Sunday, March 3, 2013

Report: 47 Tcf Gas Potential at Buru's Canning Permits

Buru Energy revealed Friday that RISC, an independent evaluation group, has completed an assessment of the prospective resources for all of the company's onshore permit areas in the Canning Superbasin.

The evaluation report confirmed that the Basin Centred Gas System in the Laurel Formation, spanning around 6,708 square miles (17,373 square kilometers), contains an unrisked gross recoverable volume of 47 trillion cubic feet of gas and 1,177 million barrels of condensate.

RISC has only considered the reservoirs in the overpressured part of the Laurel Formation in their analysis, Buru noted in a statement.

More work is required to quantify the resources in the extensive overlyinggas accumulation in the normally pressured section, generally above 8,202 feet (2,500 meters), Buru added.

RISC also stated its view that the existing analysis identified reservoirs which are a combination of conventional and unconventional reservoirs; the latter will likely to require stimulation.

Buru, in a joint agreement with Mitsubishi Corp, owns five permits that lie on the onshore Canning Superbasin. In November last year, the company signed an agreement with Western Australia's state government for EP 71, 391, 428, 431 and 436. The contract runs for 25 years, and comes with a separate 25-year extension option.

Buru said in November last year that the agreement provides a framework for the development of a project to deliver gas to a liquefied natural gas facility in the Pilbara, once sufficient gas has been identified to sustain domestic consumption. The JV is required to submit a proposal for the development of a domestic gas project and pipeline by June 30, 2016.

Quintella has reported on the upstream and downstream oil and petrochemicals markets from 2004. Email Quintella at quintella.koh@rigzone.com.

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Trapoil Buys 33.33% of Trent East Terrace Area

UK North Sea-focused junior Trapoil announced Friday that it has agreed to buy one-third of the Trent East Terrace (TET) Area license in the southern North Sea from Perenco UK.

In return for its 33.33-percent share in Block 43.24a, where the TET Area is located, Trapoil has committed to securing a drilling rig within six months for a planned appraisal well. Trapoil’s share of the drilling costs is expected to be approximately $8 million.

It is also intended that Trapoil will be the operator of the TET Area, subject to approval from the Department of Energy and Climate Change.

TET has proven gas in the Carboniferous Westphalian and Namurian reservoirs, with gross recoverable gas resources estimated by Trapoil's management to be between 35 and 60 billion cubic feet. Trapoil's management believes that the proposed drilling of a new appraisal well could potentially recover closer to 60 bcf if all of the main porous gas-bearing sands flow at commercial rates. The existing 43/25-3 discovery well drilled by Arco British Limited flow tested from two of the five potential sands at an aggregate rate of 50 million cubic feet of gas per day.

Trapoil CEO Mark Groves Gidney commented in a company statement:

"The farm-in to the TET asset enables the group to secure operatorship, subject to DECC's approval, and therefore exercise greater control over the scheduling of our work program. In addition, this relatively straight forward gas development project, in conjunction with the promising exploration potential in the adjacent acreage, offers the prospect of attractive cash flow for the group in the medium term."

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DOI Calls for Drillers to Inspect, Replace Bolts after Defects Found

The U.S. Department of the Interior (DOI) has directed U.S. Gulf of Mexico drilling operators whose rigs have a lower mariner riser package (LMRP) H4 connector manufactured by GE Oil & Gas' Hydril division to cease operations and to inspect and possibly replace these bolts after defects were uncovered on some rigs.

GE Oil & Gas issued a notice Jan. 29 to customers calling for them to inspect and remove the bolts after the upper and lower bodies of a H4 Connector contained in the LMRP of a rig operating in the U.S. Gulf of Mexico separated.

A recent investigation indicated that stress corrosion cracking caused by hydrogen embrittlement contributed to the separation of the upper and lower bodies of the LMRP, according to a GE statement.

GE is conducting a root cause analysis into the incident. Additionally, the company has been recently made aware of two additional data points found during surface inspections of the identified bolts. Both instances are being investigated.

The company has expanded the safety notice to include all H4 Connector bolts (P/N H10004-2) produced from June 2007 to October 2009 in the H4 product family, including E, DxE, ExF, HD and DWHD.

While GE is investigating the production history of these H4 Connector bolts, a preliminary investigation has indicated bolts produced during this time are more susceptible to hydrogen embrittlement.

The safety notice does not affect the SHD Connector, GE commented.

The faulty bolts should concern mainly older rigs, DOI commented.

"Operators are currently evaluating which rigs have the faulty equipment, but at this time it looks like this will have a minimum impact on the drillers as this equipment is produced over a short period of time," DOI added in a statement.

Recently delivered rigs with the Hydrill blowout preventer (BOP) that have a Super HDH-4 connector were mostly delivered after 2009, and DOI has no indication that these rigs would be affected.

Officials with DOI's Bureau of Safety and Environmental Enforcement met with industry officials late last month to discuss the initial finding associated with a pollution incident involving the discharge of a synthetic base mud in the Gulf due to a loss of integrity of a LMRP H-4 connector. During the meeting, it was introduced that zinc electroplating without proper baking, as per ASTM B633, was a possible cause of hydrogen embrittlement. BSEE was also informed during this meeting of two other rigs as having H-4 connector bolt failures.

On Jan. 25, BSEE received information from GE which identified rigs as having BOP stack connectors that may contain bolts that may no longer be fit for purpose. BSEE then contacted operators associated with this subset of rigs currently operating in the U.S. Gulf of Mexico, asking them to halt operations until the existing bolts on the LMRP connector/wellhead connector could be changed out with bolts that have been certified by an independent third-party to comply with recommended heat treatment practices or if existing bolts have been examined and certified as fit for purpose.

Though the notice covers the entire Outer Continental Shelf, the issue is only for subsea BOPs, which are typically used for floating rigs, according to a Feb. 2 research note from Barclays Capital. GE holds approximately 50 percent market share for the deepwater Gulf BOP market.

Industry sources indicate that 159 connectors from GE's Vetco division have issues. Drilling contractor Transocean Ltd. is estimated to have 60 rigs and Diamond Offshore Drilling, Inc. has approximately 30 rigs. Rigs belonging to Noble Drilling and Ensco plc are believed to be impacted, while three Seadrill rigs were affected.

While U.S. Gulf rig operators will have to stop operations to pull the BOP and fix the problem, it is believed that drilling operators operating worldwide – at least in Brazil – the bolts will be repaired the next time the BOP is pulled for a normal reason such as a new well.

For rigs operating in the U.S. Gulf of Mexico, it is not known how this will play out in terms of rigs being on day rate or not when the bolts are fixed. According to one drilling contractor, one day per BOP in time of fixing the bolts, excluding pulling and setting the BOP, could total two weeks.

A final issue is whether the rig owners have spare bolts or not, but industry analysts believe most do. GE said in its notice it would supply new bolts as appropriate. GE estimates that 9,000 to 10,000 bolts need to be replaced and has been producing replacement bolts since Feb. 2 at a rate of 500 per day, according to Barclays' analyst James C. West.

GE said in its notice it would supply new bolts as appropriate.

Halting operations to inspect and replace bolts will pose additional downtime risk for offshore drillers, but Barclays Capital analyst James C. West commented that downtime could be limited and can be often mitigated through the course of normal operations.

While the BSEE notice called for operators to halt operations until the existing bolts are replaced and verified, the notice also recommended operators consult with contractors to determine the appropriate…corrective actions," potentially leaving some room to inspect BOPs during the normal course of operations rather than stopping work immediately, said West in the Feb. 7 note.

"While we await further clarity, we think this event could present knee-jerk headline risk for some offshore drillers, particularly those with direct exposure to GE bolts," West commented.

The H4 family of subsea connectors was introduced in 1964 and is used in every major producing region worldwide and every type of offshore environment, according to Hydril's website.

Karen Boman has more than 10 years of experience covering the upstream oil and gas sector. Email Karen at kboman@rigzone.com.

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Senecio Tight Gas Feasibility Study Underway

AWE disclosed Thursday that it has started on a development feasibility study for the commercialization of the onshore Senecio tight gas accumulation. The Senecio discovery is located in the north Perth Basin, Western Australia.

Analysis of pressure tests conducted in November 2012 and other data captured since the fracture stimulation has confirmed permeability of between 0.03 millidarcy (mD) to 0.06 mD, which is within the pre-fracture estimated range.

"This analysis, together with the successful flow test in September 2012 that reported a stabilized gas rate of 1.35 million standard cubic feet of gas per day, with a 16-foot (five-meter) perforation interval, demonstrates potentially commercial reservoir flow capacity," AWE said in a statement. AWE's project partner is Origin Energy. Both of the companies have an equal stake in the partnership.

AWE has previously booked a 2C contingent resource for its 50 percent equity share of Senecio of 4.4 million barrels of oil equivalent (mmboe). Previously interpreted 2D seismic data indicated a potential estimated recoverable volume of at least double the quantity currently booked. An outcome of the feasibility study will be an updated definitive resource estimate which will be based on latest interpretation of the well data, the new 3D seismic data, and planned reservoir modeling studies.

AWE's Managing Director Bruce Clement, said that the Senecio tight gas commercialization program is gaining momentum and that positive subsurface data has given the company considerable confidence that commercial gas production can be achieved from the Senecio discovery.

"The results of the pressure test, the flow test, and the Irwin 3D seismic program indicate that a horizontal, multi-stage, hydraulically fracture stimulated well at Senecio could be economically viable," Clement noted in a statement.

"The Perth Basin is potentially a very important source of energy for the Western Australian market and we believe that the timely completion of a development feasibility study will help define a valuable gas resource," Clement added.

AWE plans to consider the use of nearby existing plant processing infrastructure to minimize the project's environmental footprint and development costs. Evaluation of the Dongara and Xyris gas plants and associated infrastructure will form part of the study.
Detailed work on project planning, budget and product marketing may start as soon as 2Q 2013.

Clement said: "The unconventional gas program in the Perth Basin has been very successful to date, significantly increasing our understanding of the geological and commercial potential of the tight gas and shale gas opportunities in the Basin.

Our exploration team is looking at 30 years of accumulated data for the Perth Basin, compiled through conventional oil and gas exploration activities, to identify additional tight gas intersections with development potential."

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SKKMigas: Pipeline Leak Resolved, Chevron Resumes Oil Deliveries from Riau

Oil deliveries from Chevron Corp’s fields in Indonesia's Riau province have resumed, following delays early this week due to a pipeline leak, SKKMigas disclosed in a statement late Thursday.

A breach of the 47-mile (76-kilometer) pipeline, which occurred Tuesday, disrupted deliveries of oil from the Bangko area to the Dumai terminal, SKKMigas' Deputy of Operations, Gde Pradnyana, said in a statement.

SKKMigas and Chevron Pacific Indonesia started repair and clean-up works Wednesday, with operations expected to return to normal Friday. SKKMigas was not reachable for an update on the repair and clean-up operations Friday. 

Seven workers were exposed to splashes of oil. Three workers were flown by helicopter to a nearby hospital Tuesday, while the remaining four were sent back home as their "conditions were not alarming." Of the three hospitalized workers, two are already discharged Thursday.

SKKMigas and Chevron Pacific Indonesia are at present conducting a joint investigation to confirm the cause of the accident and the volume of oil which spilled as a result.

The pipeline delivers output from the Duri field in the Rokan production sharing contract (PSC).

The Duri field is the largest producing field operated by Chevron in Indonesia. The field, discovered in 1941 on the island of Sumatra, is home to one of the world’s largest steamflood projects. Extensions to the field are on-going at present.

Quintella has reported on the upstream and downstream oil and petrochemicals markets from 2004. Email Quintella at quintella.koh@rigzone.com.

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Man Working at Carroll Site Crushes Hand

A worker on the Harvey oil-well site on Buttercup Road in Washington Township was injured Tuesday morning when his hand became caught in the main controls for the rig.

Carroll County Sheriff Dale Williams said his office received the call for assistance at 11:22 a.m. and his deputies responded, as well as Fox Township, Carroll County and Carrollton Village fire departments.

Williams said the man's hand was crushed and a piece of metal impaled his hand.

Williams said the injuries were not life-threatening and the main was transported by ambulance to a Canton hospital.

Copyright 2013 The Times Reporter Distributed by Newsbank, Inc. All Rights Reserved

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Gunmen Blow Up Marib Oil Pipeline in Yemen

SAN'A, Yemen - Gunmen in Yemen Friday blew up a key oil pipeline that has been repeatedly attacked in the country's eastern Marib province, a security official and witnesses said.

"Subversive elements in Wadi Obaida (around 12 kilometers from Marib) blew up" the 320-kilometre pipeline that carries oil from the Safer oilfields in Marib to an export terminal on the Red Sea, the official said.

Witnesses said flames erupted from the pipeline that carries around 180,000 barrels a day following the explosion early Friday.

Attacks on oil and gas pipelines by al Qaeda or by tribesmen seeking to win concessions from the central government are common in Yemen, an impoverished country that produces about 300,000 barrels of oil a day, mostly for export.

In December, the army launched an offensive against tribesmen suspected of repeatedly sabotaging the pipeline, sparking clashes which left 17 people dead.

According to official figures, lost production because of pipeline attacks in the east cost the government more than $1 billion in 2012, while oil exports fell by 4.5%.

In July, Petroleum and Minerals Minister Hisham Abdullah said Yemen had lost more than $4 billion in revenues since February 2011 because of such attacks.

Copyright (c) 2012 Dow Jones & Company, Inc.

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Lebanon's Plans for Gas Boom Falter

Lebanon's dysfunctional government desperately wants to start awarding contracts for natural gas exploration in the eastern Mediterranean and start a process that could rescue a steadily declining economy.

But Lebanon is crippled by centuries-old sectarian rivalries that could derail the process of extracting the estimated 25 trillion cubic feet of gas that lies beneath Lebanese waters while neighboring Israel and Cyprus press ahead with developing gas booms that will transform their economies.

The pre-qualification process for international companies seeking exploration licenses was to begin Feb.1 after many months of delays because of political infighting between the leading sects for controlling interests in the enterprise.

If it did, nobody noticed it. That probably has a lot to do with the fact the Council of Ministers hasn't issued a decree authorizing the bidding process, in which Energy Minister Gebran Bassil claims 40 international companies are ready to participate.

"When it eventually does, it will in theory initiate a bidding timetable insulated from the bickering and volatility of Lebanese politics and should see contracts being awarded in March next year," the Financial Times reported.

"But analysts warn that many complex, politically sensitive decisions still lie ahead."

The endemic sectarian rivalries that have plagued Lebanon, even when it was under Ottoman rule that ended after World War I, infect just about every facet of life in the tiny country and regularly trigger violence, the 1975-90 civil war being the extreme example.

And the prospective gas boom is no exception. Every sectarian leader wants a cut of the action.

A few weeks ago, the government appointed a six-member Petroleum Administration, comprising representatives of the main sects, after months of wrangling. It's supposed to prepare the technical and legal work before negotiations with the foreign companies commences.

Demarcation disputes with Israel, with which Lebanon is still technically at war and Cyprus have complicated the entire exploration process.

But growing political and sectarian polarization, aggravated by the civil war in neighboring Syria that's approaching its third year, has virtually paralyzed recent governments, to the point that no national budget has been passed since 2005.

Bassil has repeatedly assured the nation that the selection process will be finalized by March 2014 with exploration expected to start in 2017.

Cesar Abi Khalil, an energy ministry adviser, insists the exploration and production agreement, or EPA, model will be approved by the Council of Ministers and bidding will begin May 2.

There's supposed to a parliamentary election in June, although the parties cannot agree on an electoral law since all want to secure the greatest advantage for themselves and their constantly changing alliances.

But Abi Khalil says the likelihood of prolonged difficulties in actually forming a government won't interfere with the process of awarding exploration blocks to foreign companies, all of which have to have Lebanese partners.

It's not known which blocks are likely to be put up for auction but these are likely to be in areas off southern Lebanon, which abut Israel's big Leviathan field discovered in 2010.

Leviathan contains an estimated 16-20 tcf. The Tamar field to the south holds 8.4 tcf.

Seismic surveys in Lebanese waters have concentrated on the southern zone that's believed to be an extension of Leviathan's gas-bearing strata. This includes a triangular 330-square-mile zone that's the center of the dispute with the Jewish state.

The prize is great. The U.S. Geological Survey reported in 2010 that the deep-water Levantine Basin, which encompasses Syria, Lebanon, Cyprus, Israel and the Gaza Strip, contains 122 tcf, plus 1.7 billion barrels of oil.

Extracting all of this will require an investment of tens of billions of dollars.

That's a problem for Israel and possibly for Lebanon, too.

Major oil companies have shied from investing in Israel's energy bonanza because of the decades-old fear of offending the Arab world where about one-fifth of the world's oil lies.

Lebanon's propensity for violence -- its own or somebody else's -- could also drive off potential investors.

The Jamestown Foundation, a Washington think tank, observed in January that for Lebanon "in the foreseeable future, the potential political conflict over the exploitation of energy resources ... is most likely to follow the predictable pattern of conflict" between the main pro-Syrian and anti-Syrian blocs that are currently the country's key protagonists.

Copyright 2013 U.P.I. All Rights Reserved


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Oklahoma City Fears an End to Chesapeake's Largess

OKLAHOMA CITY - At the 100-acre headquarters of Chesapeake Energy Corp., cranes continue to erect new glass-walled buildings and the company is seeking a sushi chef for what will be the fifth restaurant on its campus.

But the buzz here is that the nation's second-biggest natural-gas producer is cutting back on spending. And that worries some of its 5,000 employees here, as well as local government officials, nonprofit leaders and even some sports fans, all of whom have benefited from the largess of Chesapeake and its co-founder and chief executive, Aubrey McClendon.

Mr. McClendon, a native son of Oklahoma City, was ousted last week by directors insisting on financial austerity. His departure follows Chesapeake's decision to cut in half its charitable contributions, which totaled more than $56 million in 2010 and 2011 combined, within three years and to chop $190 million in overhead within 24 months.

The natural-gas company's finances have suffered from low prices for natural gas, compounded by its heavy spending to find and pump greater amounts of more-lucrative oil.

The company plans to sell assets to raise at least $5 billion this year to pay for its drilling and to reduce debt, which at the end of September exceeded the company's current $13 billion market capitalization.

Directors of local nonprofits, from food banks to arts organizations, that have received donations for years from Chesapeake and from Mr. McClendon say they are worried.

"It's hard not be concerned," said Lori Dickinson, president of the Foundation for Oklahoma City Public Schools, which doles out school supplies and pays for programs for city schoolchildren. Chesapeake accounts for 15% of its budget.

Energy companies, including Devon Energy Corp. (DVN), SandRidge Energy Inc. (SD) and Continental Resources Inc. (CLR), have helped drive an economic expansion here in recent years. The companies have recruited workers from across the country and have built big headquarters. Unemployment in the metro area was 4.7% in December, compared with the national average of 7.8%.

But Chesapeake has taken a leading role in transforming a city that used to be dismissed as a cow town. Its name is on the arena that is home to its professional basketball team, the Thunder, a major source of civic pride. The team reached the finals of the National Basketball Association's championship last year, losing to the Miami Heat.

Mr. McClendon, who helped bring the team from Seattle and owns 19% of it, has pledged to donate to Oklahoma schools the amount of fees Chesapeake pays for naming rights multiplied by his ownership stake in the team for at least this year and last.

"Oklahoma City's national and international perception has changed because of the Thunder," said Jim Couch, the city manager. A framed team jersey, autographed by the players, hangs on the wood paneling of his office.

"It's been pretty public that they're going to shed some assets," Mr. Couch said of Chesapeake. "How that goes and what means for Oklahoma City, I don't know."

Michael Kehs, a Chesapeake spokesman, said: "Our commitment to being a helpful and engaged corporate citizen will continue." Chesapeake employees will continue to volunteer their time local organizations, and the corporation will make financial and in-kind contributions, he added. A spokesman for Mr. McClendon declined to comment.

Mr. McClendon has his own financial issues to contend with. He owed at least $846 million in loans at the end of 2011, according to a regulatory filing in April.

He used most of the proceeds to participate in a perk that allows him to acquire a small stake in every well Chesapeake drills as long as he pays his share of the costs, which totaled $457 million in 2011.

The perk sparked controversy last year after disclosures that Mr. McClendon borrowed from firms that invested in Chesapeake, and he and the board of directors agreed to end the practice next year.

A board review hasn't found any misconduct, the company said last week.

Despite an exit package of almost $50 million, to be paid out over four years, Mr. McClendon's cash needs are likely to remain high. He is again investing in the company's new wells this year. A state filing in January indicated that he and his wife have repaid a 2009 loan from George Kaiser, a Tulsa oil magnate. Mr. McClendon has pledged as loan collateral many of his assets, including a wine collection and a warehouse full of old gasoline pumps and oil memorabilia, and has plans to develop lakefront property in Michigan.

Mr. McClendon's departure, coupled with Chesapeake's spending cuts, have prompted anxiety among some employees, which Chairman Archie Dunham moved to address last week. He told employees in an email that the board isn't planning to eliminate its child-care facility, shut down its 72,000-square-foot gym or sell its campus restaurants.

Except for a recent increase in the gym-membership fee, which the company won't divulge the size of, the flagship campus isn't showing signs of a financial squeeze.

Modern, glass-walled offices are going up next to Chesapeake's red-brick, Georgian-style buildings and will house employees currently working elsewhere in the city. A fifth restaurant called Skyline, will be perched on the top floor and offer a view of downtown six miles away. Chesapeake has posted job openings for a sushi chef and cooks to serve Mongolian and Italian offerings.

But some members of Chesapeake's board, controlled since June by directors nominated by its largest shareholders, have raised eyebrows at the company's amenities. Chesapeake, however, has long argued that they are key to attracting talented employees and maximizing productivity.

Some Thunder fans have speculated Chesapeake's spending diet could hurt the basketball team it sponsors. But the company has a sponsorship agreement that runs for at least a decade under which it pays between $6 million and $7 million a year in sponsorship fees and naming rights to the Chesapeake Energy Arena.

The team is a big hit with Oklahomans like Gary May, who drove an hour to see the Thunder play the Dallas Mavericks here on Monday. The 57-year-old contract driller pumped his fist as the hometown team scored, en route to a 112-91 victory.

Mr. May said he is sorry to see Mr. McClendon leave Chesapeake. But taking in the glitz of the arena, and thinking of his glimpses of Chesapeake's sprawling campus, he marveled at all the funds that went to things other than producing oil and gas.

"There's probably a lot of money spent where it didn't need to be spent," he said.

Copyright (c) 2012 Dow Jones & Company, Inc.

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Senex Starts Fracture Stimulation Program Onshore Cooper Basin

Senex Energy disclosed Thursday that it has started on a large scale fracture stimulation program on its unconventional gas exploration wells in the onshore Cooper Basin, beginning with Skipton-1 in PEL 516.

The five well program aims to delineate unconventional gas resources in several Senex permits in the southern and northern South Australian Cooper Basin.

Senex has successfully drilled three new dedicated unconventional gas exploration wells in its southern permits: Skipton-1, Kingston Rule-1, and Talaq-1. A fourth well, Paning-2 in the northern Cooper Basin, has successfully been drilled and is currently being cased. Senex observed significant zones of net gas pay within all of these wells.

This program involves fracture stimulation and flow testing of these wells, along with the existing Hornet-1 well which flowed gas to surface during drilling in 2004. Senex expects this program will provide information on post-fracture production rates and detailed information to allow the refinement of fracture stimulation design within tight gas sands, shales and deep coals in the Cooper Basin.

In particular, the program seeks to determine the fracture complexity and orientation within both the primary target Patchawarra Formation sands and the secondary targets Roseneath, Epsilon and Murteree shale and tight sand package and the Toolachee and Patchawarra coals.

Senex's Managing Director Ian Davies, noted that the fracture stimulation program would provide valuable information for the appraisal and testing of its unconventional gas assets in the Cooper Basin.

"For Senex, this is another major step forward in the appraisal of our highly prospective unconventional gas assets," Davies said in a statement.

Senex expects the current program will result in the certification of material contingent resources. Measurement of gas flows from these wells will influence the design and location of pilot programs required for longer term production testing and reserves certification.

Upon completion of the Skipton-1 program, Senex will fracture stimulate Kingston Rule-1, Talaq-1, Hornet-1 and Paning-2. The fracture stimulation program will be completed over a two month period, with flow testing to continue into June this year.

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