Just curious...

     I am in Liberty township and a few months ago got an offer to buy my royalties for 1500 to 1800 per acre, but they would do a more in-depth look if I was serious which "mite change the numbers" slightly....even tho I am not drilled or receiving any royalties ..talked to a landsman rite b4 I contacted them and he advised caution as there will be "significant" activity in my area in the "near future"....how about it, anybody else get an offer or hear anything or see any activity here in Tioga Co. ?

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GAS COULD GO TO $1: 68 --- IT IS $2.57 AS I TYPE THIS

From PA DEP online well production numbers for Tioga County, PA - October, 2018

== Regulatory inactive horizontal unconventional wells ==

CHARLESTON VANDERGRIFT 290-2H SWEPI
CHATHAM BIESER V 833-2H SWEPI
CHATHAM SHOWALTER 822-3H SWEPI
COVINGTON TORPY VAN ORDER 574-3H SWEPI
DEERFIELD DOAN J 870 5H SWEPI
DEERFIELD SCHEIBLE P 898-5H SWEPI
DELMAR BROADBENT C 466 5H SWEPI
DELMAR BROWN 425-1H SWEPI
DELMAR COOLIDGE 464-5H SWEPI
DELMAR STEHMER 420-1H SWEPI
DELMAR WILLARD 419-1H SWEPI
DELMAR WILLARD 419 26H SWEPI
ELK THOMAS 3H SWEPI
ELK THOMAS 4H SWEPI
ELK TRACT 839 815 1H SWEPI
ELK TRACT 839 815 3H SWEPI
FARMINGTON SANCHIS M 1129-5H SWEPI
GAINES PIERSON 810 2H SWEPI
GAINES PIERSON 810 4H SWEPI
GAINES PIERSON 810 7H SWEPI
GAINES PIERSON 810 8H SWEPI
GAINES TRACT 839 815 2H SWEPI
GAINES TRACT 839 815 4H SWEPI
GAINES TRACT 856 822 1H SWEPI
GAINES TRACT 856 822 2H SWEPI
JACKSON ALLEN 264 1H REPSOL
JACKSON BREWER 258-1H SWEPI
JACKSON TOLBERT B 263 1H SWEPI
LAWRENCE DRAKE 274-6H SWEPI
LIBERTY EAST POINT FISH& GAME CLUB 726-1V ROCKDALE MARCELLUS
LIBERTY GUILLAUME M 714E-5 ROCKDALE MARCELLUS
LIBERTY GUILLAUME S 715E-4H ROCKDALE MARCELLUS
LIBERTY GUILLAUME S 715E-6H ROCKDALE MARCELLUS
LIBERTY GUILLAUME S 715W 715W-2H ROCKDALE MARCELLUS
LIBERTY KOHLER 2H SWN PROD CO LLC
LIBERTY TAYLOR M 718E-5H ROCKDALE MARCELLUS
LIBERTY TAYLOR M 718E-6H ROCKDALE MARCELLUS
LIBERTY TAYLOR M 718W-2H ROCKDALE MARCELLUS
MIDDLEBURY CHAPPELL D 855-5H SWEPI
RICHMOND BIELSKI 628-1V SWEPI
RICHMOND COLE R 495-6H SWEPI
RICHMOND COURTNEY H 255-2H SWEPI
RICHMOND FISH 301-1V 6H SWEPI
RUTLAND OLDROYD 509-5H SWEPI
RUTLAND PHILLIPS W 504-2H SWEPI
RUTLAND PHILLIPS W 504-5H SWEPI
SULLIVAN APPOLD F 493-3H SWEPI
SULLIVAN APPOLD F 493-8H SWEPI
UNION FITCH 115-1H ROCKDALE MARCELLUS
UNION MILLER E 116-2V ROCKDALE MARCELLUS
UNION MILLER E 116E-10H ROCKDALE MARCELLUS
UNION MILLER E 116W-8H ROCKDALE MARCELLUS
UNION SAWYER 376 5HS ROCKDALE MARCELLUS
WARD DCNR 587 002-03 REPSOL
WARD DCNR 587 02 004-04 REPSOL

== Regulatory inactive vertical unconventional wells ==

CHARLESTON BARBINE 2921V SWEPI
CHARLESTON BOROCH 477-1V SWEPI
CHARLESTON HEMENWAY TSRC 1 38937 SWEPI
CHARLESTON HOTCHKISS 472-1V SWEPI
CHARLESTON HUDSON 575-1V SWEPI
CHARLESTON LOPATOFSKY 287-1V SWEPI
CHARLESTON NEWLIN 4761V SWEPI
CHARLESTON PATTERSON 570-1V SWEPI
CHARLESTON PROPHETA 288-1V SWEPI
CHARLESTON REESE 289-1V SWEPI
CHARLESTON SALEVSKY 335-1V SWEPI
CHARLESTON SEVEM 474-1V SWEPI
CHARLESTON SHELMAN 2911V SWEPI
CHARLESTON SIGNOR 566-1V SWEPI
CHARLESTON SIGNOR 578-1V SWEPI
CHARLESTON SMITHGALL 293-1V SWEPI
CHARLESTON WORDEN 571 1V SWEPI
CHATHAM KALKE 819-1V SWEPI
CHATHAM VIOLET BIESER REVOC LIV TR 833-1V SWEPI
COVINGTON FROST 573-1V SWEPI
COVINGTON HITESMAN 580-1V SWEPI
COVINGTON SIGNOR 583-1V SWEPI
COVINGTON ZIMMER 586-1V SWEPI
DEERFIELD BAKER 897-1V SWEPI
DEERFIELD DOAN 893-1V SWEPI
DEERFIELD EMPSON 899-1V SWEPI
DEERFIELD MURDOCK 862-1V SWEPI
DEERFIELD MY T B INV LLC 891-1V SWEPI
DEERFIELD WOOD 874-1V SWEPI
DELMAR ANTHONY 5641V SWEPI
DELMAR BAKER 128D SWEPI
DELMAR BROADBENT 466-1V SWEPI
DELMAR BUCKWALTER 429-1V SWEPI
DELMAR BUTLER 127D SWEPI
DELMAR CLARK 392-1V SWEPI
DELMAR CLEVELAND 616-1V SWEPI
DELMAR ERICKSON 423-1V SWEPI
DELMAR FULEIHAN 417-1V SWEPI
DELMAR HACKMAN 143D SWEPI
DELMAR HALTEMAN 6111V SWEPI
DELMAR HEATH 418-1V SWEPI
DELMAR HEGE 4261V SWEPI
DELMAR KENNEDY 137D SWEPI
DELMAR KLETTLINGER 294-1V SWEPI
DELMAR LANGE 447-1V SWEPI
DELMAR MARTIN 421-1V SWEPI
DELMAR MILLER 394-1V SWEPI
DELMAR STEVENS 142D SWEPI
DELMAR STICKLIN 610-1V SWEPI
DELMAR TOPF 4161V SWEPI
DELMAR VANVLIET 614-1V SWEPI
DELMAR WASKIEWICZ 445-1V SWEPI
DELMAR WEBSTER 549-1V SWEPI
FARMINGTON BALDWIN 881-1V SWEPI
FARMINGTON DAVIS 829-1V SWEPI
FARMINGTON SANCHIS 1129-1V SWEPI
FARMINGTON SCHIMMEL 830-1V SWEPI
FARMINGTON STRATTON 885-1V SWEPI
FARMINGTON SWAN 11221V SWEPI
FARMINGTON WEINER 882-1V SWEPI
FARMINGTON YOURGALITE 11191V SWEPI
LIBERTY GUILLAUME 715-1V ROCKDALE MARCELLUS
LIBERTY INGALLS 710-1V ROCKDALE MARCELLUS
LIBERTY MCNETT 708-1V ROCKDALE MARCELLUS
LIBERTY SPENCER 729-1V ROCKDALE MARCELLUS
LIBERTY TAYLOR 718-1V ROCKDALE MARCELLUS
MIDDLEBURY BAUER 849-1V SWEPI
MIDDLEBURY BUTLER 853-1V SWEPI
MIDDLEBURY CRUTTENDEN 846-1V SWEPI
MIDDLEBURY FISH 826-1V SWEPI
MIDDLEBURY GEE832-1V SWEPI
MIDDLEBURY HAMBLIN 860-1V SWEPI
MIDDLEBURY KINNAN 845-1V SWEPI
MIDDLEBURY M L MITCHELL TRUST 554-1V SWEPI
MIDDLEBURY OWLETT 843-1V SWEPI
MIDDLEBURY TAFT 851-1V SWEPI
MORRIS HEYLER 748 1v ROCKDALE MARCELLUS
NELSON HARSELL 883-1v SWEPI
NELSON WOLFE 1114 1V SWEPI
OSCEOLA SORENSEN 876 1V SWEPI
OSCEOLA STANLEY 11061V SWEPI
OSCEOLA SYNNESTVEDT 878-1V SWEPI
RICHMOND BARTLETT 531-1V SWEPI
RICHMOND BENSON 130D SWEPI
RICHMOND BURT 518-1V SWEPI
RICHMOND CRITTENDEN 593 1V SWEPI
RICHMOND HAUSWIRTH 516-1V SWEPI
RICHMOND I G COVENEY REVOCABLE LVG TRUST 282-1V SWEPI
RICHMOND KUHL 529-1V SWEPI
RICHMOND SWINGLE 591-1V SWEPI
RICHMOND WESTBROOK 487-1V SWEPI
RICHMOND WOOD 496-1V SWEPI
RUTLAND BYRNE 510-1V SWEPI
RUTLAND CAMP NEVER TOO LATE 521-1V SWEPI
RUTLAND JENKINS 523-1V SWEPI
RUTLAND MCCLURE 527-1V SWEPI
RUTLAND SEELEY 524-1V SWEPI
RUTLAND STERLING 525-1V SWEPI
RUTLAND WOOD 512-1V SWEPI
RUTLAND WOOD 513-1V SWEPI
SHIPPEN CASCARINO 443-1v SWEPI
SHIPPEN HAZELTON 424-134 1V SWEPI
SHIPPEN WALKER 438-1V SWEPI
SHIPPEN YOUNG 431-1V SWEPI
SULLIVAN APPOLD 493-1V SWEPI
SULLIVAN BREON 492-1V SWEPI
SULLIVAN CLARK 486-1V SWEPI
SULLIVAN DEWEY HOLLOW GUN CLUB 601-1V SWEPI
SULLIVAN OLD POSSESSIONS HUNTING CLUB 485-1V SWEPI
SULLIVAN REDL 600-1V SWEPI
UNION COCHRAN 705-1v ROCKDALE MARCELLUS
UNION GUINDON 706-1V ROCKDALE MARCELLUS
UNION HEUER 701-1V ROCKDALE MARCELLUS
UNION MILLER 116 ROCKDALE MARCELLUS
UNION WESNESKI 724-1V ROCKDALE MARCELLUS
UNION YAGGIE 704-1V ROCKDALE MARCELLUS

Some of the vertical Swepi wells here were in the East purchase and the well pads are producing.

According to the data, in Delmar Twp, that was true for only 2 of 89 entries.  

Blue Ridge Mountain Resources Shareholders Approve Eclipse Merger



Last August Eclipse Resources announced it had sold itself to Blue Ridge Mountain Resources, the renamed remnant of Magnum Hunter Resources (see Eclipse Resources Merging with Former Magnum Hunter). Although Eclipse shareholders have approved the deal, not until today was there official approval by the shareholders of Blue Ridge Mountain Resources.

According to the press release below, the merger will happen by the last week of February. Which can’t come too soon for Eclipse since last month the NYSE has threatened them with delisting their stock (see NYSE Threatens Eclipse Resources with Stock Delisting).

We maintain that Blue Ridge is the company doing the buying, although the transaction is technically a merger (and although the name will remain Eclipse). Why do we say that? Because post-merger most of Eclipse’s top management is exiting state left, and Blue Ridge people are assuming most of the top management positions (see Eclipse’s Top Brass Not Sticking Around After Blue Ridge Merger).

Eclipse Resources Corporation (NYSE:ECR) (the “Company” or “Eclipse Resources”) and Blue Ridge Mountain Resources, Inc. (OTCPK: BRMR) (“Blue Ridge”) today announced that the stockholders of Blue Ridge, through the delivery of written consents, have adopted the definitive merger agreement under which Eclipse Resources and Blue Ridge will combine in an all-stock transaction (the “Transaction”) and approved the merger and the other transactions contemplated by the definitive merger agreement. The Transaction has now been approved by the boards of directors and stockholders of each company. Because Blue Ridge has received stockholder written consents sufficient to adopt the merger agreement and approve the merger and the other transactions contemplated by the merger agreement, all stockholder written consents received by Blue Ridge have become irrevocable.

Additionally, Blue Ridge has received requests from holders of the requisite percentage of outstanding Blue Ridge common stock to cause the Transaction to be a “drag transaction” for purposes of the Blue Ridge stockholders agreement. As a result, Blue Ridge’s stockholders will be required to take or refrain from taking certain actions, in each case, in furtherance of the completion of the Transaction.

As previously disclosed, Blue Ridge stockholders will receive consideration consisting of 4.4259 shares of Eclipse Resources common stock for each share of Blue Ridge common stock, before adjustment for a 15-to-1 reverse stock split of Eclipse Resources common stock to be effected concurrently with closing of the Transaction. Upon completion of the merger, Eclipse Resources will change its name to Montage Resources Corporation, and thereafter the Eclipse Resources common stock will trade on the New York Stock Exchange under the symbol “MR”.

The closing of the Transaction remains subject to customary closing conditions. Eclipse Resources and Blue Ridge expect that the Transaction will be completed during the last week of February 2019.

About Eclipse Resources Corporation

Eclipse Resources is an independent exploration and production company engaged in the acquisition and development of oil and natural gas properties in the Appalachian Basin, including the Utica and Marcellus Shales. For more information, please visit the Company’s website at www.eclipseresources.com.

About Blue Ridge Mountain Resources, Inc.

Blue Ridge is an Irving, Texas based independent exploration and production company engaged in the acquisition, development, and production of natural gas and natural gas liquids. Blue Ridge is active in two of the most prolific unconventional shale resource plays in North America, the Marcellus and Utica Shales.*

*Blue Ridge Mountain Resources (Feb 11, 2019) – Stockholders of Blue Ridge Mountain Resources, Inc. Approve Combina...

Marcellus Laterals Get Longer – Heading for 18,000 Feet!
 
February 18, 2019

A drilling team with experience drilling more than 1,000 Marcellus shale wells in Pennsylvania with laterals from 1,500 feet to 11,000 feet recently published a research paper looking at best practices and what it will take to routinely drill wells with laterals longer than 18,000 feet.

The following is a summary of a paper titled “Drilling Extended Laterals in the Marcellus Shale” was published in the Society of Petroleum Engineers’ Journal of Petroleum Technology, outlining the results of important new research.

A drilling team has focused on increasing lateral lengths in the Marcellus Shale. The team determined which operational practices would need to be revised in order to drill and case laterals in excess of 18,000 ft. During a 12-month period of revised processes and upgrades, the team drilled 34 horizontal wells, each exceeding 12,000 ft in lateral length, which represented the first Marcellus lateral to exceed that length.

Introduction

At the time of writing, the team had drilled more than 1,050 Marcellus wells in the state of Pennsylvania. In the first decade of development (2006–2016), it drilled hundreds of Marcellus horizontal wells with laterals ranging from 1,500 to 11,000 ft. The average lateral length over that period was 3,950 ft. In late 2016, focus was placed on developing the core acreage of the Marcellus field with extended laterals. This change in planning resulted in dozens of wells being scheduled that would feature lateral lengths exceeding 12,000 ft. As a result, the average lateral length increased to 9,450 ft over a span of 200 additional wells drilled starting in 2017.

Throughout the initial years of drilling Marcellus horizontal wells, tools and practices were used that efficiently drilled laterals under 4,000 ft in length. Routine operations included use of rigs with 5,000-psi circulating systems, directional tools with bent housing motors, saltwater-based polymer drilling fluids, and standard drilling procedures. In re-evaluating processes, the team focused on cost per lateral foot (Fig. 1). Increased performance coupled with maintenance of consistent overall drilling costs helped lower the cost per lateral foot.

Fig. 1—Drilling cost per lateral foot in Marcellus wells, 2012–2018.

Comprehensive studies followed by field tests were implemented in preparation for the extended laterals.

Rig Selection

While focusing on what are now deemed as shorter laterals, the team had experienced success drilling with super single rigs because of their versatility and efficient design. The second iteration of a rig fleet to meet the challenges of developing the Marcellus Shale came in the form of high-performance rigs with new enhanced horizontal-drilling capabilities. The team used this style of rig to meet lateral-length challenges successfully from 2010 until late 2016, drilling 805 Marcellus horizontal wells in that time period.

In the spring of 2016, the first 14,000?ft lateral was placed on the drilling schedule for the end of that same year. The rig fleet would need to be upgraded in order to meet the upcoming required changes in lateral length. Size of the rig and equipment became another critical consideration for the rig fleet, because, by then, returning to sites with actively producing wells had become routine, so the upgraded rigs selected would have to fit onto these sites.

After finding suitable candidates that fit the change in the drilling program, an additional rig was added in the fall of 2016 that featured the following characteristics:

  • 1,500-hp drawworks
  • 2,000-hp mud pumps (7,500-psi maximum rated working pressure with 4.5-in. liners)
  • 500-ton topdrive (37,500 ft-lbf maximum continuous drilling torque capability)
  • 1,365-kW generators
  • 5-in.-outer-diameter drillpipe
  • 750,000-lbm capacity mast, capable of racking back 21,500 ft of drillpipe

Directional Tools

As lateral-length average reached 6,000 ft, the ability to slide drill effectively and hold consistent tool face suffered and the drilling team used oscillating tools (initially, a rocking tool). Drilling laterals greater than 7,000 ft, however, required a different type of oscillating tool called an agitator. This is a downhole tool that is run on the bottomhole assembly (BHA) that increases the effectiveness of slide drilling by axially moving the drillstring as fluid is pumped through the tool. Agitators make each slide and rotate sequence more effective, especially when paired with surface oscillating tools.

When the drilling schedule increased to 10,000 ft and greater by the end of 2016, however, the team evaluated the currently used directional tools and determined that rotary-steerable tools would be required to reach these lateral lengths. Rotary-steerable tools allow the drillstring to steer while rotating the entire drillstring, eliminating the need to have a bent housing and slide drill. Fully rotating the drillstring throughout the drilling process reduces the friction between the drillpipe and wellbore. Rotary-steerable capability eliminates the need to use oscillating tools and the additional risk associated with each technology. Rotary-steerable tools also have precise directional steering ability in tighter target windows. Improved wellbore cleaning leads to improved rate of penetration and wellbore stability.

Drilling Fluids

Saltwater-based polymer drilling mud was used widely on lateral lengths up to 10,000 ft until 2015. This system used a high-chloride-based mud for improved inhibition drilling through the Marcellus shale, with effective rheologies for hole cleaning and additives to improve lubricity. This system was effective on shorter lateral lengths, but the drilling team experienced several instances of instability as the program developed from the early stages of drilling. Major lessons learned pointed to fluid-loss reductions and mud-weight increases.

Diesel-oil-based muds feature improved shale inhibition and lubricity. When paired with rotary-steerable tools, the time spent on wells and wellbore cleaning is reduced, leading to greater lateral drilling success.

By the end of 2016, the upgraded rig fleet with improved rig horsepower and additional pressure rating, combined with rotary-steerable tools and diesel-oil-based drilling fluid, were crucial to the team’s success in drilling laterals between 10,000 and 18,000 ft. Wellbore stability dramatically improved.

The changes resulted in a drastic increase in daily lateral footage per day. From the beginning of 2017 until the time of writing, there have been more than 30 days (24-hour report time) that have exceeded 5,000 lateral ft, including 2 days that have eclipsed 6,000 ft. These days have pushed the daily lateral average above 3,400 ft, which is close to the record day from 2015.

Casing Flotation

When running a long string of casing, increased drag must be considered before the casing run is begun. If the drag associated with running casing is modeled to reach a critical limit in which the pipe will not be able to be slacked off to bottom, a casing flotation sub can be used to achieve a desired set depth with minimal operational changes.

A flotation sub can be placed strategically in the casing string to aid in floating casing to bottom. With a single-drilling-fluid system, a specified length of casing is left empty (air-filled) with the area above the flotation sub filled with drilling fluid to aid in weight transfer. In the lateral, a buoyant effect on the casing caused by the difference between the drilling fluid and the air-filled portion of the casing helps float the casing to bottom.

After the casing is landed at the desired set depth, depending on the type of flotation sub used, the sub is then opened or ruptured to allow the lower portion of the casing to fill with drilling fluid. The air is then allowed to swap with the now-drilling-fluid-filled portion of the casing string and circulated back to surface, where it is bled off in a controlled manner. Afterward, the void is fully filled back to surface and prejob circulations can begin to condition the wellbore before cementing the production casing string.

Best Practices

Hole-cleaning practices and parameters have changed as lateral lengths have increased. Shorter laterals saw less of a procedural focus on wellbore-cleaning practices. The drilling-engineering team typically reproduced standard procedures in well after well. As laterals continued to lengthen, an abnormal number of wellbore issues were encountered in 2014 and 2015. An in-depth review determined that, while drilling, parameters including flow rates and rotational speed needed to be increased. After drilling to total depth (TD), the circulations increased with specific parameters to maintain.

In addition to cleanup-cycle parameters, an added focus also was put on tripping procedures. Standard procedure for shorter laterals focused on fast tripping in order to get the wellbore cased and cemented in a short time. As laterals were extended, a point was reached at which pulling the drillstring off bottom without needing the drilling contractor’s overpull approval was unachievable. In those instances, back-reaming was the recommended method to get off bottom. The first two laterals exceeding 15,000 ft required back-reaming to trip out of the hole once TD was reached. In both of those wells, while tripping out, the drillstring encountered tight hole spots where back-reaming was required to continue out of the hole. On the third 15,000-ft lateral, back-reaming operations resulted in the drillstring sticking and leaving the BHA downhole. An investigation uncovered that the drillstring was being back-reamed out of the hole at higher-than-recommended speeds. Even with the drillstring being back-reamed out of the hole, at those speeds, it was pulled into a cuttings bed that ultimately packed off the BHA. New back-­reaming standards were implemented to limit tripping speeds while back-reaming.*

The article was written by by Joshua Doak, SPE, Matthew Kravits, SPE, Michael Spartz, SPE, and Pat Quinn, Range Resources-Appalachia.

The full article is available for purchase here: https://www.onepetro.org/conference-paper/SPE-191783-18ERM-MS

*Journal of Petroleum Technology (Feb 1, 2019) – Revised Drilling Practices Lead to Lateral-Length Gains in Marcellu...


Thank you for posting this kind of information. I am the kind of person that likes to know how things work. Starting at about 8 years old, I took apart many old wind up clocks just to see how the many brass gears, hair springs and assorted parts were able to work together. 

Granddad Ladd 

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Forgotten Men and Women of Canadian Energy Industry Protest

Posted by Thomas J Shepstone on January 4, 2019 at 10:37am 0 Comments

The forgotten men and women of the Canadian energy industry are mad as hell and not taking it anymore. They’re protesting in their trucks and it’s spreading.

Whenever I go to New York City, which is as seldom as…

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