 bbls 7.4 ppg slurry @ 2.4 bpm 2. PW Disposal: 1,000,000 bbls produced water @ 1 bpm 3. Future Cuttings Disposal: 60,000 7.4 ppg slurry @ 2.4 bpm Injection String 2-3/8", 4.7 Ibm/R tubing Bottom of upper confining layer @ 3260 TVD, 2543 psi stress F PW Disp rac Len osal ...... 190 ft ....... Historic Fr al Cutting ac Len 3 s Injectio 90 ft••••°•° n ""'~ T op of low er confin ing layer @ 3380 ~ ND, 271 ~ 4 psi str ess Injec tion zone 3260-33 38 T~/D, 2366 psi stress September 8, 2008, page8 B-Ola Disposal Injection Discussion of A-12 performance to date. NCIU A-12 injects approximately 1000 bbls of water every other day. Daily injection rates and pressures average 700 BWPD at 1300 psia when the well is actively injecting fluids. A plot of the rate and pressure versus time over the past year is shown in Attachment 8. The last Mechanical Integrity Test was performed and witnessed by AOGCC representative Louis Grimaldi on July 5, 2005. North hook lnl~t. Fuld t~epth Structure on Tops of C.I. 1 Sind a ~ 1Qe NCI ST 1 6. ~ ~ w~ 000 ~ P ' ~ m '/ ~~@Q 3 M ~' M a a QQ ~ @ , ~ , ~ °a ~ ,3°jQ w w / ,,®00 ~ ~@m / ~/ SUNFISH ~ I w~ CI ~11 ~ I ~' I -1 3e~$ NGI A-Q1/NCI A-05 NCI A-10 h/ NCI A-08 NCI A-1Q "` ~ le ' ~ ®m C I L7 / ' w~ Q~ / ~ o oQm f r~ NCI -02 I o-m ~ ~ ~ ~ o- / CIA 43 ' / @ / a~ / mm~ ~ a / m a p. m t+f m I ~ NCI A S GI 7 '~N A-O~m / A wm ~ ti 17 ~ ST ~ I A- NGI Q7 ~ / '^ ~ @Q / ~~~ e ~ c ~ 0 1 ~ + FISH a / '~4 ~ 98 N B-O1 NI Q F ~QQ m `` -3~0 NCI B -p l S' ~ a' y ~`aQ ~?8e ~9~~8 C X18 41 1 m y~aQ 8s ~ m a~Q ~ ` NCI 8 3P91 ~ ~~ o~ 'y ~ ;~ s~6 ~ ~ _ 5 T 1 _ q1~ / ~2~~ s `9988 ~ ~ ~e ' 436 ~ ~m w~ ~~QO ~ ~ / P~ m~ ' ~@0 968 ~ I ~ ~o ~~~ ~~~-~ ~ ¢ ~Qx se ~ ~ u~ Attachment 1 Sterling Fm. ^ Shallow Sand Injection Zone in NCI B-01a Approximate - - - Gas /Water Contact in Cook Inlet 1 Sand Line of Cross Section 1 Mile , N • • R. A. Levinson 11/04 Attachment 2 CrQ~ ~C~IQ~1 ~i~lln~ NCB B*~~~ 't~~tJ~~ ~ItS~~ ~~" ConocoPhillips Alaska R. Levinson NCI A-12 NCI B-02 NCI A-11 North Soufh 50: i £vi S 6NP~SNP N_t 9 A s 6 , m ~ ~~ , ~ _ ~ -' NwdS CNi 6_, a ~ a~~ '~~~~ ~ EPi 'S --- ~ $NGL SNa 6 1 a n a ow .m o-xu .m a -w ., ~ NCI B-01a ------__ -- -- - -- - __~__ -- <~532'~ n6o 564'- --- -- '~° -- - ----- -- ~508'~ ~,~ ~66 , _ _ _ --_ --- - - - ~ --- - - - - - __-" ~,~ - . i SSND ~ MD I i z~5o i _ - fio oo _ 6,w ,~ _ ~ _ .. _. _.- .. :666 - 2 00 ; . ' . ._.__.- 2700 , _ ieao ~o6 _ - ~ ..- voo - - f ' n6o , -- .. - - - ~ nob nso r S - 3n6 , zloo ___ -'-- -__ X966 -- - a -- .. 2 10. , -- - -- -- - ~6 - o X60 i ~ . 3,~ „~ 2900 2 00'' 3osa .. - - 3950 .... ~ --.- 3100 ~ _ - - - - -'i _ - .. ..-. .. - - - .. . .. .. .. ~ _ - . __ - . - __ ~. ..._..._~. .. awo .... 3000 i i i 6,o0 . -_ >rm - --- 3 -- -- .- - - -Jn II I - - 900 .. __ _.: ~~ _. .. -~ - . ]000 ~. ~` 3 A - .. I I 3,50 -- ... ..... 3]00 .. ~ .. _ -- -_ f- 831' --------- _ -- - - J666 - ~ -- -- -- -- -- ~ 785'-~ ---------- _ Soso `, _ - X779': ------------- - - ~ 3;m --- - --- --- --- - s,oo > r -, , - - - -- 3~6 _ - - ,00 - - - ---- - -- - --- ~ - 3,a0 - - 3 D j .- r -- - -- -- -- - --- _. -' t _ ii i~i . _ . i - a 5.7 . .. - .. z; SSS 3200 ~ I I ll - J ~~ ~ ~ Upper !l ,j,{ { ~ ~ ~~ '~ U ... ~ ti ~ ~ ~ . r , ~ , r ~ ~ t : .l A = L.' ~~ L wer ` ~~ 1z. ~s r ~ ~ t. ~ w ~ 1 , r 3300 - ``"~-. z - 3 ,mo . ~ ww - - ~~ _ _ -~ .._._ ~_. f ,300 - ,. .,.. 3 00 - ~. --^-. - .. . - ~ ~ - ~~~ i 3nw >t_ ___ nso .. ~ - .,w -- .. .. 3400 ., a i f 6506 nso " -. >330 - - ' - ~~ .n f-1094'---- 3550 '- ~ 990' ~,~ <,. <~-916' >so '°~° _ ___ "~° Datum = Top of Stray . ~ <>~ .. .. ., 6600 _.._... x5o 3mo .. --.. -. - _ ... axa 3550 - _.. ~ ~ 3650 9550 _-, - "~ _ ~ .. 00 3550 ` _._ .. - 5ac0 .. I - _ 359 3100 J950 %00 J60D - - ~ 113'F'-- .a~ - ~ __ ~-101 T~ :: 3~6 - . .. 3]00 3]50 - _. ' C.~.~ .. } 3soo - - -~ >s~ ~ 1209=~ zuo ~ ~ ,656 ~ _ __ • 108 { 3em - - _ .. Q, NCIU B-01 a -- Type Log Attachment 3 Recorded CDR LWD Log nadrllt Varalo n: 2.oA-070 <MD > Vertical Scab: z• ar t0o~ Ora hlea Flls v'reatad: No Fila Gam a Aa GA CDR haaa Hbltt Re latlvll P6R (QAPI) ]00 0.1 (OHMM) 2000 SSND R tO OF pens retlan`5( '(tared iRQPSj_ MD _ _ _ _ Arie~Oal _on FleelstwHy rwTA)_ _ _ _ _- 0 {F'/HA) O 0.2 (OHM&f) II000 3000 2800 _ 3100 _ _ 2900 • .~ 3zoa - - - T - - - - - - - - - - Top Confining Zone 3000 3300 _ Arresting Zone Confining Beds Arrestin Zone 3aaa g 3100 Confinin Beds g ~ ~ _._ _. - _ _ __ ;~:~~~- ___ _._._ _ -_ - _ _ _- Existing ~ 3200 f '. . ._ - --- .._,_,~.. Perforations - -- Disposal Injection Zone t I t -N ....... __._ _...._ .~. „{ _T . .. i , ( ~ ~~ __ _ _ ~ ' ' ~ t; Confining Bed `~ t . ! Arresting Zone 3300 - ;~ _ - :~ 3700 I _ - _ - _ i B C fi d _ - __ - ng s on n e i Casing - - ~ Shoe { 3400 aeoo Arresting Zone Lower Confining Bed • C.I. Stray -Top of Gas Production 3500 C.I. A C.I. B aaoo 3600 4]00 3700 ' - " ~ • _ _ _ - _ C.I. 1 -Structure Map Surface _ _ _ aaoo 3800 a3oo C.I. 2 C.I. 3 • • Attachment 4 Table of Distances Between Wells in Proposed Injection Zone Distance to Distance to Distance from top of zone, bottom of Within B-01A zone B-01a ft zone, ft of interest? NCI A-01 2,074 2,148 NCI A-02 1,750 1,802 NCI A-03 1,448 1,498 NCI A-04 971 990 Yes NCI A-05 2,220 2,295 NCI A-06 737 761 Yes NCI A-07 466 468 Yes NCI A-08 2,480 2,584 NCI A-09 1,406 1,452 NCI A-10 2,457 2,547 NCI A-11 2,483 2,567 NCI A-12 883 921 Yes NCI A-13 1,974 2,046 NCI B-01 - - Yes NCI B-01A - - Yes NCI B-02 1,717 1,784 NCI B-03 944 983 Yes NCI B-03PB1 944 983 Yes NCI ST 1 12,183 12,210 • • Attachment 5 NCIU A-01 Pressures 40U 400 350 300 250 ~N a 200 150 100 50 0 • Jan-04 Jui-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 NCIU A-2 Pressues 600 500 400 as '~ 300 a 200 100 0 A-2 FTP A-21NNER_ANNULUS PRESS -A-2 OUTER ANNULUS PRESS Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jul-08 • NCIU A-03 Pressures soo 700 600 500 m '~ 400 a 300 200 100 0 -A-3 FTP A-31NNER ANNULUS PRESS -A-3 OUTER ANNULUS_PRESS II! • • Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jul-08 NCIU A-04 Pressures 500 450 400 350 300 m 'w 250 a 200 150 100 50 0 Jan-04 A-4 FTP A-41NNER ANNULUS PRESS A-4 OUTER ANNULUS PRES: Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jul-08 NCIU A-05 Pressures 600 500 400 m '~ 300 200 100 0 Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jul-08 •~~ • NCIU A-06 Pressures 450 400 350 300 250 m .~ a 200 150 100 50 0 • • Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 NCIU A-07 Pressures 500 450 400 350 300 m '~ 250 a 200 150 100 50 0 -A-7 FTP -A-7 INNER ANNULUS PRESS -A-7 OUTER_ANNULUS_PRESS ~'' • Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 600 500 400 m 'w 300 a 200 100 0 NCIU A-08 Pressures • Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 NCIU A-09 Pressures 600 500 400 m '~n 300 a 200 -A-9 FTP A-91NNER ANNULUS PRESS -A-9 OUTER ANNULUS PRES: 100 • • 0 h If1 I ~ II,~~j r I I I. ,~, II II 1 ~' I I P '~ - F I Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 NCIU A-10a Pressures 1,200 1,000 A-10A FTP A-10A INNER ANNULUS_PRESS -A-10A OUTER ANNULUS PRESS 800 as 'w 600 a 400 200 .a.al„"".~~~wf~.1 0 1 1 III I I~ I I 1 11 II I M 1-' 1 1 I hl I I I~ 1 '. I Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 w NCIU A-11 Pressures 700 600 500 400 m .~ a 300 200 100 0 Jan-04 A-11 FTP A-11 INNER_ANNULUS_PRESS -A-11 OUTER ANNULUS PRESS Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 NCIU A-12 Pressure 3000 2500 2000 m '~ 1500 a 1000 500 0 i s • A-12 Inj Pres -A-12 FTP A-121NNER ANNULUS PRESS - ~ -A-12 OUTER ANNULUS PRESS • - - ~ • • • • i • • „ . .• •. ~ ~ • • • • • ~l...l...,_ Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jui-08 • NCIU A-13 Pressures 1200 1000 800 m 'w 600 a 400 200 • • Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jul-08 NCIu B-01a Pressures 1, 200 1,000 800 a~ 'in 600 a 400 200 0 - B-1 A FTP B-1A INNER ANNULUS PRESS -B-1A OUTER ANNULUS PRESS i i Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 • • NCIU B-02 Pressures 900 - B-2 FTP B-2 INNER_ANNULUS_PRESS 800 -B_2 OUTER ANNULUS PRESS I ~ - - - 700 600 500 g~ .y a 400 300 -- 200 100 0 • Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 NCIU B-03 Pressures 600 500 400 m '~ 300 a 200 100 0 • • Jan-04 Jul-04 Dec-04 Jul-05 Dec-05 Jul-06 Dec-06 Jul-07 Dec-07 Jul-08 Dec-08 l._.~J N Attachment 6 ~~. 6~ Slze~ Lo~- ~~ ~ _ .. - - C~?~APl4~tJY Phillips Petroleum Corp. . c W~f..L:_ Nart1~ Cook Inlet Unit °B" i~la. 1 y ~ E ~~E~C7 Nt~rth Cook Inlet c c A :~ 's ;~ °- . . .: ~ ~ ~ ~ t~3FtU{.f~H li~nai S'1EAT~ _ ,b o ~ 9 _. t ~ ~ = z ~ Q # 7?~' F ILL ~. 92a' F+~JL x - a ~ hJ 'tiarfac~ - ~ z `~ ~ ~ ~ A f' f ~3 E R IA l . H~ SECT. T V 1- l s , ft R NGI •' J ~ U ~ Q j 'y A~ 3 ~ } ~ y W VU~YGY~J~ ~''{~ r y , y y ~•y ~ G~Lt 6 1 i,Y ~ ~~! P~rmsnent [7st19Y;i MSL Elev. D.0 F _ Log_MGasurec3l~rvm F1KB t3~TJ F s~oy8 ~rrh_ i3s4sm Drilli Nlessur~dFrnm RKB - _ Omt~ 03-SEP- i :~7 FUJ17 hdo. `~ Y~ L}epth I~rflier 103g0.b F 13epr2h Logger t~L) . X713,0 F -..- Blrrs. La_g Irit~rxn~ „)`~ C1 F Tap Lr~ I rrteryeF t 507.0 F F `~ lypa Fluid in M+vl~ F~e~ii ti1`Jater MUD ~~ - Satlnli lVa~b _ ~4UQ.U PPM _ Fluad~Larel • Dp F Maot. F~ 7•ntnp. .^ ._ .~.:d. ll~C3F _, '~ _flCV1~lUR ~ ;yj [}~i[j ~ __ -~~ ~O J$~1' ~Y2 F~G~O(TI 78' U[l ~- . i~quiEk Lac~lfi4i~ 31Q Kenai Alaska ~r~rl t3~ _ : Ftaeisel l .'ash , _ ~.:TirHn~c~ 6y - •` j Mr. M,.rk Ki~p~ . - BO~~ENdLt = FiECr3r~- Q - ~11t 5€~ . 12 91,x' ~ ~ Y 0380. C7 F _ -_ ''•~ C/1^slt4l~ 8s TLIBIf1Gi 1~(:QFi!€3 ~~= - 133113' _ 17ei h[ ~ _ _ ~ 72_Clu~}U Li~rF _ Ca~irig'T~op-Ariiter `', c7, f} F _ - _ CesirFgaFls~-['Irliier ~ ~1?E~J.DF~ _ _ 37E~,0 F AlasEc~ CkheC '~aervi cx._t: QITE r..u r CNL F1FY C~I~v = M4.I i,'1 ~2A i' ~.F.13S.o F G.L I v~~'r~~ I ~ i=~ ~.~ ~°-.~~~~ = ~', I ~ a : G ~ I ~;°~~~~ ~' I mra.a'~ tai '~'~ ~ ~:: N I m- ;:v ^, •~,. ~ o ~; ~ Q. '.I ~U~r~tA s• I LL'x d'aF ~ v ~• ~, s: ~ ~-" ~ a- ~ an t ~ •- -Lg! ~c '~ S~ ~r a ~a' I -~s m w. c~ rt. ° ~ `n~ nri ~ H3 T N ' v n.• 6 p ayt2 a m r ~ ~ LS I ~ • C tl.~ I ~ ~ VR ~ V c _~ :. I ~.~~~~ai ~ m v` Et) u Q~77 L.. ~ ~ Li .fJ.~.~~ ~ U v mc-~3rna r ~ L v ~ ~ ~~ j m ur ti 1 rs~n°'•~n r• ~_ ~~~~ 6 *' c a ~ RF ~ ~ ~ c ~~^.n n 1 ~~ ~~~ '= C.1~` 'u ~ ~ -~- ~ ~ V I I i I N l; Q A t3 u ~ .5t e i= J`r ~~ N Attachment 7 MFrac Three-Dimensional Hydraulic Fracturing Simulator MFrac is a trademark of Meyer 8 Associates, Inc. Copyright (c) 19852006, Meyer 8 Associates, Inc. 2130 Freeport Rd, Suite C, NaVOna Heights, PA 15065 USA MFrec versbn 5.30.3263 http:/lmftac.coM Simulation Date 8/2512008 2:59:30 PM Company: CPAI Well: NCIU B-1 LocaBon: North Cook Inlet Date: August 19, 2008 Comments: Steding Sand Input Data GENERAL OPTIONS Simulaton Method Reservoir Coupling Net Present Value Fluid Loss Model Fluid Type Dependent Leakoft Include Fluid Loss History Treatment Type Treatment Design Wellbore Hydraulics Model No. of Frac Soln. Iteratbns Maximum Time Step Heat Transfer Oft, Fluid Temperature: FRACTURE OPTIONS Fracture Geometry Fbwback Fracture Fluid Gradient SeH Similar Closure Propagation Parameters Fracture Initiation Interval Fracture Friction Model Wall Roughness Tip Effects PROPPANT OPTIONS Proppant Solution Proppant Ramp Proppant Flowback Perforation Erosion Proppant Transport Methodology Proppant Settling Option Wellbore-Proppant Effects Fracture-Proppant Effects ROCK PROPERTIES Design Mode Linear Ofl Constant OH Oft Proppant Input Empirical - Virk/KecWPrendtt 30 1 (min) 90 (deg F) Three-Dimensional Off Inctuded Off Default Growth Perforated Interval Off Oft OH On On Off None Conventional Empirical None None TVD at Bottom MD at Bottom Stress Gradient Stress Zone Name (ft) (ft) (psUft) (psi) Fracture Young's Modulus Toughness Critical Stress Stress (psi) Poisson's Ratio (psi-in^1/2) (psi) Interpolation Upper Bound 3260 Sterling 3380 Lower Bound 3480 FLUID LOSS DATA Zone Name 3442.4 0.78 3590.8 0.7 3716.7 0.78 ND at Bottom (ft) 2542.8 2366 2714.4 2e+O6 1e+O6 2e+O6 MD at Bottom (ft) 0.35 1000 0.22 2000 0.35 1000 Leakoff Coef. (ft/min"1/2) 0 Off 0 Off 0 Off Spurt Loss (gaI1100 ft"2) Upper Bound 3110 3260 0.1 1 Steding 3209.1 3380 0.1 5 Lower Bound 3290.6 3480 0.1 1 WELLBORE HYDRAULICS DATA General Wellbore Volume 27.127 (bbl) Injection Down Tubing Horizontal Well 08 Surtace Line Volume 0 (bbl) Wellbore Volume Reference MD 3590.8 (ft) Wellbore Volume Reference TVD 3380 (R) Maximum BHTP 10000 (psi) Deviation linear Segments Off MFrac -NCIU B-t Multiwell - 8/25/2008 _1 - Measured Depth TVO gle (ft) (ft) (deg) 200 200 0 300 300 0 400 400 0 430 430 0 557 557 0 710 709.96 2.2693 860 859.81 2.845 1029 1028.4 5.3033 1119 1117.9 5.7684 1214 1212.3 7.3008 1307 1304.5 7.7383 1400 1396.4 9.7058 1493 1487.9 10.959 1588 1580.9 12.864 1681 1671.4 13.655 1776 1763.2 16.093 1871 1854.1 17.643 1965 1943.4 19.011 2059 2032.1 19.688 2155 2121.9 21.572 2248 2208.2 22.255 2342 2294.9 23.138 2432 2377.4 23.941 2527 2463.8 25.131 2555 2489.2 25.223 2620 2547.9 25.276 2714 2632.7 26.014 2807 2716 26.815 2900 2798.9 27.113 2990 2878.2 29.267 3083 2959 29.989 3179 3041.5 31.49 3274.3 3121.9 33.393 3370 3200.9 35.39 3463 3276.8 35.296 3553 3349.7 36.487 3648 3425.5 37.671 3860 3594.6 36.47 Casing Relative Pipa Roughness p Fdctfon Loss Multiplier 1 Measured Depth Section Length OD Weight ID (ft) (ft) (in.) (Ibf/ft) (in.) 2600 2600 20 106.5 19 3860 1260 13.375 68 12.415 Tubing Relative Pipe Roughness 0 Friction Loss Multiplier 1 Measured Depth OD Weght ID (ft) (in.) (IbfHl) (in.) 3500 2.375 4.7 1.995 BHTP References Measured Depth TVD Reference Name (ft) (ft) Main BHTP 3590.8 3380 PERFORATION ZONES Top of Perfs TVD Bottom of Perfs TVD Top of Perfs MD Bottom of Perts MD Active Zone (ft) (ft) (ft) (ft) 1. Yes Sterling 3306.9 3339.2 3500 3540 ZONE DATA Mul&Layer Pay Zone No. of Multiple Stiffness Fluid Loss Stiffness Mulct-Layer Fluid From To Perm. Perforations Diameter Zone Fractures Interaction Interactlon Interaction Loss Interaction (ft) (ft) (md) Number (in.) 1. Sterling 1 0 0 0 0 3260 3480 1500 120 0.46 INPUT BOTTOMHOLE TREATMENT SCHEDULE Schedule Typa Bottomhole Flush Fluid Type KCL2 Recirculatbn Volume 0 (bbl) Slurry Rate Stage Liquid Voluma Stage Time Prop Conc. From Prop Conc. Ta Stage No. (bpm) (bbl) (min) Stage Type Fluid Type Prop Type (Ibmlgal) (IbMgaq Prop Damage Factor 1 2.4 200 83.333 Pad KCL2 0000 0 0 0 2 2.4 1.4986e+OS 83333 Slug KCL2 0007 7.4 7.4 0 3 1 1e+O6 1e+O6 Flush KCL2 0000 0 0 0 4 2.4 60000 33365 Slug KCL2 0007 7.4 7.4 0 Fluid Type: KCL2 - 2% KCI Proppant Type: 0000 - No Prop, Slug, ... Proppant Type: 0007 - 40/70 St. Peter Sand MFrac - NCIU B-1 Multiwell - 8/25/2008 -2- • PROPPANT CRITERIA Min. Number of Proppant Layers to Prevent Bridging Min. Concentre8on/Area for Propped Fracture Embedment Concentration/Area Cbsure Pressure on Proppant Output Data BOTTOMHOLE TREATMENT SCHEDULE PUMPED Avg Slurry Rate Liquid Volume Slurry Volume Stage Na. (bpm) (bbl) (bbl) • 2 0.5 (IbmHt"2) 0.5 (Ibmfft"2) 100 (psi) Total Slurry Volume Total Time Conc. From Conc. To Prop. Stage Mass (bbl) (min) (Ibmlgal) (Ibmlgal) (Ibm) 1 2.4 200 2 2.4 1.4986e+05 3 1 1e+O6 4 2.4 59999 Total Slurry Volume Total Liquid Volume Total Sand Mass WELLBORE HYDRAULICS SOLUTION Tme Delta P Friction (min) (psi) 200 2e+O5 1e+O6 80075 lta P (psi) 200 2.002e+OS 1.2002e+O6 1.2803e+06 1.2803e+O6 1.2101e+O6 6.5223e+07 GravRy 83.333 83417 1.0834e+O6 1.1168e+O6 HTP (psi) 0 7.4 0 7.4 (bbl) (bbl) (Ibm) 0 7.4 0 7.4 urface Pressure (psi) 0 4.6575e+07 0 1.8648e+07 ydraulic Power (hhp) 1 250.51 1482.6 2488.3 1256.2 73.863 11264 352.34 2085.2 2469.8 736.86 43.327 22528 352.34 2085.2 2471.1 738.2 43.406 33792 352.34 2085.2 2471.7 738.83 43.443 45056 352.34 2085.2 2471.8 738.91 43.446 56320 352.34 2085.2 2472.3 739.43 43.479 67584 352.34 2085.2 2472.5 739.59 43.488 78848 352.34 2085.2 2472.6 739.7 43.494 90112 52.183 1482.6 2460.9 1030.5 25.247 1.0138e+OS 52.183 1482.6 2459.3 1028.9 25.208 1.1264e+O5 52.183 1482.6 2458.5 1028.1 25.188 1.239e+05 52.183 1482.6 2458.3 1027.8 25.182 1.3517e+05 52.183 1482.6 2458.7 1028.3 25.193 1.4643e+OS 52.183 1482.6 2459.1 1028.7 25.203 1.577e+05 52.183 1482.6 2459.4 1029 25.21 1.6896e+OS 52.183 1482.6 2459.7 1029.3 25.217 1.8022e+OS 52.183 1482.6 2459.9 1029.5 25.222 1.9149e+OS 52.183 1482.6 2460.1 1029.7 25.227 2.0275e+05 52.183 1482.6 2460.3 1029.8 25.231 2.1402e+OS 52.183 1482.6 2460.4 1030 25.235 2.2528e+OS 52.183 1482.6 2460.5 1030.1 25.238 2.3654e+OS 52.183 1482.6 2460.7 1030.2 25.241 2.4781 a+OS 52.183 1482.6 2460.8 1030.3 25.243 2.5907e+OS 52.183 1482.6 2460.9 1030.4 25.246 2.7034e+OS 52.183 1482.6 2461 1030.5 25.248 2.816e+05 52.183 1482.6 2461 1030.6 25.25 2.9286e+05 52.183 1482.6 2461.1 1030.7 25.251 3.0413e+OS 52.183 1482.6 2461.2 1030.7 25.253 3.1539e+05 52.183 1482.6 2461.2 1030.8 25.254 3.2666e+05 52.183 1482.6 2461.3 1030.8 25.256 3.3792e+OS 52.183 1482.6 2461.3 1030.9 25.257 3.4918e+OS 52.183 1482.6 2461.4 1030.9 25.258 3.6045e+OS 52.183 1482.6 2461.4 1031 25.259 3.7171 a+OS 52.183 1482.6 2461.4 1031 25.26 3.8298eW5 52.183 1482.6 2461.5 1031.1 25.261 3.9424e+OS 52.183 1482.6 2461.5 1031.1 25.262 4.OS5e+05 52.183 1482.6 2461.5 1031.1 25.262 4.1677e+OS 52.183 1482.6 2461.6 1031.1 25.263 4.2803e+OS 52.183 1482.6 2461.6 1031.2 25.264 4.393e+OS 52.183 1482.6 2461.6 1031.2 25.264 4.SOS6e+OS 52.183 1482.6 2461.6 1031.2 25.265 4.6182e+OS 52.183 1482.6 2461.7 1031.2 25.265 4.7309e+O5 52.183 1482.6 2461.7 1031.3 25.266 4.8435e+O5 52.183 1482.6 2461.7 1031.3 25.266 4.9562e+O5 52.183 1482.6 2461.7 1031.3 25.267 5.0688e+O5 52.183 1482.6 2461.7 1031.3 25.267 5.1814e+OS 52.183 1482.6 2461.7 1031.3 25.267 5.2941 a+OS 52.183 1482.6 2461.8 1031.3 25.268 5.4067e+05 52.183 1482.6 2461.8 1031.3 25.268 5.5194eW5 52.183 1482.6 2461.8 1031.4 25.268 5.632e+05 52.183 1482.6 2461.8 1031.4 25.268 5.7446e+05 52.183 1482.6 2461.8 1031.4 25.269 5.8573e+05 52.183 1482.6 2461.8 1031.4 25.269 5.9699e+OS 52.183 1482.6 2461.8 1031.4 25.269 6.0826e+05 52.183 1482.6 2461.8 1031.4 25.269 6.1952e+OS 52.183 1482.6 2461.8 1031.4 25.269 6.3078e+OS 52.183 1482.6 2461.8 1031.4 25.269 6.4205e+OS 52.183 1482.6 2461.8 1031.4 25.27 6.5331 a+05 52.183 1482.6 2461.8 1031.4 25.27 6.6458e+05 52.183 1482.6 2461.9 1031.4 25.27 6.7584e+O5 52.183 1482.6 2461.9 1031.4 25.27 6.871 e+05 52.183 1482.6 2461.9 1031.4 25.27 6.9837e+OS 52.183 1482.6 2467.9 1037.4 25.27 7.0963e+O5 52.183 1482.6 2461.9 1031.4 25.27 7.209e+OS 52.183 1482.6 2461.9 1031.4 25.27 7.3216e+OS 52.183 1482.6 2461.9 1031.4 25.27 7.4342e+OS 52.183 1482.6 2461.9 1031.4 25.27 7.5469e+OS 52.183 1482.6 2461.9 1031.4 25.27 7.6595e+OS 52.183 1482.6 2461.9 1031.4 25.271 7.7722e+05 52.183 1482.6 2461.9 1031.5 25.271 MFrac - NCIU B-1 Multiwell - 8/25/2008 3 Time Delta P Friction P Gravity BHTP S sure Hydraulic Power (min) (Psi) (Psi) ( (hhP) 7.8848eW5 52.183 1482.6 2461.9 1031.5 25.271 7.9974e+OS 52.183 1482.6 2461.9 1031.5 25.271 8.1101e+OS 52.183 1482.6 2461.9 1031.5 25.271 8.2227e+O5 52.183 1482.6 2461.9 1031.5 25.271 8.3354e+OS 52.183 1482.6 2461.9 1031.5 25.271 8.446e+05 52.183 1482.6 2461.9 1031.5 25.271 8.S606e+05 52.183 1482.6 2461.9 1031.5 25.271 8.6733e+OS 52.183 1482.6 2461.9 1031.5 25.271 8.7859e+05 52.183 1482.6 2461.9 1031.5 25.271 8.8986e+05 52.183 1482.6 2461.9 1031.5 25.271 9.0112e+p5 52.183 1482.6 2461.9 1031.5 25.271 9.1238e+OS 52.183 1482.6 2461.9 1031.5 25.271 9.2365e+OS 52.183 1482.6 2461.9 1031.5 25.271 9.3491e+05 52.183 1482.6 2461.9 1031.5 25.271 9.4618e+OS 52.163 1482.6 2461.9 1031.5 25.271 9.57dde+OS 52.183 1482.6 2461.9 1031.5 25.271 9.687e+05 52.183 1482.6 2461.9 1031.5 25.271 9.7997e+OS 52.183 1482.6 2461.9 1031.5 25.271 9.9123e+OS 52.183 1482.6 2461.9 1031.5 25.271 1.0025e+O6 52.183 1482.6 2461.9 1031.5 25.271 1.0138e+O6 52.183 1482.6 2461.9 1031.5 25.271 1.025e+O6 52.163 1482.6 2461.9 1031.4 25.271 1.0363e+O6 52.183 1482.6 2461.9 1031.4 25.27 1.0476e+O6 52.183 1482.6 2461.9 1031.4 25.27 1.OSBBe+O6 52.183 1482.6 2461.9 1031.4 25.27 1.0701 a+O6 52.183 1482.6 2461.9 1031.4 25.27 1.0813e+O6 52.183 1482.6 2461.9 1031.4 25.27 1.0926e+06 352.34 2085.2 2469.4 736.47 43.304 1.1039e+p6 352.34 2085.2 2469.8 736.92 43.331 1.1151 a+p6 352.34 2085.2 2470.9 738.01 43.395 1.1168e+O6 250.51 1482.6 2457.3 1225.2 72.04 FRACTURE TREATMENT SCHEDULE Avg Slurry Rate Liquid Volume Slurry Volume Total Slurry Volume Total Time Conc. From Conc. To Prop. Stage Mass Stage No. (bpm) (bbl) (bbl) (bbl) (min) (Ibm/gal) (IbMgal) (Ibm) 1 2.4 200 200 200 83.333 0 0 0 2 2.4 t.4986e+O5 2e+O5 2.002e+05 83417 7.4 7.4 4.6575e+07 3 1 1e+O6 1e+O6 1.2002e+O6 1.0834e+06 0 0 0 4 2.4 59999 80075 1.2803e+06 1.1168eW6 7.4 7.4 1.8648e+07 Total Slurry Volume 1.2803e+06 (bbl) Total Liquid Volume 1.2101 a+06 (bbl) Total Sand Mass 6.5223e+07 (Ibm) FRACTURE PROPAGATION SOLUTION Time (min) Total Volume (bbl) Net Pressure (psi) BHFP (psi) Fracture Lengfh (ft) Max. Wellbore Width (in.) Avg. Wellbore Width (in.) Avg. Fracture Width (in.) Upper Height (R) Lower Height (ft) Fracture Efficiency 1 2.4 97.261 2463.3 27.254 0.10264 0.081179 0.068766 25.443 29.404 1 15869 38086 69.277 2435.3 135.9 0.15119 0.1156 0.10094 64.726 59.586 0.0010643 31358 75260 69.336 2435.3 185.17 0.15949 0.12162 0.10724 65.018 59.794 0.00079145 46852 1.1245e+05 70.975 2437 221.53 0.16649 0.12692 0.11245 65.128 59.868 0.00067047 62099 1.4904e+OS 71.253 2437.3 251.56 0.16868 0.12855 0.11422 65.179 59.904 0.00058714 77387 1.8573e+05 71.42 2437.4 277.76 0.16994 0.12948 0.11527 65.207 59.923 0.00052761 93328 2.1011e+p5 69.336 2435.3 73.349 0.13082 0.10261 0.087759 55.012 58.638 0.0017427 1.0971 a+O5 2.265e+O5 67.717 2433.7 83.976 0.13143 0.10197 0.087566 61.921 58.718 0.00079416 1.2567e+OS 2.4245e+OS 67.366 2433.4 94.079 0.13341 0.10266 0.088517 64.867 58.802 0.00057438 1.408e+OS 2.5758e+05 67.953 2434 107.8 0.14017 0.10767 0.093267 65.135 58.947 0.00051395 1.5608e+OS 2.7287e+OS 68.403 2434.4 119.81 0.14514 0.11135 0.096802 65.32 58.043 0.00047046 1.714e+OS 2.8818e+05 68.758 2434.8 130.48 0.14891 0.11415 0.099521 65.452 59.112 0.00043681 1.868e+OS 3.0359e+05 69.044 2435 140.13 0.15187 0.11634 0.10168 65.552 59.164 0.00040924 2.019e+05 3.1868e+05 69.276 2435.3 148.87 0.15423 0.11809 0.10341 65.629 59.204 0.00038695 2.1776e+OS 3.3454e+OS 69.483 2435.5 157.54 0.15628 0.11961 0.10494 65.696 59.239 0.00036747 2.3352e+OS 3.5031 a+OS 69.656 2435.7 165.54 0.15797 0.12086 0.10621 65.75 59.266 0.00035058 2.4931e+OS 3.6609e+05 69.804 2435.8 173.13 0.1594 0.12192 0.10729 65.794 59.289 0.00033587 2.6513e+OS 3.8191e+05 69.934 2435.9 180.43 0.16063 0.12283 0.10823 65.832 59.308 0.00032299 2.8077e+OS 3.9755e+OS 70.043 2436 187.18 0.16166 0.12359 0.10902 65.863 59.324 0.00031133 2.9635e+p5 4.1314e+05 70.139 2436.1 193.64 0.16255 0.12425 0.10971 65.89 59.337 0.0003009 3.1237e+p5 4.2916e+05 70.226 2436.2 200.07 0.16336 0.12485 0.11035 65.914 59.349 0.00029125 3.2872e+OS 4.4551e+OS 70.304 2436.3 206.41 0.16408 0.12538 0.11092 65.935 59.36 0.00028234 3.4511e+OS 4.6189e+OS 70.373 2436.4 212.56 0.16472 0.12586 0.11142 65.953 59.369 0.00027418 3.6147e+05 4.7825e+p5 70.434 2436.4 218.47 0.16528 0.12627 0.11187 65.969 59.377 0.00026663 3.7784e+O5 4.9463e+05 70.488 2436.5 224.19 0.16577 0.12664 0.11227 65.983 59.384 0.00025965 3.9423e+OS 5.1101 a+OS 70.536 2436.5 229.76 0.16621 0.12697 0.11263 65.995 59.39 0.00025318 4.1061e+OS 5.274e+OS 70.579 2436.6 235.12 0.1666 0.12725 0.11295 66.006 59.396 0.0002471 4.27e+OS 5.4378e+OS 70.617 2436.6 240.38 0.16695 0.12751 0.11325 66.015 59.401 0.00024146 4.4338e+OS 5.6016e+OS 70.651 2436.7 245.48 0.16727 0.12775 0.11351 66.023 59.406 0.00023616 4.5976e+OS 5.7655e+05 70.681 2436.7 250.45 0.16755 0.12796 0.11375 66.03 59.411 0.00023115 4.7615e+05 5.9293e+OS 70.709 2436.7 255.31 0.16781 0.12815 0.11396 66.037 59.414 0.00022645 4.9253e+05 6.0932e+p5 70.733 2436.7 260.06 0.16804 0.12832 0.11416 66.043 59.418 0.00022201 5.0892e+OS 6.257e+OS 70.755 2436.8 264.68 0.16824 0.12847 0.11434 66.048 59.421 0.00021779 5.253e+05 6.4208e+OS 70.774 2436.8 269.22 0.16843 0.12861 0.1145 66.054 59.424 0.00021379 5.4168e+OS 6.5847e+OS 70.791 2436.8 273.68 0.1686 0.12873 0.11465 66.058 59.427 0.00021001 5.5807e+O5 6.7485e+05 70.806 2436.8 278.07 0.16876 0.12885 0.11479 66.064 59.429 0.00020643 5.7445e+OS 6.9124e+OS 70.82 2436.8 282.31 0.1689 0.12895 0.11492 66.068 59.431 0.00020296 5.9084e+O5 7.0762e+p5 70.832 2436.8 286.53 0.16903 0.12905 0.11503 66.072 58.433 0.00019968 6.0722e+05 7.24e+05 70.843 2436.8 290.64 0.16914 0.12913 0.11514 66.076 59.435 0.00019654 6.236e+OS 7.4039e+OS 70.853 2436.9 294.71 0.16925 0.12921 0.11524 66.079 59.436 0.00019354 6.3999e+OS 7.5677e+OS 70.862 2436.9 298.7 0.16935 0.12929 0.11533 66.082 59.438 0.00019067 6.5637eW5 7.7316e+O5 70.869 2436.9 302.62 0.16944 0.12935 0.11541 66.085 59.439 0.00018791 6.7276e+05 7.8954e+05 70.876 2436.9 306.48 0.16952 0.12941 0.11549 66.087 59.44 0.00018526 6.8914eW5 8.0582e+05 70.882 2436.9 310.29 0.1696 0.12947 0.11557 66.09 59.441 0.00018271 7.0552e+p5 8.2231 a+05 70.887 2436.9 314.03 0.16967 0.12952 0.11563 66.082 59.442 0.00018026 7.2191e+OS 8.3869e+O5 70.891 2436.9 317.73 0.16973 0.12957 0.11569 66.094 59.443 0.0001779 7.3829e+O5 B.SSOBe+OS 70.895 2436.9 321.38 0.16979 0.12861 0.11576 66.095 59.444 0.00017563 7.5468e+O5 8.7146e+OS 70.898 2436.9 324.97 0.16985 0.12865 0.11581 66.097 59.444 0.00017344 7.7106e+OS 8.8784e+OS 70.901 2436.9 328.51 0.1699 0.12969 0.11586 66.098 59.445 0.00017132 7.8744e+05 9.0423e+05 70.903 2436.9 332.02 0.16994 0.12972 0.1159 66.1 59.445 0.00016927 MFrac - NCIU B-1 Multiwell - 8/25/2008 -4- Time (min) Total Volume (bbl) Net Pressure (psi) B (psi Fracture Length (ft) Max. Wellbore Width (in.) Avg. Wellbore Width (in.) Av Wi~ (in.) Upper Height (ft) lower Height (ft) Fracture Efficiency 8.0383e+05 9.2061e+OS 70.905 2436.9 335.47 0.76998 0.12975 0.11595 66.101 59.446 0.00016729 8.2021e+O5 9.37e+OS 70.906 2436.9 338.89 0.17002 0.12978 0.11599 66.102 59.446 0.00016538 8.366e+05 9.5338e+OS 70.907 2436.9 342.27 0.77006 0.12981 0.11602 66.103 59.447 0.00016353 8.5298e+O5 9.6976e+OS 70.908 2436.9 345.6 0.17009 0.12983 0.11606 66.104 59.447 0.00016173 8.6936e+05 9.8615e+OS 70.908 2436.9 348.9 0.17012 0.12985 0.11609 66.105 59.447 0.00015999 8.8575e+OS 1.0025e+O6 70.908 2436.9 352.16 0.17015 0.12987 0.11612 66.105 59.447 0.0001583 9.0213e+OS 1.0189e+06 70.908 2436.9 355.38 0.17017 0.12989 0.71615 66.106 59.448 0.00015666 9.1852e+05 1.0353e+O6 70.907 2436.9 358.55 0.1702 0.12991 0.71618 66.106 59.448 0.00015506 9.349e+05 1.0517e+O6 70.807 2436.9 361.7 0.17022 0.12992 0.1162 66.107 59.448 0.00015351 9.5128e+OS 1.0681e+O6 70.806 2436.9 364.82 0.17024 0.12994 0.11622 66.107 59.448 0.00015201 9.6767e+OS 1.0845e+O6 70.905 2436.9 367.91 0.17025 0.12995 0.11624 66.108 59.448 0.00015055 9.8405e+OS 1.1008e+O6 70.903 2436.9 370.95 0.17027 0.12996 0.11626 66.108 59.448 0.00014912 1.0004e+06 1.1172e+O6 70.902 2436.9 373.99 0.17028 0.12997 0.11628 66.108 59.448 0.00014773 1.0768e+06 1.1336e+O6 70.9 2436.9 376.97 0.1703 0.12998 0.1163 66.108 59.448 0.00014638 1.0332e+O6 1.15e+06 70.898 2436.9 379.94 0.17031 0.12999 0.11631 66.109 59.448 0.00014507 1.0496e+O6 1.1664e+O6 70.897 2436.9 382.87 0.17032 0.13 0.11633 66.109 59.448 0.00014378 1.O66e+O6 1.1828e+O6 70.895 2436.9 385.79 0.17033 0.13001 0.11634 66.109 59.448 0.00014253 1.0824e+O6 1.1991 a+O6 70.893 2436.9 388.68 0.17034 0.13001 0.11636 66.109 59.448 0.00014131 1.0983e+O6 1.2359e+O6 69.75 2435.2 131.96 0.14994 0.11468 0.10003 64.696 59.557 0.00109 1.1138e+O6 1.273e+06 70.404 2436.4 182.28 0.1617 0.12338 0.10873 65.01 59.784 0.00081587 1.1167e+O6 1.2802e+06 70.761 2436.8 190.22 0.16338 0.12462 0.11 65.039 59.805 0.00078577 1.1167e+O6 1.2802e+06 70.15 2436.1 190.22 0.16197 0.12355 0.10896 65.039 59.805 0.00077871 1.1167e+O6 1.2802e+p6 69.39 2435.4 190.22 0.16021 0.12218 0.10774 65.039 59.805 0.00076996 1.1167e+O6 1.2802e+O6 68.12 2434.1 190.22 0.75728 0.1199 0.10568 65.039 59.805 0.00075526 1.1167e+O6 1.2802e+06 69.498 2435.5 190.22 0.16046 0.12233 0.10805 65.039 59.805 0.00077182 1.1167e+O6 1.2802e+O6 69.365 2435.4 190.22 0.16015 0.12209 0.10772 65.039 59.805 0.0007698 1.1t67e+O6 1.2802e+06 69.095 2435.1 190.22 0.15952 0.12162 0.10729 65.038 59.805 0.00076667 1.1167e+O6 1.2802e+O6 69.483 2435.5 190.22 0.16041 0.1223 0.10795 65.038 59.805 0.00077138 1.1167e+O6 1.2802e+O6 69.483 2435.5 190.22 0.16047 0.1223 0.10792 65.038 59.805 0.00077111 1.1167e+O6 1.2802e+O6 69.484 2435.5 190.22 0.16041 0.1223 0.10792 65.038 59.805 0.0007711 1.1167e+O6 1.2802e+O6 69.542 2435.5 190.22 0.16054 0.12241 0.10802 65.038 59.805 0.00077175 1.1167e+O6 1.2802e+O6 69.598 2435.6 190.22 0.16067 0.12251 0.1081 65.038 59.805 0.00077235 1.1167e+p6 1.2802e+O6 69.659 2435.7 190.22 0.16081 0.12261 0.1082 65.038 .59.805 0.000773 1.1167e+p6 1.2802e+O6 69.723 2435.7 190.22 0.16095 0.12272 0.1083 65.038 59.805 0.00077369 1.1167e+p6 1.2802e+O6 69.786 2435.8 190.22 0.1611 0.12284 0.1084 65.038 59.805 0.00077436 1.1167e+06 1.2802e+O6 69.847 2435.8 190.22 0.16124 0.12295 0.10849 65.038 59.805 0.00077504 1.1167e+O6 1.2802e+O6 69.907 2435.9 190.22 0.16138 0.12306 0.10859 65.038 59.805 0.00077569 1.1167e+O6 1.2802e+06 69.963 2436 190.22 0.16151 0.12316 0.10868 65.038 59.805 0.00077631 t.1167e+O6 1.2802e+O6 70.016 2436 190.22 0.16164 0.12325 0.10877 65.038 59.805 0.00077689 1.1167e+O6 1.2802e+06 70.064 2436.1 190.22 0.16175 0.12334 0.10884 65.038 59.805 0.00077743 1.1167e+O6 1.2802e+O6 70.109 2436.1 190.22 0.16186 0.12343 0.10892 65.038 59.805 0.00077792 1.1168e+O6 1.2802e+p6 70.149 2436.1 190.22 0.76195 0.1235 0.10898 65.038 59.805 0.00077835 1.1168e+O6 1.2802e+06 70.185 2436.2 190.22 0.16204 0.12357 0.10904 65.038 59.805 0.00077875 1.1168e+O6 1.2802e+O6 70.193 2436.2 190.22 0.16211 0.12363 0.10909 65.038 59.805 0.00077884 1.1168e+O6 1.2802e+O6 70.244 2436.2 190.22 0.16213 0.12364 0.10911 65.038 59.805 0.00077941 1.1168e+O6 1.2802e+O6 70.25 2436.2 190.22 0.16223 0.12372 0,10918 65.038 59.805 0.00077947 1.1168e+O6 1.2802e+O6 70.288 2436.3 190.22 0.16225 0.12373 0.10919 65.038 59.805 0.00077988 1.1168e+O6 1.2802e+O6 70.292 2436.3 190.22 0.16227 0.12375 0.1092 65.038 59.805 0.00077992 1.1168e+06 1.2802e+O6 67.072 2433.1 190.22 0.15486 0.11807 0.10422 65.038 59.805 0.00074475 1.1168e+O6 1.2802e+O6 70.379 2436.4 190.22 0.16249 0.12386 0.10941 65.038 59.805 0.00078123 1.1168e+06 1.2802e+O6 70.478 2436.5 190.22 0.16272 0.12403 0.10947 65.038 59.805 0.00078132 1.1168e+O6 1.2802e+O6 67.015 2433 190.22 0.15473 0.1179 0.10404 65.038 59.805 0.0007437 1.1168e+O6 1.2802e+O6 70.38 2436.4 190.22 0.16249 0.12382 0.10938 65.038 59.805 0.00078098 1.1168e+O6 1.2802e+O6 70.546 2436.5 190.22 0.16288 0.12412 0.10955 65.038 59.805 0.00078214 1.1168e+O6 1.2802e+O6 66.916 2432.9 190.22 0.1545 0.1177 0.10386 65.038 59.805 0.00074236 1.1168e+O6 1.2802e+06 70.438 2436.4 190.22 0.16262 0.12389 0.10945 65.038 59.805 0.00078136 1.1168e+06 1.2802e+O6 66.788 2432.8 190.22 0.1542 0.11744 0.10363 65.038 59.805 0.00074072 1.1168e+O6 1.2802e+06 70.291 2436.3 190.22 0.76228 0.1236 0.10919 65.038 59.805 0.0007795 1.1168e+O6 1.2802e+06 66.67 2432.7 190.22 0.15392 0.11722 0.70342 65.038 59.805 0.00073931 1.1168e+O6 1.2802e+06 ~ 70.139 2436.1 190.22 0.16193 0.12332 0.70895 65.038 59.805 o.ooonnz 1.1168e+O6 1.2802e+06 66.571 2432.6 790.22 0.15369 0.11704 0.10325 65.038 59.805 0.00073812 1.1168e+O6 1.2802e+O6 69.986 2436 190.22 0.16157 0.12304 0.1087 65.038 59.805 0.00077591 1.1168e+O6 1.2803e+O6 66.489 2432.5 790.22 0.15349 0.11689 0.10312 65.038 59.805 0.00073711 1.1168e+O6 1.2803e+O6 69.831 2435.8 190.22 0.1612 0.12276 0.10846 65.038 59.805 - 0.0007741 1.1168e+O6 1.2803e+O6 66.42 2432.4 190.22 0.15333 0.11676 0.103 65.038 59.805 0.00073626 1.1168e+O6 1.2803e+O6 69.677 2435.7 190.22 0.16084 0.12248 0.10821 65.038 59.805 0.00077229 1.1168e+O6 1.2803e+O6 66.364 2432.4 190.22 0.15319 0.11665 0.10291 65.038 59.805 0.00073554 1.1168e+06 1.2803e+O6 69.522 2435.5 190.22 0.16048 0.1222 0.10796 65.038 59.805 0.00077049 1.1168e+06 1.2803e+O6 66.318 2432.3 190.22 0.15308 0.11656 0.10283 65.038 59.805 0.00073495 1.1168e+06 1.2803e+O6 69.368 2435.4 190.22 0.16012 0.12192 0.10772 65.038 59.805 0.00076869 1.1168e+06 1.2803e+O6 66.282 2432.3 190.22 0.153 0.11649 0.10277 65.038 59.805 0.00073448 1.1168e+O6 1.2803e+O6 69.215 2435.2 190.22 0.15976 0.12165 0.10747 65.038 59.805 0.00076691 1.1168e+06 1.2803e+O6 66.259 2432.3 190.22 0.15294 0.11645 0.10273 65.038 59.805 0.00073415 Calculated Values at End of Treatment Sterling Slurry Volume Injected 1.2803e+O6 (bbl) Liquid Volume Injected 1.2101e+O6 (bbl) Fluid Loss Volume 1.2783e+O6 (bbl) Frec Fluid Efficiency 0.00076691 Net Frac Pressure 69.215 (psi) Length (one wing) 190.22 (ft) Upper Frac Height 65.038 (ft) Lower Frac Height 59.805 (ft) Upper Frac Height (ND) 3258 (ft) Lower Frac Height (ND) 3382.9 (ft) Total Frac Height ~ 124.84 (ft) Max. Frac Width at Perfs 0.15976 (in.) Avg. Hydraulic Frac Width 0.10747 (in.) FRACTURE WELLBORE HYDRAULICS SOLUTION Time Delta P Perfs Delta P Near Welibore Delta P Near Welibore Total BHFP (min) (Ps9 (Psi) (p59 (Psi) BHTP Well (psi) 1 0.0279 0 0.0279 2463.3 2463.3 15869 0.03924 0 0.03924 2435.3 2435.3 31358 0.03924 0 0.03924 2435.3 2435.4 46852 0.03924 0 0.03924 2437 2437 62099 0.03924 0 0.03924 2437.3 2437.3 77387 0.03924 0 0.03924 2437.4 2437.5 MFrac - NCIU B-1 Multiwell - 8/25/2008 -s- Terre Delta P PerFS ~ P Near Welibore Delta P Near WeUbore Total BHTP WeU 93328 0.0048437 0 0.0048437 2435.3 2435.3 1.0971e+OS 0.0048437 0 0.0048437 2433.7 2433.7 1.2567e+05 0.0048458 0 0.0048458 2433.4 2433.4 1.408e+05 0.0048452 0 0.0048452 2434 2434 1.5608a+05 0.0048449 0 0.0048449 2434.4 2434.4 1.714e+05 0.0048447 0 0.0048447 2434.8 2434.8 1.S68e+O5 0.0048446 0 0.0048446 2435 2435 2.019e+05 0.0048445 0 0.0048445 2435.3 2435.3 2.1776e+05 0.0048444 0 0.0048444 2435.5 2435.5 2.3352e+OS 0.0048443 0 0.0048443 2435.7 2435.7 2.4931e+OS 0.0048443 0 0.0048443 2435.8 2435.8 2.6513e+OS 0.0048442 0 0.0048442 2435.9 2435.9 2.8077e+05 0.0048442 0 0.0048442 2436 2436 2.9635e+05 0.0048441 0 0.0048441 2436.1 2436.1 3.1237e+05 0.0048441 0 0.0048441 2436.2 2436.2 3.2872e+05 0.0048441 0 0.0048441 2436.3 2436.3 3.4511 a+OS 0.0048441 0 0.0048441 2436.4 2436.4 3.6147e+05 0.004844 0 0.004844 2436.4 2436.4 3.7784e+05 0.004844 0 0.004844 2436.5 2436.5 3.9423e+OS 0.004844 0 0.004844 2436.5 2436.5 4.1061 a+O5 0.004844 0 0.004844 2436.6 2436.6 4.27e+OS 0.004844 0 0.004844 2436.6 2436.6 4.4338e+O5 0.004844 0 0.004844 2436.7 2436.7 4.5976e+OS 0.004844 0 0.004844 2436.7 2436.7 4.7615e+OS 0.004844 0 0.004844 2436.7 2436.7 4.9253e+OS 0.0048439 0 0.0048439 2436.7 2436.7 5.0892e+OS 0.0048439 0 0.0048439 2436.8 2436.8 5.253e+O5 0.0048439 0 0.0048439 2436.8 2436.8 5.4168e+OS 0.0048439 0 0.0048439 2436.8 2436.8 5.5807e+OS 0.0048439 0 0.0048439 2436.8 2436.8 5.7445e+OS 0.0048439 0 0.0048439 2436.8 2436.8 5.9084e+05 0.0048439 0 0.0048439 2436.8 2436.8 6.0722e+OS 0.0048439 0 0.0048439 2436.8 2436.8 6.236e+OS 0.0048439 0 0.0048439 2436.9 2436.9 6.3999e+OS 0.0048439 0 0.0048439 2436.9 2436.9 6.5637e+OS 0.0048439 0 0.0048439 2436.9 2436.9 6.7276e+05 0.0048439 0 0.0048439 2436.9 2436.9 6.8914e+p5 0.0048439 0 0.0048439 2436.9 2436.9 7.0552e+OS 0.0048439 0 0.0048439 2436.9 2436.9 7.2191 a+OS 0.0048439 0 0.0048439 2436.9 2436.9 7.3829e+OS 0.0048439 0 0.0048439 2436.9 2436.9 7.5468e+O5 0.0048457 0 0.0048457 2436.9 2436.9 7.7106e+OS 0.0048456 0 0.0048456 2436.9 2436.9 7.8744e+OS 0.0048456 0 0.0048456 2436.9 2436.9 8.0383e+05 0.0048455 0 0.0048455 2436.9 2436.9 8.2021 e+p5 0.0048455 0 0.0048455 2436.9 2436.9 8.366e+05 0.0048455 0 0.0048455 2436.9 2436.9 8.5298e+05 0.0048454 0 0.0048454 2436.9 2436.9 8.6936e+05 0.0048454 0 0.0048454 2436.9 2436.9 8.8575e+05 0.0048454 0 0.0048454 2436.9 2436.9 9.0213e+OS 0.0048453 0 0.0048453 2436.9 2436.9 9.1852e+OS 0.0048453 0 0.0048453 2436.9 2436.9 9.349e+OS 0.0048453 0 0.0048453 2436.9 2436.9 9.5128e+p5 0.0048452 0 0.0048452 2436.9 2436.9 9.6767e+05 0.0048452 0 0.0048452 2436.9 2436.9 9.8405e+05 0.0048452 0 0.0048452 2436.9 2436.9 1.0004e+O6 0.0048451 0 0.0048451 2436.9 2436.9 1.0168e+O6 0.0048451 0 0.0048451 2436.9 2436.9 1.0332e+O6 0.0048451 0 0.0048451 2436.9 2436.9 1.0496e+O6 0.0048451 0 0.0048451 2436.9 2436.9 1.066e+O6 0.0048451 0 0.0048451 2436.9 2436.9 1.0824e+O6 0.004845 0 0.004845 2436.9 2436.9 1.0983e+06 0.03924 0 0.03924 2435.2 2435.2 1.1138e+O6 0.03924 0 0.03924 2436.4 2436.4 1.1167e+p6 0.03924 0 0.03924 2436.8 2436.8 1.1167e+p6 0.03924 0 0.03924 2436.1 2436.2 1.1167e+O6 0.03924 0 0.03924 2435.4 2435.4 1.1167e+O6 0.03924 0 0.03924 2434.1 2434.2 1.1167e+O6 0.03924 0 0.03924 2435.5 2435.5 1.1167e+06 0.03924 0 0.03924 2435.4 2435.4 1.1167e+O6 0.03924 0 0.03924 2435.1 2435.1 1.1167e+O6 0.03924 0 0.03924 2435.5 2435.5 t.1167e+06 0.03924 0 0.03924 2435.5 2435.5 1.1167e+06 0.03924 0 0.03924 2435.5 2435.5 1.1167e+p6 0.03924 0 0.03924 2435.5 2435.6 1.1167e+O6 0.03924 0 0.03924 2435.6 2435.6 1.1167e+O6 0.03924 0 0.03924 2435.7 2435.7 1.1167e+O6 0.03924 0 0.03924 2435.7 2435.8 1.1167e+O6 0.03924 0 0.03924 2435.8 2435.8 1.1167e+O6 0.03924 0 0.03924 2435.8 2435.9 1.1167e+06 0.03924 0 0.03924 2435.9 2435.9 1.1167e+p6 0.03924 0 0.03924 2436 2436 1.1167e+06 0.03924 0 0.03924 2436 2436.1 1.1167e+p6 0.03924 0 0.03924 2436.1 2436.1 1.1167e+O6 0.03924 0 0.03924 2436.1 2436.1 1.1168e+O6 0.03924 0 0.03924 2436.1 2436.2 1.1168e+O6 0.03924 0 0.03924 2436.2 2436.2 1.1168e+06 0.03924 0 0.03924 2436.2 2436.2 1.1168e+O6 0.03924 0 0.03924 2436.2 2436.3 1.1168e+06 0.03924 0 0.03924 2436.2 2436.3 1.1168e+06 0.03924 0 0.03924 2436.3 2436.3 1.1168e+06 0.03924 0 0.03924 2436.3 2436.3 1.1168e+O6 0.03924 0 0.03924 2433.1 2433.1 1.1168e+O6 0.03924 0 0.03924 2436.4 2436.4 1.1168e+O6 0.03924 0 0.03924 2436.5 2436.5 1.1168e+O6 0.03924 0 0.03924 2433 2433.1 1.1168e+O6 0.03924 0 0.03924 2436.4 2436.4 1.1168e+06 0.03924 0 0.03824 2436.5 2436.6 1.1168e+O6 0.03924 0 0.03924 2432.9 2433 1.1168e+06 0.03924 0 0.03924 2436.4. 2436.5 1.1168eW6 0.03924 0 0.03924 2432.8 2432.8 1.1168e+O6 0.03924 0 0.03924 2436.3 2436.3 1.1168e+O6 0.03924 0 0.03924 2432.7 2432.7 1.1168e+O6 0.03924 0 0.03924 2436.7 2436.2 MFrac - NCIU B-1 Multiwell - 8/25/2008 -s- Time Delta P Pens Delta P Near Wellbore Della P Near Wellbore Total BHTP Well (min) (psi) (psi) (psi) ~ (psi) 1.1168e+06 0.03924 0 0.03924 2432.6 2432.6 1.1168eW6 0.03924 0 0.03924 2436 2436 1.1168e+O6 0.03924 0 0.03924 2432.5 2432.5 1.1168e+06 0.03924 0 0.03924 2435.8 2435.9 1.1168eW6 0.03924 0 0.03924 2432.4 2432.5 1.1168e+O6 0.03924 0 0.03924 2435.7 2435.7 1.1168e+O6 0.03924 0 0.03924 2432.4 2432.4 1.1168e+06 0.03924 0 0.03924 2435.5 2435.6 1.1168e+O6 0.03924 0 0.03924 2432.3 2432.4 1.1168e+O6 0.03924 0 0.03924 2435.4 2435.4 1.1168e+O6 0.03924 0 0.03924 2432.3 2432.3 1.1168e+O6 0.03924 0 0.03924 2435.2 2435.3 1.1168e+O6 0.03924 0 0.03924 2432.3 2432.3 PROPPANT TRANSPORT SOLUTION Distance Pay W idth Inlet Conc. EOJ Conc. Total Height Susp. Height Bank Height Cbsure Time Prop Height Pay Cond. Prop Width Cond Area (ft) (in.) (IbMgal) (Ibmlgal) (ft) (ft) (ft) (min) (ft) (md-ft) (in.) (IbnJft"2) STAGE 4 190.22 0 7.4 7.4 0 0 0 1.4856 0 0 0 0 0 0.13241 7.4 7.4 124.84 124.84 121.26 1.4856 122.69 395.56 0.07656 0.68604 Fluid injected before time = 1116739.38 (min)is lass due to leakoN 8 spurt The volume of fluid to account for this bss is 7.99697e+04 (bbl) Proppant Design Summary Sterling Frac Length -Created 190.22 (R) Fret Length -Propped 0 (ft) Fret Heght-Avg. 61.346 (ft) Propped Height (Pay Zone) -Avg. 61.346 (ft) Max Width at Perts - EOJ 0.15294 (in.) Propped Width (Well)-Avg. 0.07656 (in.) Propped Width (Pay Zone)-Avg. 0.03828 (in.) Conc./Area (Fret) -Avg. at EOJ 0 (IbrNR"2) Conc./Area (Pay Zone) -Avg. at Closure 0.34302 (IbMR^2) Frac Conductivity (Pay Zone) -Avg. at Cbsure 0 (md-ft) Dimensionless Frac Conductivity (Pay Zone) 0 Avg. Fracture Permeability 0 (md) Propped Fracture Ratio (EOJ) 0 Cosure Time 41.183 (min) Proppant Displacement & Location Sch # Screen-out Distance From (ft) Distance to (ft) Screervout From (ft) Screenout to (ft) 4 No 0 190.22 For a banking fluid, the Screen-out distance only represents the propped pack volume (distance). FLUID LEAKOFF OUTPUT Time Inj. Rate Leakoft Rate K' Inlet Apparent V'~scosiry Wall Shear Rafe (min) (bpm) (bpm) n' Inky (Ibf-s"n'Ift^2) (cp) (1/s) Reynolds Number 1 2.4 0 1 2.18e-OS 1.0438 373.79 184.15 15869 2.4 2.3996 1 2.18e-OS 1.0438 76.581 114.1 31358 2.4 2.3786 1 2.18e-OS 1.0438 67.578 113.72 46852 2.4 2.3989 1 2.18e-05 1.0438 61.366 113.58 62099 2.4 2.4 1 2.18e-OS 1.0438 59.437 113.52 77387 2.4 2.4 1 2.18e-OS 1.0438 58.339 113.49 93328 1 0.99962 1 2.18x05 1.0438 46.169 37.03 1.0971e+OS 1 0.99999 1 2.18e-05 1.0438 43.687 34.885 1.2567e+OS 1 1 1 2.18e-05 1.0438 41.705 34.033 1.408e+OS 1 1 1 2.18e-05 1.0438 37.441 33.919 1.5608e+OS 1 0.99918 1 2.18e-OS 1.0438 34.679 33.842 1.714e+OS 1 0.99949 1 2.18e-05 1.0438 32.757 33.787 1.868e+OS 1 1 1 2.18e-OS 1.0438 31.344 33.746 2.019e+05 1 0.99874 1 2.18e-OS 1.0438 30.274 33.714 2.1776e+O5 1 1 1 2.18e-OS 1.0438 29.374 33.686 2.3352e+O5 1 0.99999 1 2.18e-OS 1.0438 28.66 33.664 2.4931 a+O5 1 1 1 2.18e-OS 1.0438 28.07 33.646 2.6513e+05 1 1 1 2.18e-OS 1.0438 27.571 33.631 2.8077e+OS 1 1 1 2.18e-O5 1.0438 27.162 33.618 2.9635e+OS 1 0.9994 1 2.18e-05 1.0438 26.811 33.607 3.1237e+OS 1 0.99931 1 2.18e-OS 1.0438 26.498 33.597 3.2872e+p5 1 1 1 2.18e-05 1.0438 26.22 33.589 3.4511eW5 1 0.99999 1 2.18e-05 1.0438 25.976 33.581 3.6147e+p5 1 0.9998 1 2.18e-05 1.0438 25.763 33.575 3.7784e+OS 1 0.99938 1 2.18e-OS 1.0438 25.575 33.569 3.9423e+OS 1 1 1 2.18e-05 1.0438 25.408 33.565 4.1061e+OS 1 0.99997 1 2.18e-OS 1.0438 25.26 33.56 4.27e+OS 1 0.99981 1 2.18e-OS 1.0438 25.127 33.556 4.4338e+OS 1 0.99984 1 2.18e-05 1.0438 25.009 33.553 4.5976e+OS 1 0.99997 1 2.18eA5 1.0438 24.902 33.549 4.7615e+05 1 0.99998 1 2.18e-05 1.0438 24.805 33.547 4.9253e+05 1 1 1 2.18e-OS 1.0438 24.717 33.544 5.0892e+OS 1 0.99999 1 2.18e-OS 1.0438 24.638 33.542 5.253e+OS 1 1 1 2.18e-OS 1.0438 24.566 33.54 5.4168e+O5 1 1 1 2.18e-05 1.0438 24.501 33.537 5.5807e+O5 1 0.99993 1 2.18x05 1.0438 24.44 33.536 5.7445e+OS 1 0.99998 1 2.18x05 1.0438 24.386 33.534 5.9084e+OS 1 0.99984 1 2.18x05 1.0438 24.336 33.532 6.0722e+OS 1 0.99969 1 2.18x05 1.0438 24.289 33.531 6.236e+05 1 1 1 2.18x05 1.0438 24.247 33.53 6.3999e+OS 1 0.99998 1 2.18x05 1.0438. 24.208 33.528 6.5637e+p5 1 0.9997 1 2.18x05 1.0438 24.171 33.527 6.7276e+05 1 0.99988 1 2.18x05 1.0438 24.138 33.526 6.8914e+OS 1 0.99973 1 2.18x05 1.0438 24.107 33.525 MFrac - NCIU B-1 Multiwell - 8/25/2008 -7- Time (min) Inj. Rate (bpm) LeakotY Rat (bpm) n' Inlet IC Inlel (Ibf-s"n'Ift"2) Apparent (cp) Wall Shear Rate (1/s) Reynolds Number 7.0552e+05 1 0.99972 1 2.18e-OS 1.0438 24.079 33.525 7.2191e+OS 1 0.99999 1 2.18e-OS 1.0438 24.052 33.524 7.3829e+OS 1 0.99999 1 2.18e-OS 1.0438 24.028 33.523 7.5468e+O5 1 0.99999 1 2.18e-OS 1.0438 24.005 33.526 7.7106e+O5 1 0.99995 1 2.18e-OS 1.0438 23.984 33.525 7.8744e+05 1 0.99987 1 2.18e-OS 1.0438 23.964 33.524 8.0383e+05 1 0.99985 1 2.18e-05 1.0438 23.946 33.524 8.2021e+OS 1 0.99998 1 2.18e-05 1.0438 23.929 33.523 8.366e+O5 1 0.99999 1 2.18e-05 1.0438 23.914 33.523 8.5298e+05 1 0.99998 1 2.18e-OS 1.0438 23.899 33.523 8.6936e+05 1 0.99998 1 2.18e-05 1.0438 23.885 33.522 8.8575e+OS 1 0.99978 1 2.18e-O5 1.0438 23.873 33.522 9.0213eW5 1 0.8999 1 2.18e-OS 1.0438 23.861 33.522 9.1852e+OS 1 0.99998 1 2.18e-O5 1.0438 23.85 33.522 9.349e+05 1 0.99985 1 2.18e-O5 1.0438 23.84 33.521 9.5128e*05 1 0.99994 1 2.i8e-O5 1.0438 23.831 33.521 9.6767e+OS 1 0.99984 1 2.18e-05 1.0438 23.822 33.521 9.8405e+OS 1 0.99999 1 2.18e-OS 1.0438 23.814 33.521 1.0004e+O6 1 0.99996 1 2.i8e-O5 1.0438 23.806 33.521 1.0168e+O6 1 0.99984 1 2.i8e-O5 1.0438 23.799 33.521 1.0332e+O6 1 0.99994 1 2.18e-O5 1.0438 23.793 33.52 1.0496e+O6 1 0.99978 1 2.18e-05 1.0438 23.787 33.52 1.O66e+O6 1 0.99999 1 2.18e-05 1.0438 23.781 33.52 1.0824e+O6 1 0.99997 1 2.18e-05 1.0438 23.776 33.52 1.0983e+O6 2.4 2.4 1 2.18e-OS 1.0438 78.007 113.86 1.1138e+O6 2.4 2.4 1 2.18e-OS 1.0438 65.741 113.61 1.1167e+O6 2.4 1.3991 1 2.18e-OS 1.0438 64.213 113.59 1.1167e+O6 2.4 2.963 1 2.18e-05 1.0438 65.442 113.59 1.1167e+O6 2.4 3.0978 1 2.18e-05 1.0438 66.934 113.59 1.1167eW6 2.4 7.4589 1 2.18e-05 1.0438 69.561 113.59 1.1167e+O6 2.4 0.67312 1 2.18e-05 1.0438 66.543 113.59 1.1167e+p6 2.4 2.5599 1 2.18e-05 1.0438 66.952 113.59 1.1167e+O6 2.4 2.6481 1 2.18e-OS 1.0438 67.495 113.59 1.1167e+O6 2.4 2.0215 1 2.18e-05 1.0438 66.668 113.59 1.1167e+06 2.4 2.4201 1 2.18e-OS 1.0438 66.71 113.59 1.1167e+O6 2.4 2.3986 1 2.18e-05 1.0438 66.708 113.59 1.1167e+O6 2.4 2.3463 1 2.18e-OS 1.0438 66.591 113.59 1.1167e+O6 2.4 2.3503 1 2.18e-O5 1.0438 66.483 113.59 1.1167e+O6 2.4 2.3459 1 2.18e-05 1.0438 66.366 113.59 1.1167e+O6 2.4 2.3435 1 2.18e-05 1.0438 66.245 113.59 1.1167e+O6 2.4 2.3439 1 2.18e-05 1.0438 66.124 113.59 1.1167e+O6 2.4 2.344 1 2.18e-OS 1.0438 66.004 113.59 1.1167e+O6 2.4 2.3459 1 2.18e-05 1.0438 65.888 113.59 1.1167e+O6 2.4 2.3486 1 2.18e-OS 1.0438 65.779 113.59 1.1167e+O6 2.4 2.3518 1 2.18e-OS 1.0438 65.676 113.59 1.1167eW6 2.4 2.3554 1 2.18e-OS 1.0438 65.581 113.59 1.1167e+O6 2.4 2.3592 1 2.18e-05 1.0438 65.495 113.59 1.7168e+O6 2.4 2.363 1 2.18e-05 1.0438 65.416 113.59 1.1168e+06 2.4 2.3668 1 2.18eA5 1.0438 65.346 113.59 1.1168e+O6 2.4 2.3908 1 2.18e-05 1.0438 65.283 113.59 1.1168e+06 2.4 2.3523 1 2.18e-05 1.0438 65.266 113.59 1.1168e+06 2.4 2.3936 1 2.18e-05 1.0438 65.183 113.59 1.1168eW6 2.4 2.3653 1 2.18e-05 1.0438 65.17 113.59 1.1168e+O6 2.4 2.3948 1 2.18e-05 1.0438 65.155 113.59 1.1168e+O6 2.4 5.2122 1 2.18e-OS 1.0438 71.531 113.59 1.1168e+O6 2.4 0 1 2.18e-05 1.0438 64.907 113.59 1.1168e+O6 2.4 2.3912 1 2.18e-OS 1.0438 64.837 113.59 1.1168e+O6 2.4 5.4084 1 2.i8e-O5 1.0438 71.782 113.59 1.1168e+06 2.4 0 1 2.i8e-05 1.0438 64.937 113.59 1.1168e+O6 2.4 2.3052 1 2.18e-05 1.0438 64.736 113.59 1.1168e+O6 2.4 5.5819 1 2.18e-05 1.0438 72.03 113.59 1.1168e+O6 2.4 0 1 2.18e-05 1.0438 64.862 113.59 1.1168e+O6 2.4 5.6506 1 2.18e-05 1.0438 72.352 113.59 1.1168e+06 2.4 0 1 2.18e-05 1.0438 65.163 113.59 1.1168e+06 2.4 5.6149 1 2.18e-05 1.0438 72.644 113.59 1.1168e+06 2.4 0 1 2.18e-OS 1.0438 65.455 113.59 1.1168e+O6 2.4 5.5676 1 2.18e-05 1.0438 72.872 113.59 1.1168e+06 2.4 0 1 2.18e-05 1.0438 65.752 113.59 1.1168e+O6 2.4 5.5041 1 2.18e-OS 1.0438 73.065 113.59 1.1168e+O6 2.4 0 1 2.18e-05 1.0438 66.053 113.59 1.1168e+O6 2.4 5.4275 1 2.18e-OS 1.0438 73.228 113.59 1.1168e+O6 2.4 0 1 2.18e-05 1.0438 66.354 113.59 1.1168e+O6 2.4 5.34 1 2.18e-OS 1.0438 73.363 113.59 1.1168e+O6 2.4 0 1 2.18e-O5 1.0438 66.657 113.59 1.1168e+06 2.4 5.2431 1 2.18e-OS 1.0438 73.474 113.59 1.1168e+O6 2.4 0 1 2.18e-05 1.0438 66.961 113.59 1.1168e+O6 2.4 5.1379 1 2.i8e-O5 1.0438 73.563 113.59 1.1168e+O6 2.4 0 1 2.18e-OS 1.0438 67.265 113.59 1.1168e+O6 2.4 6.0838 1 2.18e-OS 1.0438 73.622 113.59 MFrac - NCIU B-1 Multiwell - 8/25/2008 9 NCIU A-12 Injection Rate and Pressure 2500 2000 ~v c. d L L 1500 a elf 0 3 m 1000 c d 500 0 Attachment 8 . ~ ~ ^ ^ o o~ 0 ~i __ __.. _ ^ ^ O 0 ° O ~~ ~ ~ ^~ ^ ~ ~ _ ^ ~ ^ • ~ li -_ ^ ^ o~ 8~ 0 0~ ~ ~ o ° o O o~ O~ o~ 0 0 8 0 ,O~oB° 1D 8° g oo ~° O o000 ~O c~~ o~ ~ o~ 080 ° 0 0~ O ~ 0~ ~ ~°0 0 O ° ~ O O 6c B° ~ ~ p4~ 080° ~ ~8 0 °~° o o, ~ , .~ ° ° ~' ~ ~p~° o is ~ i 00 O O 0 Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08 Jul-08 o j 0 0, 0 0 0 ° O °g O O ° ° o o~ c ° O ° ~ ° o °oo o Apo O 0 moo $ ~ °QgO o~°g~ ° ° O ~ ~° I~ A bb ~ o0 00 ~ °~~ o ~9° a°8oO 0 8~ ° °o~° ~o $ b >~ a9 $ ~ gO8 g ~go°oo ~ooc~aoo~c o °~o O c°~ 4g O° 4~$ O° 00 °O O e R~ ~ °i • • ~3 • ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION North Cook Inlet Unit B-OlA Disposal Injection August 26, 2008 AT 9:00 am NAME AFFILIATION PHONE # TESTIFY (Yes or No) ~-. ~~~~ ~~~~~+~ Cr~G~ 2G3 ~s~ es rLWA 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_02814057 /`1 SEE BOTTQM FOR INVOICE ADDRESS F R AOGCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. Jul 16 2008 ° M Anchorage, AK 99501 907-793-1238 PHONE - PcN OATES ADVERTISEMENT REQUIRED: July 20, 2008 o Peninsula Clarion P.O. Box 3009 Kenai AK 99611 ~ 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 2 PAGES TOTAL OF ALL PAGES$ REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN z A~ 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LIQ 1 08 02140100 73451 2 3 4 REQUISITIONED B ~ DIVISION APPROVAL: • Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservation Commission Re: Request for Disposal Injection Order for North Cook Inlet Unit, Well B-OIA, located on the Tyonek Platform, Cook Inlet, Alaska ConocoPhillips Alaska Inc. (CPAI), by letter received on July 14, 2008 has applied for a disposal injection order in accordance with 20 AAC 25.252. An order would authorize disposal of Class II drilling and production wastes into the Sterling formation using existing well B-OIA. The proposed disposal injection is located within Section 6, T11N, R9W, Seward Meridian. The receiving zone for this well is proposed at an approximate depth range of 3195 to 3248 feet true vertical depth subsea. CPAI's application may be reviewed at the offices of the Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska, or a copy may be obtained by phoning the Commission at (907) 793-1221. The Commission has tentatively scheduled a public hearing on this application for August 26, 2008 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on August 6, 2008. 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 public hearing, please ca11793-1221 after August 13, 2008. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on August 21, 2008, except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the August 26, 2008, hearing. If you are a person with a di order to comment or to attend Special Assistant Jody Colombie need special accommodations in please contact the Commission's Jr. C • PUBLISHER'S AFFIDAVIT UNITED STATES OF AMERICA, STATE OF ALASKA ss: Denise Reece being first duly sworn, on oath deposes and says: That I am and was at all times here in this affidavit mentions, Supervisor of Legals of the Peninsula Clarion, a news- paper of general circulation and published at Kenai, Alaska, that the Public Hearing AO-02914001 a printed copy of which is hereto annexed was published in said paper one each and every day for one successive and consecutive da~_in the issues on the following dates: July 20, 2008 1.C~L1 e ~~LLs SUBSCRIBED AND SWORN to me before 1st day of August 2008 NOTARY PUBLIC in favor for the State of Alaska. My Commission expires 26-Aug-08 ~`°~~s a~ss~~, ~~' ~aTARy ~~((~~ ~'tJB1-~C' ' Notice of Public Hearing ' Stets of Aleslu I Alaska Oil and Gas .Conservation Commission 1 Re: CookeniefouDis Wsaf6 0lAi, located on tthe h ' Tyonek Platform, Cook mist, Alaska ConocoPhlliips Alaska Inc. (CPAI), by letter' received on July 14, 2008 has applied for a disposal I injection order in accordance with 20 AAC 25.252..An onier-would authonze`disposal of Class II drilling and I production wastes into the Sterling formation using existing well B-01A.' The proposed disposal injection is I 'located within Section 6, T11 N, R9W, Seward Meridian. ,The receiving zone for this well. is proposed at an approximate depth ranfe of 3195 to 3248 feet true 'vertical depth subsea. CPAI's application may be' reviewed at the offices of the Commission, 333 West' ' 7th Avenue, Suite 100, Anchorege,' Alaska, or a copy I may be obtained by phoning the Commission at (907) 793-1221. f The Commission has tentatively scheduled a1 public hearing on this application for August 28, 2008,1. at 9:00 am at the offices of the Alaska Oil and Gas 'Conservation Commission at 383 West 7th .Avenue, Suite t00, Anchorage, .Alaska 99501,. A person may request that the tentatively scheduled hearing be held. by filing a written request with the Commission no later' than 4:30 pm on AugusKB, 2008. 1f a request fora hearing is not timely filed, fhe) 'Commission may Consider She issuance of an order ' without a hearing. To learn if the Commission will hold the public hearing, Please call 793-1221 after August I 13, 2008. In addition, a person may submit a written l I protest or written comments regarding this application ' and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100,' Anchorage, Alaska 99501, Protests and comments ' must b® received no Eater than 4:30 pm on August2l' 2008, except that if the Commission decides to hold a ' public hearing, protests or comments must be received no dater than the oonciusion of the AugusY26, 2008,' hearing. Jf you are a person wkh a disability who may ' need spedal accommodations in order to comment or 'to attend the. public hearing, please contact the Commission§ Special Assistant Jody Cokxntre at 793-1221, I Daniel T. Seamount, Jr. Chair ' `PUBU~H:~ Oi2~8 ~ ~ ~ ~ 204 ~ 02-902 (Rev. 3/94) Publisher/~nal Copies: Department Fiscal, Departme~ceiving AO.FRM STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ 0_02814057 ` AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF 1 / ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS' F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue. Suite 100 Anchnrage_ AK 9951 PHONE PCN M 907-793-1238 - DATES ADVERTISEMENT REQUIRED: July 20, 2008 T PenlnSUla C1aPlOn O PO Box 3009 Kenai AK 99611 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ~ ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United states of America R EM i N D ER State of 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 2007, and thereafter for consecutive days, the last publication appearing on the day of , 2007, 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 2007, Notary public for state of My commission expires 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 /~ 0_02814056 I"~ SEE BOTTOM FOR INVOICE ADDRESS F R AOGCC 333 W 7th Ave, Ste 100 AGENCY CONTACT Jod Colombie DATE OF A.O. Jul 16 2008 ° M Anchorage, AK 99501 907-793-1238 PHONE - PCN DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News PO Box 149001 Anchora e AK 99514 g ~ July 17, 2008 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 z A>~ 02910 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LID ~ 08 02140100 73451 2 REQUISITIONED BY: DIVISION APPROVAL: 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM r~ L Notice of Public Hearing State of Alaska Alaska Oil and Gas Conservation Commission Re: Request for Disposal Injection Order for North Cook Inlet Unit, Well B-OlA, located on the Tyonek Platform, Cook Inlet, Alaska ConocoPhillips Alaska Inc. (CPAI), by letter received on July 14, 2008 has applied for a disposal injection order in accordance with 20 AAC 25.252. An order would authorize disposal of Class II drilling and production wastes into the Sterling formation using existing well B-OIA. The proposed disposal injection is located within Section 6, T11N, R9W, Seward Meridian. The receiving zone for this well is proposed at an approximate depth range of 3195 to 3248 feet true vertical depth subsea. CPAI's application may be reviewed at the offices of the Commission, 333 West 7th Avenue, Suite 100, Anchorage, Alaska, or a copy may be obtained by phoning the Commission at (907) 793-1221. The Commission has tentatively scheduled a public hearing on this application for August 26, 2008 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm on August 6, 2008. 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 public hearing, please call 793-1221 after August 13, 2008. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on August 21, 2008, except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the August 26, 2008, hearing. If you are a person with a di order to comment or to attend the Special Assistant Jody Colombie y need special accommodations in please contact the Commission's Jr. ~nchora a Dail News g Y ~/2a/2cx)s Affidavit of Publication 1001 Northway Drive, Anchorage, AK 99508 ,. ,- tcPR-ICE r-OTHER OTHER OTHER OTHER OTHER GRAND A3~ #, i-DATE .PO ACCOLiNT PEI~DAYn- CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 52405 ' b7J12/~2008 , `A4956-y STOF0330 ' - $209:~IG• ! ~.. da~~yfl~~' $209:16 $0.00 $0.00 $0.00 $0.00 $0.00 $209.16 STATE OF ALASKA THIRD JUDICIAL DISTRICT Christine Clark, being first duly sworn on oath deposes and says that she 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 during 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 Subscribed and sworn to me be ore this date: Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY . ~~~• ~` 4 ~'~T'!Rr ~~ ~'uB1.1G ., ._. J~~~ i~~ ~~,~~ Notice of Public Hearing State ofAlask~ Alaska Oil and Gas Conservation Commission Re: Request for Disposal Injection Order for North Cook Inlet llnit, Well B-01A, located on the { Tyonek Platform, Cook Inlet, Alaska CdnocoPhillips Alaska,Jnc. (CPAI), byietfer ' received'pn JUIy'14, 2Q08 hasapplied for a disposal injection order in accordance with 20 AAC 25.252. An order would aUthorrze disposal of Class n drilling and production wastes into the Sterling formation Lsing existing well B 01A. The proposed tlisposal injection is located within Section-6, T11N, R9W, Seward Meridian: The receiving zone for this well is proposed at an approximate depth range of 3195 to 3248 feet true vertical depth subsea. CPAI's application may be reviewed at the offices of the Corrfmission, s33 west 7th Avenue, suite 100, Anchorage, Alaska, or-a cgpyy may be obtained by phoning# a COmfTlisSiOli at (907) 793-1221. The Commission has tehtatWely scheduled;a public"hearing on this application for August 26, 2008 at 9:00: am at the offices of the Alaska oil and ' Gas Conservation Commission at 333 1Nest7th. Avenue, Suite 100, Anchorage, Alaska 9950E A persorrmay request that the tentatively'scpeduled hhearing be held by tiling a written request withh the Commission no later than 4;30 pm on August 6, 2008. Ilia 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 Yuill hold the public hearing, please call 793-1221 after AUgu8Y13, 2008. do addition, a person may submiCa written- protest o,r written comments regarding this . application andproposarto the Alaska Ril and Gas, COgSerVatiOn COmmiSSioh at 333 West'7th AVenUe, : Suite 1.00, Anchorage, Alaska 99$01. Protests and "~ comments must be received no later than 4:30 pm on August 21, 2008, except that if the CommiSSiOrr decides to hold a pUbhc hearin protests ,or commehts must be received no~ater then the conclusiohof the August 26; 2008, hfng. if you are a person with'a disability who may need special accommodations in order to comment or to attend the public hearing, please Contact the Commission's Special Assistant iotly Colorhbie at 793-1221... Daniel T: Seamount,.fr, Chain.: i SAO Q2&74056 PubliShed:'JUIy 17, 200$ i • ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED /~ 0_02814056 ` ORDER AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF 1 / ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BOTTOM FOR INVOICE ADDRESS F A~GCC AGENCY CONTACT DATE OF A.O. R 333 West 7th Avenue. Suite 100 ° Anch~raue. AK 99501 PHONE PCN M 907-793-1238 - DATES ADVERTISEMENT REQUIRED: o Anchorage Daily News July 17 2008 , PO Box 149001 An h r AK 99514 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN c o a e g ~ ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account # STOF0330 AFFIDAVIT OF PUBLICATION United states Df America R EM i N D ER State of 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 2008, and thereafter for consecutive days, the last publication appearing on the day of , 2008, 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 2008, Notary public for state of My commission expires Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS 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 John Levorsen Mark Wedman Baker Oil Tools 200 North 3rd Street, #1202 Halliburton 4730 Business Park Blvd., #44 Boise, ID 83702 6900 Arctic Blvd. Anchorage, AK 99503 Anchorage, AK 99502 Schlumberger Ciri Ivan Gillian Drilling and Measurements Land Department 9649 Musket Bell Cr.#5 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99507 Anchorage, AK 99503 Anchorage, AK 99503 Jill Schneider Gordon Severson Jack Hakkila US Geological Survey 3201 Westmar Cr. PO Box 190083 4200 University Dr. Anchorage, AK 99508-4336 Anchorage, AK 99519 Anchorage, AK 99508 Darwin Waldsmith James Gibbs Kenai National Wildlife Refuge PO Box 39309 PO Box 1597 Refuge Manager Ninilchick, AK 99639 Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-2139 Penny Vadla Richard Wagner Cliff Burglin 399 West Riverview Avenue PO Box 60868 PO Box 70131 Soldotna, AK 99669-7714 Fairbanks, AK 99706 Fairbanks, AK 99707 Bernie Karl North Slope Borough Williams Thomas K&K Recycling Inc. PO Box 69 Arctic Slope Regional Corporation PO Box 58055 Barrow, AK 99723 Land Department Fairbanks, AK 99711 PO Box 129 Barrow, AK 99723 i'/~ ~ /~ ~ Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, July 16, 2008 12:04 PM Subject: Public Notice DIO NCIU B-01A Attachments: Public Notice DIO NCIU B-01A.pdf BCC:Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert 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, C (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); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA); 'Dale Hoffman'; Fridiric Grenier; Joseph Longo; 'Lamont Frazer'; 'Mary Aschoff; Maurizio Grandi; 'Scott Nash'; Tom Gennings; 'Willem Vollenbrock'; 'Aleutians East Borough'; 'Anna Raff; Arion, Teri A (DNR); 'Arthur Copoulos'; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol Smyth'; 'Cary Carrigan'; caunderwood@marathonoil.com; 'Charles O'Donnell'; 'Chris Gay'; 'Christian Gou-Leonhardt'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidji '; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; Gould, Greg M (DEC); 'Gregg Nady'; 'gregory micallef ; 'gspfoff ; 'Hank Alford'; 'Harry Engel'; 'j ah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn'; 'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marguerite kremer'; 'marty'r 'Matt Rader'; 'Meghan Powell'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mk1n7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay'; 'Wayne Rancier' Attachments:Public Notice DIO NCIU B-OlA.pdf; Jody Jaylene Colombie Special Assistant to the Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 793-1221 Direct Line (907) 276-7542 Fax 7/16/2008 ~~ ~ `~ ' ~`" "-, ~... John C. Braden, PE ~ Cook Inlet Asset ~ ~ '°~~ ~ Telephone:(907) 263-4536 ConocoPh~ I I ~ p `fit ~~ ~ Facsimile: (907) 265-1441 ~~~~ Email: jbraden@ppco.com ~~S~;w 700 G. Street ¢ ~' ~' _ ~ ~``~"~`~g~""'~y~~~ P. O. Box 100360 - ~` Anchorage, Alaska 99510-360 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Dear Tom, ConocoPhillips Alaska Inc. submits application for B-01 a annular tubing strings to be used for Class II disposal into the zone that is currently perforated, which is the exempt aquifer below 2900' MD in A-12 cited in Aquifer Exemption Order #4. The confining zone is similar as seen in the attached cross-section and is approximately 100 feet. In Disposal Injection Order 17, fracture modeling demonstrated that injection will not initiate or propagate fractures through the confining zone at the approved injection rates and pressures. The disposal plan for the North Cook Inlet Unit is to (1) develop an alternative Class II well to minimize production interruptions and (2) create a Class I injection well for all other fluids in a depleted producing zone. The information required in 20 ACC 25.252 is addressed below. The italics print are the regulations, the regular font is the operators response. We look forward to meeting with you to discuss this further. Sincerely, John Braden • 20 AAC 25.252. Underground disposal of oil field wastes and underground storage of hydrocarbons (a) The underground disposal of oil field wastes and the underground storage of hydrocarbons are prohibited except as ordered by the commission under this section. In response to a letter of application for injection filed by an operator, the commission will issue an order authorizing the underground disposal of oil field wastes that the commission determines are suitable for disposal in a Class II well, as defined in 40 C.F.R. 144.6(b) as revised as of July 1, 1998, which is adopted by reference, or the underground storage of hydrocarbons. An order authorizing disposal or storage wells remains valid unless revoked by the commission. (b) The operator has the burden of demonstrating that the proposed disposal or storage operation will not allow the movement of oil field wastes or hydrocarbons into sources of freshwater. Disposal or storage wells must be cased and the casing cemented in a manner that will isolate the disposal or storage zone and protect oil, gas, and freshwater sources. (c) An application for underground disposal or storage must include (1) a plat showing the location of all proposed disposal and storage wells, abandoned or other unused wells, production wells, dry holes, and any other wells within one-quarter mile of each proposed disposal or storage well; Attachment 1 is a map of the North Cook Inlet Unit showing the location of all wells on the platform and highlighting all wells within %4 mile of the proposed injection zone. (2) a list of all operators and surface owners within aone-quarter mile radius of each proposed disposal or storage well; ConocoPhillips Alaska, Inc. is the only operator within one quarter mile radius of the proposed disposal well. (3) an affidavit showing that the operators and surface owners within aone-quarter mile radius have been provided a copy of the application for disposal or storage; There are no parties due notice of the proposed disposal well. (4) the name, description, depth, and thickness of the formation into which fluids are to be disposed or stored and appropriate geological data on the disposal or storage zone and confining zones, including lithologic descriptions and geologic names; The proposed disposal zone in within the Sterling Formation. The Sterling Formation is composed of coarse-grained clastic intervals with interspersed relatively thin carbonaceous mudstones. Lithologic units are correlative throughout the Unit. Logs through the disposal zone are on file. This aquifer has been approved for disposal in Aquifer Exemption Order #4. The approved zone in A-12 is 3260' MD to 3380'MD (- 3144 SS to -3264 SS). A well correlation is shown in the Attachment 2. • • (5) logs of the disposal or storage wells, if not already on frle, or other similar information; Well logs of the disposal well are on file with the AOGCC. Duplicates can be made available if necessary. (6) a description of the proposed method for demonstrating the mechanical integrity of the casing and tubing under 20 AAC 25.412 and for demonstrating that fluids will not move behind casing beyond the approved disposal or storage zone, and a description of (A) the casing of the disposal or storage wells, if the wells are existing; or The two 2-3/8" tubing strings are in the 13-3/8" x 20" annulus. The 20" conductor shoe is at 2579' MD; it is cemented to surface. The 13-3/8" casing shoe is at 3760' MD. The 13/3-8" casing is cemented to surface, encasing the 2-3/8" tubing in cement. The 13-3/8" casing and two 2-3/8" tubing strings are perforated from 3500' to 3540' MD (-3175SS to -3207SS). A wellbore schematic is shown in Attachment 3. The bond log indicates top of cement at 2590'MD; above the log is invalid because the 20" casing interferes with the log response. 20", 2600' Perfs 3500-3540' 13-3/8", 3760' Producing Interval 3850'-6767' 9-5/8", 10736' 5-I/2" tubing 9-5/8" casing (cemented below 3588') 13-3/8" casing (cemented) 20" Conductor (cemented) ' 2/3/8" tubing The disposal strings are two 2-3/8" tubing strings in the 13-3/8" by 20" annulus. The strings are perforated and communicate with the 9-5/8" x 13-3/8" annulus via those perforations. They were used for cuttings disposal in 1997 and 1998, injecting approximately 200,000 barrels. The 2-3/8" strings are not accessible for logging • • purposes because of the wellhead configuration. The proposed method of demonstrating mechanical integrity would be twofold. First, the 9-5/8" x 13-3/8" annulus and 2-3/8" tubing strings would be loaded with an immiscible fluid that is lighter than water, such as diesel. The approximate reservoir pressure is known from A-12 injection. Based on the known reservoir pressure of the disposal zone, the annulus and tubing in B-Ola will register a positive pressure. Since they are all in communication at the same depth (the proposed disposal zone), they should read the same surface pressure under static conditions. If there is a leak in one string, then the lighter immiscible fluid would swap for injected fluid of formation water and the surface pressure would read lower than strings without a leak. The depth of the leak could be determined because the fluid gradient is known, the depth where the three communicate is known and the pressure at that point is calculated from the highest surface pressure. Thus, a differential pressure from any of the three surface readings while they contain the same fluid, would indicate the disposal tubing is not competent and the depth of the leak can be calculated. Surface pressure would otherwise correlate to reservoir pressure. The primary method of determining integrity can also be monitored by a pump-in differential temperature log in the 5-1/2" tubing, looking for potential leaks and confirm isolation of fluids within the injection zone. The operator will confirm continued mechanical integrity by (1) monitoring injection pressure and rate, (2) monitoring the surface pressure at static conditions in the two strings and open annulus with a known fluid and (3) perform pump-in temperature logs to ensure injected fluids are not migrating above the approved disposal zone as correlated in Attachment 2. (7) a statement as to the type of oil field wastes to be disposed or hydrocarbons stored, their composition, their source, the estimated maximum amounts to be disposed or stored daily, and the compatibility offluids to be disposed or stored with the disposal or storage zone; The types of oil field wastes will be Class II fluids as defined in 40 CFR 146.5, which will include, but not limited to, drilling mud, drilling cuttings, reserve pit fluids, rig wash fluids, formation material, completion fluids, produced water, stimulation fluids which are intended as an integral part of production operations on the Tyonek Platform. The estimated maximum daily amount disposed into the zone would be 3000 BPD using a maximum surface pressure of 2500 psia based on findings for Disposal Injection Order 17. The operator will pursue a Class I permit to dispose all non-C1assII fluids in a depleted gas zone that has been abandoned. Well B-Ola has injected approximately 200,000 barrels of similar fluids into this injection zone without any adverse fluid or formation interactions. Similar injection has occurred in A-12 without any compatibility problems. Based on past experience, the injected fluids will be compatible with the reservoir fluid and formation of the disposal zone. (B) the proposed casing program, if the disposal or storage wells are new; • (8) the estimated average and maximum injection pressure; The estimated maximum injection pressure would be 2500 psia based on findings for Disposal Injection Order 17. (9) evidence to support a commission finding that the proposed disposal or storage operation will not initiate or propagate fractures through the confining zones that might enable the oil field wastes or stored hydrocarbons to enter freshwater strata; Disposal Injection Order 17 found that disposal or storage operations into the proposed zone will not propagate fractures through the confining zones. Fracture model results were submitted as part of Disposal Injection Order 17. (10) a standard laboratory water analysis, or the results of another method acceptable to the commission, to determine the quality of the water within the formation into which disposal or storage is proposed, A standard laboratory water analysis was submitted with the application for Aquifer Exemption Order #4 and for Disposal Injection Order 17. (11) a reference to any applicable freshwater exemption issued in accordance with 20 AAC 25.440: and (12) a report on the mechanical condition of each well that has penetrated the disposal or storage zone within aone-quarter mile radius of a disposal or storage well. Wells penetrating the disposal zone within'/4 mile radius are A-03, A-04, A-06, A-07, A- 09, A-12 and B-03. Each well is in good mechanical condition. Annulus pressures are monitored daily and have not shown any anomalies. Attachment 4 is a table of the planar distance from B-01 a to other wells at North Cook Inlet Unit. (d) The mechanical integrity of a disposal or storage well must be demonstrated under 20 AAC 25.912 before disposal or storage operations are begun, after a well workover affecting mechanical integrity is conducted, and at least once every four years. To confirm continued mechanical integrity, the operator shall monitor the injection pressure and rate and the pressure in the casing-tubing annulus during actual disposal or storage operations. The monitored data must be reported monthly on the Monthly Injection Report (Form 10-406). (e) If an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing, tubing, or packer, the operator shall note the commission by the next working day and shall implement corrective action or increased surveillance as the commission requires to ensure protection of freshwater. (~ The commission will require additional mechanical integrity tests if the commission considers them prudent for conservation purposes or protection of freshwater. (g) Modifications of existing or pending disposal or storage operations will be approved by the commission, in its discretion, under 20 AAC 25.507, upon application containing sufficient detail to evaluate the proposed modification. No modification will be approved unless the applicant proves to the commission that the modification will not allow the movement of fluids into sources of freshwater. • • (h) If wells, including freshwater wells or other borings, are located within aone-quarter mile radius of the disposal or storage well, are a possible means for oil field wastes or hydrocarbons to move into sources of freshwater, and are under the control of (1) the operator, the operator shall ensure that the wells are properly repaired, plugged, or otherwise modified to prevent the movement of oil field wastes or hydrocarbons into sources of freshwater; or (2) a person other than the operator, the commission will not issue an order under (a) of this section to the operator until the operator presents evidence to the commission's satisfaction that the person who controls the wells has properly repaired, plugged, or otherwise modified the wells to prevent the movement of oil field wastes or hydrocarbons into sources of freshwater. (i) The commission will publish notice of the disposal or storage application and will provide opportunity for a hearing in accordance with 20 AAC 25.540. (j) If disposal or storage operations are not begun within 24 months after the approval date, the injection approval will expire unless an application for extension is approved by the commission. (k) The annular disposal of drilling wastes approved under 20 AAC 25.080 is an operation incidental to drilling a well and is not a disposal operation subject to this section. (Z) This section does not apply to underground disposal that is regulated under 40 C.F.R. 147.101 by the United States Environmental Protection Agency. • • G~ttacnment i iviap or Nortn ~ooK ~niet unit A-1 ~';l A-11 _ _ ~ ~~1 1oA 32 el«ga-A NCI A-10,~ ~~ ~ CI A-0~ _12 i320'radius =F~ ~~ 1 5 ~, ~, eluga-A ADL037831 ~, -,.; nl~r r. A-15 ADL017589 DL018741 ~- 12 NCI 88-01 A NCI ~~ ~/z Nci e-~~ SCAILE IN MILES 7 NCI 8-01 $1 1 Attachment 1 NCIU B-01A North Cook Inlet Unit Disposal Injection Application ~ i-oa r'-zooo oeo22ooico3 • • Nc~ ~-ola. ;~~~. ?67~, South NCI A-12 • NCI B-02 • ConocoPhillips Alaska R. Levinson NCI A-11 Nosh • • ~:~~..~ i ,~ Attachment 4 Planar Distance from NCIU wells to B-Ola in AEO #4 Exempt Aquifer • Well Planar Distance at To of Zone, ft Planar Distance at Bottom of Zone, ft Is AEO#4 zone within '/a mile? A-O1 1736 2286 A-02 1518 1932 A-03 1218 1622 Yes A-04 896 1021 Yes A-OS 1892 2455 A-06 635 806 Yes A-07 509 531 Yes A-08 2061 2816 A-09 1261 1511 Yes A-l0a 2032 2733 A-11 2213 2645 A-12 712 980 Yes A-13 1680 2196 B-0l a 0 0 B-02 1425 1909 B-03 776 1103 Yes
